ML20196F410

Forwards Exam for ANO-1 Initial Exam Scheduled for 980914. Includes Hard Copies of Emergency Operating Procedures,Ro & SRO Written Exams,Dynamic Exams,Job Performance Measures (Jpms) & Administrative JPMs & Questions

ML20196F410
Person / Time
Site:	Arkansas Nuclear
Issue date:	07/16/1998
From:	Byford R ENTERGY OPERATIONS, INC.
To:	Mckernon T NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION IV)
Shared Package
ML20196F400	List: ML20196F393 ML20196F410
References
50-368-98-302, NUDOCS 9812070030
Download: ML20196F410 (900)

Text

T ENTERGY m,

- . s. m .

l July 16,1998 l

1 Mr. Tom McKernon, Chief Examiner i U. S. Nuclear Regulatory Commission 611 Ryan Plaza Drive, Suite 400 Arlington, TX 76011-8064

Subject:

Initial License Examination - Exam Submittal for ANO, Unit 1 (B&W)  !

(NRC Inspection Report 50-368/98-302)

Dear Mr. MCKernon:

Attached is the examination for the Arkansas Nuclear One, Unit 1 Initial Examination scheduled for September 14,1998. Included are hard copies of the Emergency Operating procedures, RO and SRO written exams, dynamic exams, Job Performance Measures (JPMs) and Administrative JPMs and questions. A Compact Disk with the latest revision

{

of the Abnormal Operating Procedures, Site Training Procedures and Operations Directives is included for your review.

1 Please call me at 501/858-6844 ifyou have any questions.

Sincerely, D

Robert O. Byford  :

Facility Representative Arkansas Nuclear One Supervisor, Simulator Training & Support Attachments

/

cc w/o attachment: M. Goad D. Sealock  !

S. R. Cotton Licensing 9812070030 981130 e PDR V

ADOCK 05000313 PDR [7C j

l Justifications for Changes to ANO Unit One Sample Plan Changes to Written Sample Plan:

1. SRO, Tier 1, Group 1 - Changed 026 AA2.02 to 026 AA2.05. The ability statement changed from "The cause of possible CCW loss" to "the normal values for CCW header flow rate and the flow rates to the components cooled by the CCWS."

This modification was made due to duplication of this K/A in the exam.

2. RO/SRO, Tier 2, Group 2 - Changed 014 A2.01 to 014 A2.07. The ability statement changed from " Loss of offsite power." to " Loss of reed switch."

A loss of offsite power does not produce any noteworthy effects, therefore a more appropriate topic was selected.

3. RO/SRO Differences between Tier / Group totals and NUREG 1021 Forms ES-401-4 and ES-401-3 Tier / Group totals - Some adjustments were made due to plant specific characteristics and also due to NRC request for Generic K/A's for Tier's 1 and 2 in addition to Tier 3.

4. Several typos were corrected, none of any significance.

Changes to Administrative Sample Plan:

1. SRO Operating Test No.1 - Converted the JPM subject for 2.1.4 to an open reference question for 2.1.17. Converted the open reference question subject for 2.1.17 to a JPM for 2.1.4. There wasn't any overt action for the proposed JPM subject in 2.1.4, therefore a JPM could not be developed and thus the reason for the switch.

2. SRO Operating Test No.1 - An optional JPM for topic A.2, subject 2.2.13 was added as requested by the NRC.

l

PWR RO Examination Outline Worksheet Based on NUREG-1021 Form ES-401-4 Pg 30 of 30 Interim Rev.8. January 1997 l KIA Category Points l 7

Tier Group 0 7 Awrage [#;

_ 11 K3 K4 i K5 i K6 A2 l A3 _

Tier 1 1 5 1 4 16 16 2 4 4 5 1 5 2 21 21 Plant _.

3 4 4 Evolutions 1_0__ 1 1 1 1 9 5 10 3 10 4 41 41 6.83 3.19 T s Tier 2 3 1 0 1 3 0 2 1 0 4 2 1 15 15

! Plant 2 1 1 1 l6 l2l2l1 l2l1 l1 l0l 18 fa

~

systems 1 2 1 0l1 l2l1 l1 l2l1 l2l0l 13 13 4 2 2 10 4 5 3 4 6 5 1 46 46 4.18 2.44 To s Tier 3 cati Cat 2 Cat 3 Genenc ,,,,3,,,,,,, 3 ____ _,_

13

~

l l l 1 ~ ~~

l l I l -

i i l 1 -

1 I I I K/A Totals 13 7 12 10 4 5 l6 14 6 l5 lS l 100 100 7.91 3.65 l I i l I I I I l  ! f l l

Page1

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t PWR RO Excmination Outlino __

i Emergency and Abnormal Plant Evolutions - Tier 1/ Group 1 __

E/ APE # / Name / Safety Function K1 K2 K3 A1 A2 G KIA Topic (s)K/A Topic (s)KIA Topic (s) Imp. Points 005 AK2.02 Knowledge of the interretshons between the Occoob inopwraboarStuch Ccotrol Rod t i 1 CRDS and the fobowing: Breakers, releys, disconnects, and control room =wNehes 2.5 1 015 AK3 03 Knowledge of the reesons for the following responses as they apply to the Reactor Coolant Pump ooc 315/17 RCP WWunctons i N 1 Matunchone (Loos of RC Flow): Sequence of events for manueNy tnppeng reactor and RCP as a result of an itCP maa function 3.7 1 B&W E09 EK3.3 Knowledge of the reesons for the BWTog* CE/A13. WT09&E 10 Natural Circ. / N 1

"**' 'P ' ' "'("'""  !

Circuishon Cooldown): Manipulmung cortrois to obtain i deswed results. 3.8 1

_ l 000024 Em-gancy ear = ten ii 1 2.120 Abimv to eiecute procedure steps. 4.3 1 i

M AA2.06 % b h and W the foNowmg 000026 Loss of Cor iponent Cooling Wate t vm (intermediese Cocmng 1 as they apply to the Laos of Component Coohng Water-w,,,, . Anoj The length of time after the loss of CCW flow to a component before that -W may be damaged 2.8 1 000027 Pressuntw Pressure Control System WEmeten f M 0 i

E05 EK1.2 Knowledge of the operationalimphcabons of oooooo (eWros. CE/Eos. W T 12) Steam Line Rupture - Encessive 1 the follow 6ng concepts as they appey to the (Excessrve Heat ,

""*'"*""'" Transfer): Normal, abnormal and emergency operating procedures associmeed wth (Excesswe Hast Transfer). 4.0 1 t

j 051 AA2.02 Abimy to determne and inter; ret the foNowing mo s: Loss of Condens vacuumiw as my e k h w of m vacuum-Condnions requaing reactor and/or turbine trip. 3.9 1 055 EK1.02 Knowledge of the operationalimphcahans of ooooss St. ten ewhout ivi 1 the foNowing concepts as they apply to the Stahon .

Blackout: Natural circuishon coal ng 4.1 1 ,

057 AK3 01 Knowledge of the reasons for the following responses es they apply to the loss of Vital AC Instrument ,

000057 Loss of Vital AC Elec. Inst. Bus t Vi 1 Bus: Actions contained in EOP for loss of vdal AC  !

t electncal instrument bus. 4.1 1 l l l l f

Page 1 i i

PWR RO Examination Outline '

Emer3ency and Abnormal Plant Evolutions - Tier 1/ Group 1 i

E/ APE # / Name / Safety Function K1 K2 K3 A1 A2 G M/A Topic (s)M/A Topic (s)M/A Topic (s) Imp. Points Os2 AA2.01 Abaty to determne and interpret it= fonounne nonom, to or N co , s.n, c.wei.,s u 1 en they appsy to the Laos of Nucteer Sevice Water:

Laceman of a i ek in the ccws. 2.9 1 067 AA2.17 Abouy to essermine and ar.- the followmg asses? Pi.ni rir. on-.a. nx 1 es they apply to the Plant Fire on sne: Systems that may be aneceed by the fire. 3.5 1 088 A;3.10 Knowledge of the reasons for the following 1

nnnnes (swtAotn Control Room Ev.c. IVM roepenses se they apply to the Control Room Evacushon Memeenence of Pzr level, using pumps and heelers 3.9 1 074 EK1.02 Knowledge of the operationalimpheshor's of the somewing concepes as they apply to the :, - ,

ooooF4 (W!Eas&EOT) ined Cor. Coahng i M 1 '

% .P M ances d 6 N core. 4.6 1 saW E03 EK1.2 knoweedge of the opershonal imp 4 cations of the haowing concepts se they appe r to the ( in-e-r%

swtoa e subcoonne arg+n na a w 1 subcooang Margin): Normal, abnormel 8 emwgency j operenne prar=6.ee ===ar-a-swm (inadequase subconhng Mergin). 3.8 1 076 AA1.04 Ahmty to operuse ensor monnor the fonowing l acoare H.an n cear Cooient ActiviewiEx 1 es they apply to the High Reactor Cooient ActW Failed Fuel monmaring - ~ ._ . 3.2 1 saw A03 AK1.3 Knowledge of the opershonalimphcehons of the fonounng concepts as they apply to the (Loos of NNI .s swtAnzamos too.or wxtyivs 1 y): Annundesars and condsons, indicenne signals, and remedial amans ,---ra a-aweh (Loes cf NNI-Y). 3.0 1 i K/A Category Totals: 5 1 4 1 4 1 Gfoup Point Total = 16 i

t i

Page 2 i

m i

i PWR RO Examination Outline i Emergency and Abnormal Plant Evolutions - Tier 1/ Group 2 EIAPE # # Name i Safety Function K1 K2 K3 A1 A2 G KlA Topic (s) Imp. Points  ;

001 AK114 Knowledge of the opershonal emphcations of mooct Caetinvovo Rod Weeewe' fI i the RAmn0 concepte so they appy to Conhnuous Rod 5 Wehenswei interacton of ICs contrd steene as wes as purpoop function. and modes of opererion of ICS .

34 1 003 AK103 Knowledge of the opershonalimphcatens of i

'he kAwng concepts as they apply to Dropped Control Tooc3 Drooped cased Rod 7 t 1 Rod Reimionship of g and Rn posser to rod ,

no, ment 35 1 007 EK3 01 Krew eedge of the reasone tar the RAmnng cooconsvwso2aE to. CDEo2) Reector Trp . StatAresen - es they appy to a reactor tnp' Actioris contamed m EOP 1

gee r,at ar reactor tnp 40 1  !

B&W A01 AK31 Knoweedge of the reemans for the wwact Ptent Runeset ti 1 kAmn0 responses se they appy to the (Ptert

[

Runbeck) Facilty crerahng choradonatics 32 1 B&W A04 AA2 2 Atery to determme and interpret the ww.o.T ,t.w r,f ev 1 **=no se they appy to the (Turtene inp1 Adherence to sopropna re procedures and opershon wittwn the l

• meistens m the facety ianee and _ ~-a;. 3.7 1 008 AK3 02 Knowledge of the reseens kr the kW10wrg noooon p,esonre vecer seece amon 4im 1 esponsee on they appy to the Presounter Vaptr Space Acadent Why PORV or code ess ety out temperature a bekm RCS or PZR temperature 36 1 009 EA2 01 Atztity to determine and perpret the tAmno es they appy to e smes Bresh LOCA Actons  !

a00o09 Smesi Dreet LOCAi a 9 to be takert, twesed on RCS temperature and pressure saturered and superheated 42 1

[

011 EK101 Kreweedge of the operationalimphcetions of '

the Ibilowing concepts se they appy to the Large Break  ;

000011 Lyge Brest LOCA t a 1 LOCA featural circulation and coolwg induding reh treng 4.1 1 -

B&W EOS EK2 2 Heat removai systems, retatensh@ '

BVWEoB. WWE03 LOCA Cooneewn#Despose iIV (HPi Ceeedowr1 1 behneen proper operation of these systems to the operaten d the facihty 40 1 B&W E10 EK21 Knowledge of the Honeterons between the (Post-Tnp Statdration) and the fbikwn0 VWE02 st Termtw' ion i a 1 Comgonents and functions of control and safety systems. meiudma instrumentaten . 35 1 i

I l

r f

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PWR RO Ex:mination Outlina Emergenc and Abnormal Plant Evolutions -Tier 1/ Group 2 EIAPE s i Name i Safety Function K1 K2 K3 A1 A2 G KlA Topic (s) Imp. Points 022 AA2 03 'Atary to dWerane and Herpret the TIx'22 Loes W Reetier Cecient Makeup t a hikianrig es they appfy to the Loss d Reacts Coolant ua.ieup redures d fkw onreme va we n or crmtroner 31 1 025 AK3 03 Kimatedge d the reasons for the kAwng rno non as they apply b the Lose d Resadual Heat

,xxxus tese W nun sye,em s iv co.re, Heat syeism) 1 Removal System immediWe actes contamed m EOP tr lose d RHRS 39 1 029 EK3 06 Kroanedge d the reasons for the followmg ixxxne Anwame Treae nrse seremil 1 esponses en they appy to the ATWS Venfymg a uom Turtune tnp. methods 42 1 2 4 4 AbHWy to recognAre abnorma!indcations for system cotio32 toes W Source nerve 4 8 VII operenng parameeers whdi are entry 4ewel mrw!rtens far emergency and ebncrmal operstmg prowdures 40 1 moon tese W warmeo=* asase m , vs 0 037 AA2.16 Abety to determme and everpret the t*wna es they awy to the seem Generator Tube

.xxxur steem Gene < ster Tuee teet t a Leek Pressure at u.*nch to memtam RCS dunno SG orum r, 41 1 038 EA136 Krowtedge d the operatonal unphcabons or j the Ibikwng concepts es they appey to the Steam 6038 Steam sonomsir Tutse Mustum i M Generator Tube Rupture Coutdem W RCS to specfhed tempe sture 43 1 rxxxxW (CEKM) Loos er Wem Foodwest i N l 2 411 Knowledge of abnormal conddon prowdures 34 1 B&W E04 EK12 Knowledge d the operatonal wnphcatens d the Ibnowmg concepts as they appy to 9ME04. WWEM modoquaw Host TrenWer- Lose W Seconeory Host 1 the inadequate Heat Tranneer teormal, abnormal, and S**'"

EOP procedures associs'erf with (tnodequate Heat Transten 40 1 058 AA2 01 Atery to dMermme and Werpret the j hikwng as they apo#y to the Loss of DC Power That a t.m .oc pe et t vt kan d DC power has occurred. venncation that subseture pow r soun:e tee come on line 37 1 059 AK2 01 Knowledge d the interrelatons between the cocow wier si tiquia neovirecie not a ix 1 Accidertal Liquid RadWeste Release end the Ibliowmg Redescerve Iquus morwors 2.7 1 000 AK2.01 Krum.e e dge d the Herretabons between tne

,xxxxq0 Acct $entes Geencue Redeeme Ret itg 1 Accidental Gaseous Radneste Re!ense and the hilowmg ARM system, includmg the riormal radiataan-eves indicerone and the operstwty status 26 1 0

K/A Category Totals: 4 4 5 1 5 2 Group Poent Total = 21 Page 4

PWR RO Examination Outline Emergency and Abnormal Plant Evolutions - Tier 1tGroup3 E/ APE # / hlame / Safety Function K1 K2 K3 A1 A2 G M/A Topic (s) Imp. Points t 000028 Presewirm twel MmNunchon IE O 000036 (9W/A06) Fuel Hamming AccideA iVNI O j

066 AIG02 Knowledge of the reeoons for the foNowng

% fy responess as they apper to the Loss of OffsNe Power-Actons ceremined in EOP for loss of offene power. 4.4 1 000o65 Loss of Instrument Airivu O 88W E13 EA2.2 Absty to determine and interprW the BW/E13&E14 EOP Ruien and Enciaowen 1 following as they apply to the (EOP Rules): Adherence to l appropriate prar-sees and operanon wanin the timitanons in the facaers kwnee and anwndments 3.8 1 88W A05 AA1.1 Abany to operate anWor monRor the 1

• • (

• I*"#Y UWIAoS Emegency DM Actudion f VI Actusuon): compon nes, and funcbons of control and seswy eyesems, heluding instrumentanon, signais, veeriocks, fanure modes, and... 4.3 1 eWiA07 Floodug f Vu 0  ;

CE/A16 Escoes RCS Leekage f E (13035880401 ANO) 1 Puform acsons required for excess RCS leakage 3.0 1 j i

i l

K/A Category Totals: 0 0 1 1 1 1 Group Point Total = 4 r

i Page5 I

PWR RO Examination Outline . _ _ _

Plant Systems - Tier 2/ Group 1 E/ APE # / Name / Safety Function K1 K2 K3 K4 K5 K6 A1 A2 A3 A4 G KIA Topic imp. Points 001 K5.38 Knowledge of the follcwog operationalimphcations 1 as they appey to the CROS: Defins so n of Xenon transet, 001 Control Rod De causes. effects on reactMty 3.5 1 003 K108 Ki,cw f the o physacal w,,w.v., andor 003 Reactor CooW4 Pump 1 cause effect in 4,y. between the RCPS and the fo#kune syvems: r:ortenment isolation 2.7 1 004 A4 01 'AbilRy to manua#y operate and/or rnonitor in the 004 Cbemeni and Volume Cmtros control room: Baron and control rod reactivity effects. 3g g 1

'W 013 Engmeered Sa8ery Features Actuntum (ANO - ESAS) as they apply to the ESFAS: Safety system logic and restitwy.

2.9 1 015 K6.02 Kim f theoeffect of a loss or malfunction on the folkwng d how on the NIS: Discnmhator/ v metaan 015 Nucker instrumentaton 1 circuits 2.6 1 017 A1.01 AtWy to predact and/or monit or changes in 017 Inave Temperature Mrmaor (ANO 1409 ICC Manitor parameters (to prevent expedog desgn limRs) associated g

0,sgdey System) wth operating the ITM system controls including. Core exit temperature 3.7 1 022 K2.02 Knowleoge of power supphes to the fohowmg 022 conwnment c=iing 1 Chiners. 2.5 1 g

056 A2.04 AtMy to p&and mdgate using se cond*"'** procedures loss of condensate pumps 2.6 1 059 A3.07 AtMy to mondor autv, a~ u,m stion of the MFW, 1

059 Mem Fcedwehr Muding' ICS. 3.4 1 061 K4 02 Knowledge of AFW design feature (s) and/or interlock (s) which provide for the fonowing: AFW automatic 061 AuxiharyTmergency Feedwe4er i start upon loss of MFW pump, S/G level, blackout, or safety intection. 4.5 1 068 A4.04 Atmy to manusty operate and/or monitor 'n the 1

068 L6qued Rerfweste controlroorn: Automebcleolaton. 3.8 1 071 A2.02 Atmy to FMand mitgate using peores..

071 Weste Gas Disexmal 1 Use of waste gas release monitors, radetion gas few rate, toestizer 3.3 1 072 K1.04 Knowledge of the physical connections and/or OV2 Area Radiaten Mondonng 1 cause effect retabonships between the RPS and the following systems- control room vent:taten 3.3 1 K/A Categofy Totals: 2 1 0 1 2 1 1 2 1 2 0 Group Point Total = l13 Page 6

PWR RO Examination Outline Plant Systems - Tier 2/ Group 2 ,

i E/ APE # / Name / Safety Function K1 K2 K3 K4 K5 K6 A1 A2 A3 A4 G K/A Topic imp. Points 002 K5.11 Knoudedge of the fosomng operationalimphcotons [

oaz Reector Coosent 1 as they apply to the RCS: Reishonehsp between effects of the prenery cociant system and the secondary cooient syste 4.0 1 !

006 K3 02 Knowledge of the effed that a loss or malfunction 006 Emergency Core Cooling 1 of the ECCS we have on the fonowing Fuel 4.3 1 ;

006 K8 03 Knowledge of the effact of a loss or malfunchon of o6 Enwrgency Core Cooling i the fobowing wE have on the ECCS: Safety Irjecton Pumps 3.6 1 010 A2.03 Absty to (e)preect the impacts of the foNowing l os0 Pressunzw Pressure Cormas 1 mewunchons _ and (b) mlbgete the consequences of. : PORV [

feaures. 4.1 1 ;

011 K4 01 Knoudedge of PZR LCS deesgn foor ure(s) and/or l ost Pressuriser Lees Cormai 1 mtertock(s) which provide for the fonowing- Operation of PZR t hester cutout at low FZR tevel 3.3 1 -

012 K4 01Knoudedge of RPS design feature (s) and/or  ;

012 Reector Protectum 1 intertock(s) which pnwide for the fonoudng: Trip logic when one r channet ooc or in test. 3.7 1 l 014 A2.01 Absty to (e) predict the impacts of the foNowmg ,

014 Rod Posnian Ind. cation 1 meNunctions...and (b) mitigste the consequences of. Loos of reed ownch- 2.8 1 016 A3 01 Abstyto montor automatic nperation of the NNIS  !

ois p* max *we instrument ten 1 system, including: Automenc selechon # NNIS inputs to [

control systemo 2.9 1 ;

026 K1.01 Knowledge of the physical connections and/or a:s Conem.nmeni spre, 1 cause effect reishonships between the CSS and the fo80 wing systems: ECCS. 4.2 1 [

029 A1.03 AbWty to prodd and/or montor changes in 029 Contarnnent Purge 1

" @ P'""' " N '*"5) '"  !

wth opereeng the Containment Purge Systen controis [

ecluding Contammerd preneure, temperature, and hurniday I 3.0 1 033 K4 05 Knowledge of design feature (s) and/or interlock (s) 033 Spent Fuel Pool Cooling I which provide for the fotoudng: Adequale SDM (boron conc.) 3,3 $

035 K4.01 Knowledge of S/GS design feature (s) and/or 03s steem Genereim 1 etertock(s) which provtdo for the foNowing:S/G level control.

3.6 1 l i

Page 7 f

i PWR RO Examination Outline Plant Systems - Tier 2/ Group 2 E/ APE # / Name / Safety Function K1 K2 K3 K4 K5 K4 A1 A2 A3 A4 G KIA Topic imp. Points

- w am sesem 1 039 MS 08 Knontedge of the OPershonal imphcotens es they epgdy to the MRSS: Effect of steem remeral on reactivuy 3.6 1 a56 Condenser Air Removal 0

062 K4 G3 Knowledge of oc estribubon system design as2 AC Elactncel Dewitamon 1 feature (s) enWor interlock (s) which provide for the fotowing Intertoche between automene bue trenefer end breshers 2.8 1 083 K3.02 Knowledge of the effect that e lose of the dc ce3 DC Ekwical Destrammon 1 electical metribullon eyetem we have on the fotowing-componeres using oc control power. 3.5 1 064 A4.0e Absty to manuesy operate enWor mormor in the W En m Deest h 1 mntrol roont Manuel etert,loodmg, and stopping of the ED'G.

3,g g 073 K4.01 Knowledge of PRM design feature (s) enWor oT3 Process Rederion neonnonna 1 riterteck(s) which prende for the following: Reisese terminetton when romanon exceede setpowW 4.0 1 ors cweviating wow o

07s steeion A" 0

086 K6.04 Knowledge of the effect of a lose or malfunchon of oss ri,e praisce,on 1 the fosowing we have on the Fire Protecton Systent Fire, emake, and heat detectore 2.6 1 K/A Category Totals: 1 1 1 6 2 2 1 2 1 1 0 Group Point Total = 18 l I

l Page 8

PWR RO Examination Outline _

Plant Systems - Tier 2/ Group 3 i

E/ APE # / Name / Safety Function K1 K2 K3 K4 K5 K6 A1 A2 A3 A4 G K/A Topic imp. Points j 005 A1.01 AbMy to predict and/or mondor changes in

,  %, %q j parameters (to prevent ese:eedmg design kmas) assocsated with operahng the RHRS cxintrols includog: Heatup and cooldown rates. 3.5 1 005 K4.07 Knowledge of RHRS desgn feature (s) and/or interlock (s) which providc for the following: System protection RW N RM M h ANO) 1 ]

logics, including fwgh-pressure intertock, reset contnws, and vaw interiocks 3.2 1 007 A4.10 AbiNty to manuelty operate and/or mondor in the 007 Pressurver ReHerQuench Tent l control room: Recogntion of leeking PORVAase safety.

3.6 1 he Purpose aM function d rnetw system 00 Component Cooieng Water (iniermediate Cing Wtr - ANO) i wiw m a. and contrds 3.2 1 c27 Contamment todine RM Q

028 K6 01 Knowledge of the effect of a loss or malfunction on 020 Hydrogam Recombmer and Purge Control I the fonowing we have on the HRPS: Hydrogen Recanh 2.6 1 034 Fuel Handhng Equ%merd 034 A3 02 AbMy to monkor automatic operation of the Fuel l

Handfing System, includmg: Load hmas. 2.5 1 041 Steam DumcdTurtme Bypese Contng 0

045 A3.05 AbWy to rnonitor automatic operation of the MT/G 0**"* T"'6'"' G*"* ' I system, includeng: EM Acisuhc control. 2.6 1 j 045 K3.01 Knowledge of the effect that a loss or malfuncbon

04) Mem Turbine Generator 1 of the MT/G system will have on the fdiowing: Remainder of  !

tt'e plant. 2.8 1 073 Sennce Water (and Auxihery CinDWtr. ANO) 076 A4.04 Ability to manually operate and/or monitor in the l

contrd room: Emergency heat loads. 3.5 1 '

078 K4 02 Knowledge of IAS design feature (s) and/or 07Qinstrument An 1 Irier10ck(s) which provide for the fdlowing: Crosseer to other air systems. 3.2 1 103 A3 01 'AbMy to montor automatic operation of the 103 Contamment I containment system, includog cu,w+.: isolation. 3.9 1 1 061 K4.02 ' Knowledge of AFW design feature (s) and/or 1061 Emergency reedwater initiation and Control (ANO) 1 nterlock(s) which provide for the following: AFW automatx:

start w loss d MFW pump. S/M, W, or sWW in,ection. 4.5 1 Page 9

PWR RO Examination Outline Plant Systems -Tier 2/ Group 3 E/ APE # / Name / Safety Function K1 K2 K3 K4 K5 K6 A1 A2 A3 A4 G K/A Topic imp. Points j

050 A3M AtdRytomonAorautomateoperationof the W te wegresed cioeui Sye6em @NO) system, includhe: ICS. 3.4 1 041 Ms.03 K. J4. of the effect of a toes or meNuncnon on

'" N*d SW W 1 the foAmmin0 wm have on me SDS: Centremer and posiboners, incdudina ICS. S/G. CRDS. 2.7 1 012 K1.03 Kncudiedge et the phyecal N and/or tots Deversrund Randor Overpreneurs Precediun System coues esetA reemilenships betwoon the RPS and the fomounno 1

A mesms: CRDS. 3.7 1 K/A Category Totals: 1 0 1 3 0 2 1 0 4 2 1 Group Point Total = 15 b

i Page 10 l

F ,

PWR RO Examination Outline Generic - Tier 3 i

E/ APE # / Name / Safety Function C1 C2 C3 C4 K/A Topic imp. Points 2.s Condun of op-wton. 1 2.1.12 Ab*ty to apply techncers pecificebons for a systm 7,9 3 2.1 Condue d op-wion. 1 2.1.1 Knodedge of conduct of opendions we 3.7 1 d WI ns and N h the fuy I 2.s Condue or op=winn. 1 , 2.7 1 2 2 Equipment Cored 1 2.2.13 KnoMedge of tagging and clearance procedures 3.6 1

'~

E " ' " "

2,2 Equipment Cored 1 3.4 1 sersey hmes 2.2.1 Absty to perform pre-startup procedures for the facddy, 2.2 Equepment Contrd 1 includog operatmg those controis associated wth plant ,

equipment that couid affect reactivity 3.7 1 2 2 Equipmerit Cored 1 2.2.12 KnoMedge of surweence pnnkres. 3.0 1 23.10 Absty to perform procedures to reduce excessabe leveis l 2.3 Radiation Corted of radiation and guard agemst pennonnel exposure 7,g j 2.3.2 Knowiedge 10CFR20 and reisted facWty radinhon contrd .

9 reyements 2.6 1 l

2.3.4 K. ke v= of radeon exposure kmfts and [

1 contaminshon contrd, includeg permisesbie lewds in excess of j 2.3 Radia* ion Cored those authonzed 2.5 1 l 2.4.21 Kr of the A e and toge used to essess ,

2.4 Emegency nd.;n".= 1 the status or safety funcdons including: 2. Core coohng and heet removai 3.7 1 2.4.34 KnoMedge of RO tasks performed outside the main 2 4 Emergency Promduree/Penn 1 contrd room dunng emergency opersbons includog system geography and system imphcstions. 3.8 1 1 2.4 6 Knowledge of symptom based EOP mitigahon strategies.

2 4 Empgency Proceduree/Pten 3.1 1 i

i i

K/A Category Totals: 3 4 3 3 Group Point Total = 13 t

I Page 11

+

t i

L PWR SRO Examination Outline Worksheet i Based on NUREG-1021 Form ES41-3 Pg 23of 39 Interim Rev 8. January 1997 [

K/A Category Points 7dW ##89' Tier Group 0 '

K1 K2 K3 K4 K5 K6 A1 A2 A3 A4 G i

Tier 1 1 5 1 4 16 16 Plant 2 4 2 5 1 1 17 17 Evolutions 3 1 1 1 1 1 1 6 6 i 10 4 10 3 9 3 39 41.5 6.50 3.51 T s Tier 2 3 1 0 1 2 0 2 1 4.5 3 2 1 17.5 17.5

~

Plant 2 1 0 2 4 l2 l2l1 l 4.5 l 1 lwunctiol 2.9 20.4 20.4 systems 1 1 0 1 1 l2 l0l1 l 2.5 l 1 l2l1 12.5 12.5 3 0 4 7 4 4 3 12 5 4 4.9 50.4 50.4 4.58 2.85 ,

To s

___ _ _ Tie [ 3_____ _ m_cLat2_m cat 4 _ _____

Generic 4 4 4 18 18 I I I l -'

I I I I I I I I -

I I I I K/A Totals 13 4 f4 7 4 l 6.5 l 6 20.5 5 l4 l 7.9 107.4 109.9 8.35 5.29 1 i i i l I I I l I I l I

Page 1

PWR SRO Examination Outline _

Emergency and Abnormal Plant Evolutions - Tier 1/ Group 1 __ _ _

E/ APE # 1 Name 1 Safety Function K1 K2 K3 A1 A2 G KIA Topic (s)KIA Topic (s)KIA Topic (s) Imp. Points RO Diff?

r

____._p 4

005 AK2.02 Knowledge of the interrelations between the i 000005 @eMuct Cored Rod Il 1 Inoperabee/ Stuck Control Rod and the following' Breakers. l retsys, desconnects and control roorn smtches. 2.6 1 015 AK3.07 Knowledge of the reasons for the follomng responses as they apply to the Reactor Coolant Pump i 000015/17 RCP DAsMunctes / N 1 Malfunctions (Loos of RC Flow): Ensunng that S/G levels i are contnAed property for natural cerculation enhancement 4.2 1 Y i B&W E09 EK3.3 Knowledge of the reasons for the follomng responses as they apply to the (Natural BW!E09; CE/A13. W/E09&E 10 Natural Circ. I N 1 Circulaton Cooidown): Maniputahng controls to otWain desired results during abnormal and emergency i situshons. 3.4 1 024 AK3.01 Knowledge of the receons for the folioeng 000024 Enwgency Boraton fi 1 responses as they apply to the Ernergency Boration:

When emergency boration 6. required 4.4 1 Y 026 AA2 05 Ability to determine and interpret the f 000026 Loss d Component Coohng WateriVlit (intermochet*

Cohng Water - ANO) i fonowing as they apply to the Loos of Component Coohng Water: The normal values for CCW heeder flow rate and the flow rates to the components cooied by the CCWS. 2.5 1 Y _

000027 Pressunzer Pressure Cored System MaNuncton f IN O _

B&W EOS EK1.2 Knowledge of the operatonal 000040 (BW/E05. CEX05; W/E12) Steam Une Rupture - Excessive

• • 'N

,y 1 (Excessrve Heat Transfer): Normal, abnormal and emergency operahng prwedures associated mth (Excessive Heat Transfer). 4.2 1 CE/Q11; W/EOS RCS Overcoolmg . PTS I N 0 .-

51 AA2 02 AbiNty to och and interpret the following 63d W V m iN 1 as they apply to the Loss of Condenser Vacuum-Conditons requiring reactor and/or turtune inp. 4.1 1 055 EK1.02 Knowledge of the operatonelimplications of 000055 Staten Blackout IVI 1 the foHomng concepts as they apply to the Station Blackout: Natural circutshort coohng 4.4 1 Page 1

' l l l PWR SRO Examination Outline __ _ ,i Emergency and Abnormal Plant Evolutions - Tier 1/ Group 1 EIAPE # 1 Name / Safety Function K1 K2 K3 A1 A2 G KIA Topic (s)KIA Topic (s)KIA Topic (s) Imp. Points RO Diff?

057 AK3 01 Knowledge of the reaams for the folkwng l rep as they appy to the Loss of Wal AC  ;

000057 Loss of Vnal AC Elec inst Bus tVI 1 instrument Bus: Actes contained in EOP for loss of wtal j 4.4 AC electncalinstrumerd bus. 1 062 AA2.01 AtAty to determene and interpret the folkwng  !

000063 Loss d Nuciner Serum Water I N 1 as they apply to the Loss of Nuclesr Serwce Water.

Location cf a leak in the CCWS. 3.5 1  !

067 AA2.17 Atnity to determine and interpret the fonowing -~!

000067 Plard Fire On-sda f IX 1 as they apply to the Piant Fire on Site: Systems that may f be affected by the fire. 4.3 1 1 21.8 Atwity to coordinate personnel actmties outside the ~i 1

000068 (BWI A06) Cordrol Room Evac I Vin control room. 3.6 1 Y  !

-t 000069 (WT14) Loss of CTMT Intgnty IV 0 __ ._

074 EK1.02 Knowledge of the operationalimplications of the f H wing concegs as my awo N inadequate  ;

00007c(WtonE07pnad cor cmding t w 1 Core Cooling. Potential consequences of uncovenng the -

core. 4.8 1 B&W E03 EK1.2 Knowledge of the operational i imphcations of the following concepts as they apply to the  !

BW/E03 inedequate Sut.codmg Margin I M 1 ( Inadequate Subcoding Margin): Normal, abnormal, &

emergency operahng procedures associated with (inadequate Subcochng Margin). 4.0 1 076 AA1.04 At2ty to operate and/or rnonitor the folkwng 000076 High Ree +ar Contant Activ#y IIX 1 as they apply to the Hgh Reactor Coolant Actmty: Failed Fuel monitonng equipment 3.4 1 B&W A03 AK1.3 Knowledge of the operatonal implications of the following concepts as they apply to the SWIAGMA03 Loss of NNS-X/Y / w 1 (Loss of NNI-Y): Annunciators and condhons, indicating signals, and remedial schons associated with (Loss of NNl-Y). 3.3 1 K/A Category Totals: 5 4 1 4 1 Group Point Total =

1 l16 4, Page 2

PWR SRO Exrminstion Outline __

Emergency and Abnormal Plant Evolutions - Tier 1/ Group 2 -_

ElAPE # # Name iSafety Function K1 K2 K3 A1 A2 G KIA Topic (s) Imp. Points RO Diff?

001 AK114 Knowledge of the opergsonal emphcatens d

.xicoot Conemaove Roe withdrawal # 1 1 the folkwng concepts as they apl# to Contwiuous Rod Withdrawel Interadion of ICS control stations as weil as purpone functen. and modes of opera on d ICs 37 1 003 AK103 Knowiedge of theigeratonal emphcatens of x)occ3 Oropped Corest Rod il the followmg concelta as they aWy to Oropged Control 1

Rod. Relatenship of reedMty and Rx power to rod movement 38 1 007 EK3 01 Knowiedge of the remnone kr the biiowmg

<nooor tevwEo24E 10, CEFEOa Reechw Trp . Stoomrem a .

1 as they aMy to a reedor tnp Adens contamed in EOP escowv it br ,eedor enp 46 1 B&W A01 AK31 Knowledge of the reasons kr the eqpwAct Pient Runbectiil Rureeck) Facsiity opera *mg J- .: a . 34 1 026 AA2 05 Atwhty to determme artiinterpret the bliowang as they apply to the Lose of Componert ewwAos teinp # w 1 Coohng Water. The normal vetuse kr OCW bender now rate and the flove rates k)the components coated try the  !

ccws 25 1 Y ex)os pressunser veper Space acceerti m 009 EA2 01Atzhty to determme and interpret the '

bliowmg as they apply to a Smas Breek LOCA Actons Joaco9 Smen erset LOCA Ie 9 mM mM ure W Am I saturate and supe heated 48 1

~

011 EK101 Krowiedge of the operatonalimphcations of the Ibliovang cxmcepts as they apply to the large Break i xxiott Ls ge eneet LOCA f a 1 LOCA Natural crculaton an$ conhng, including 'enux ,

bodeg 44 1 vwEos toca oumee Canis- t = 0 98W EOS EK2 2 Heat removal systems, relatenship  !

ewwEn mo3 tocA Cooeao-coprese s er(wei Comesown) 1 wweer proper operaten of these systems to the westen or the facitity 40 1 +

vwEt t toes er Emergency Coetent Rectr=. # w 0 B&W E10 EK21 Knowledge of the inteneistens between the (Post-Trip Statni zation) and the pollowmg WrE02 St Terminemm f a 9 ,

Components and h of contid and @

systems, mckong recrumenemon .. 40 1

+

022 AA2 a3 Atuhty to detemne and eterpret the mn2 t- et R=ex Coi!' eat woneup 8 s 1 [

biiovano as they appey to the tone of Reactor Coolant wakeup Fanures or now contrai veeve or controner 36 1 Page 1

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PWR SRO Examination Outline l 1

Emergency and Abnormel Plant Evolutions -Tier 1/ Group 2  !

- )

ElAPE # # Name i Safety Function M1 K2 K3 A1 A2 G KAA Topic (s) Imp. Points RO DWr?

025 AK3 03 vmenades of the femmons ear the bewng

=ponen a they epidy e > > d w Het [

moomose a nHn s,com, w toecer Heat syenemi 1 Removal SyWem : Immoewe emano contamed in EOP

~

br lame of RHRS 4.1 1

{

029 EK312 Knoudedge af the teemans for the tasomng t cono2e aMiteetse Trenennt use serem # e 1 roeponses se they appey to the ATWS Acsons  !

contemed in EOp br ATws 4.7 1 Y  :

I i

100o32 tres W Sawte mense M in l

0 RO only  ;

e Losew:_ - nonee = # n O 03T AA2.16 Alnwy to outermme and sterpret the t knowmo se they apply to the !bmem Genormaar Tube f i moost sisem cene em, tune tua a e 1 Least Preneure et which to meenen RCS damng SG [

cooidown 43 1 [

038 EA1.36 %W of the opershonalimpbcatione of f

]

accom seem con.,es, rue,e nupews # e 1

"'"""'"8""""""Y'N""8'"*  !

Generator Tutie Rupture N*hert d RCS to egoceed w 45 1 f fW aooose tCEKoF) Lane W toen F- D RO only

! 84W E04 EK1.2 Knoededge af the operational erwEos, wwEoS ; Heat Trenesse - Lose er seconsuey Heat 1 the inadequee Heat Tm Normai, samarmat. and

"'" EOP procedures uth (In=m=y=m= Host Transfer) 42 1 058 AA2 01 Atzwy to entsemme and meerpret the bno-no se my appsy e m m W oc w That a

"**'"'#DC " '" 1 kne of oc posee hoe cacuned, wrecemon that sutisteute poser soumos home came an ene 4.1 1 j ocoose acce.enw teo ue medvvise em a m O I

omoso accesentei r:- medussee net i fx 1 '080 AK3 01 Knowtedes of the smoons br the sanomeg moponnee se they apply to the Accsdental Geneous Rossesse Reisame :. - . of the Epen 42 1 Y oomsi anw s,com amane e va 0 wwEse me comee -e noe mm # m 0 ,

u m Funeenne e m O KIA Category Totsis: 4 2 5 1 4 1 Group Point Total = 17 3 i

Page 2

i l 1

PWR SRO Examination Outline _

Emersiency and Abnormal Plant Evolutions - Tier 1/ Group 3 E/ APE #I NameISafety Function K1 K2 K3 A1 A2 G K/A Topic (s) imp. Points RO Diff?

~~

i o00028 Pressurtnw Level MmNuncta1 N O  ;

B&W A06 AK1.3 Krwudedge of the opershonal wnoncehens of the foNoudng concepts as they apply to the t soonas (eW/ Ace) ruet H=ndkas a ccident iW 1 (p % % w % p w , %

and emergency opereung procedures sesociated weh (Refue6ng Canal Level Decrossen. 40.0 1 Y ,

056 AK3 02 Knoudedge of the reasons for the fotommng f 0""58 '"** "' " - * * * " " ' ' " l responses as they apply to the Loos of OffsMe Power:  !

Achone contemed in EOP for loss of offsee power. 4.7 1 l

ocoonsLee atinstnnnent Aniw 0 t

026 AA2.05 AbENy to determne and interpret the BW/E13&E14 EOP Rules and Enclosures 1 kNeunng as they apphlo the Laos of Component Coohng  ;

Weser The normal values for CCW header flow rate and the now raies in the componentsw by the cCWs. 2.5 1 I i

B&W A05 AA1.1 Absty to operate andMr mondor the

j fotowing as they appy to #w (Enwrgpincy M BW M E m W h N Actuohon)

Components, and funchons of control and schly systems, % instrumentshon, wgnels, reertocks, feihne modes, and. 4.2 1  !

I B&W A07 AK2.2 Knoudedge of the interreishons l g between the (Flooding) and the fogowing: FacMitys host BWIA07 Flooding iVfR

cooient, the decer heat remover systems, and reishans  !

behusen the proper opershon. .. 3.3 1 Y CEOS6 Excess RCS Leenage / N (Imman401 ANO) 0 RO only [

WQ13 Steem Generator Over-pressure / Rf 0  !

! W/E13 Cortsenment Flomhns 1V 0 j

+

130357e0401 Natural Emerganaes (ANO) l 2.4.12 Knowledge of abnormal condibon procedures 3.6 1 Y K/A Category Totals: 1 1 1 1 1 1 Group Point Total = 6 3 j i  !

r Page 1 j

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i i

PWR SRO Examination Outline _ _ _ _

Plant Systems - Tier 2/ Group 1 __

E/ APE # 1 Name I Safety Function K1 K2 K3 K4 K5 K6 A1 A2 A3 A4 G KIA Topic Imp. Points RO DIFF7 001 K5 38 Krm4 edge of the fonowng operational ~T oot co,w am 1 mphcatons as they anvey to the CRos: Deronson of xenon transient; causes, effects on reactrvny. 4.1 1 003 K3 05 Knowtedge of the effed that a loss or malfunction of the RCPS wWl heve on the fonomng: ICS.

3J 1

[ _

004 A4 02 'Abitay to manuapy operate and/or rnontor in the coa cneixae a vs voiume cow 1 control room: Calculaton of ECP and related borston/dilutxwVreacfrvity relationships. 3.9 1 Y 013 K5 02 Knowtedge of the fonowing operational 013 E rprwered Sa rety Features Actuaton (ANO . ESAS) 1 mphcatons as they appy to the ESFAS: Safety system logic and reahtahty. 3.3 1 m5 Wricar instwaton to the Loss of Component Cooling Wat 2.5 2.5 {o onty))

017 A1.01 Abdity to predd and/or monitor changes in 017 in<:cm Temperature Monent CCC uondor Dway system . j parameters (to prevent exceedng desgn kmits) associsted QND) wth operatog the ITM system controls including Core extt temperature. 3.9 1

~ -~

014 A2.07 Abday to (a) predd the irnpacts of the fonowing 022 Conta.nrnent Cwwg 1 maNunciens.. and (b) megate the consequences of: Loss of reed switch. 2.9 1 Y_

02s ka condenser 0 __ _

056 Condensate RO only 059 A3 07 Abdity to mondor autometr: operation of the MFW.

050 Cbn Feedwate' including- lCs. 3.5 1 061 K4.02 Knowledge of AFW desgn fea+ure(s) and/or interlock (s) which provide for the foPowing: AFW automate C31 Quarivary/Emegency Feedwe'e' I start upon loss of blFW pump, SK) level, blackout, or safety insectort 4.6 1 2.3 3 Knowledge of SRO responsibihtees for auxihary systems 338 LCauai Redweste 1 that are outside the control room (e g , waste disposal and hand %ng systems) 2.9 1 Y 071 waste Gas Dwvmad 0 RO only 072 K1.04 Knowledge of the physical connectons and/or 072 Drea RMatun Monitonng 1 cause effed relationships between the RDS and the fonowmg systems- Contros room ventiistion 3.6 1 K/A Category Totals: 1 0 1 1 2 0 1 2.5 1 2 1 Group Point Total = 12.5 4 Page1

PWR SRO Examination Outline __ _

j Plant Systems - Tier 2/ Group 2 l E/ APE # 1 Name 1 Safety Function K1' K2 K3 K4 K5 KG A1 A2 A3 A4 G K/A Topic imp. Points RO_D_iff? __

002 K511 Knowledge of the fbliowmg operational epications as they apply to the RCS: Rela +ionship between 002 Reactor CMart I effects of the onmary coolant system and the secondary coolant system 4.2 1 006 K3 02 Krmwledge of the effect that a loss or malfunction OG3 Eme9mcy C<we Cmiwg 1 of the ECCS will have on the following Fuel 4,4 j

___L. _

006 K6 03 Kntwiedge of the effect of a loss or malfunction CI3 Emergency Core Cawng 1 on the fonowmg will have on the ECCS. Safety Inrsction pumps 3.9 1 010 A2. 03 Abdity to (a)predct the impacts of the following 010 pmiounter Pressure Corcos 1 maNundens... and (b) mNigate the consequences of...

PORV fadures 4.2 1

~ ~

011 A2.11 Absty to (a)predct the mpacts of the followng ot t p.essunzer Level Cor*us to the Loss of Component Cooling Wat 2.5 malfunctons.. and (b) mitigate the consequences of...

Failure of PZR levelinstrument -low 3.6 2.5 Y_ _ __

012 K4 01 Knowledge of RPS design feature (s) and/or 012 Reactor Poectm 1 'nterkck(s) whch provide for the followng: Tnp loge when one channel ooc or in test 4.0 1 014 A2 07 Abnity to (a) predd the impacts of the follomng 014 Red Posman tr@caten 1 maWunctens...aM (b) mitigate the consequences of. Loss of L reed e*'tch- 2.9 1

- ' ~ ~ ~ ~

016 A3 01 Abtifty to .i.v.aor automate operation of the 016 Newiucieer instrumertaten 1 NNIS system, inclJdmg: Automate selection of NNIS inputs to contros systems 2.9 1

~~~

026 K1.01 Knowledge of the physcal connections and/or 026 Centaurent Spray 1 cause effect relatmnatups between the CCS and the following systems ECCS. 4.2 1 029 A1.03 Ability to predict and/or monitor changes in parameters (to prevent exceeding design hmits) associated l 029 Centariment Purge with operating the Containmert Pu ge System contrcds i, including: Containment pressure, temperature, and humidy 3.3 3 033 K4.05 Knowledge of design feature (s) and/or entertock(s) 033 Spent Fuel Paul Ca*ng I which provide for the foRowmg Adequate SDM (boron conc.)

3.3 9 i

2.1.7 Ability to evaluate plant performance and make oss steerri Generator 1 operational judgments based on operating characteristcs, reactor behavior, and intrument interpretation.

4.4 1 y l

Page 1

u.

PWR SRO Examination Outline ___

Plant Systems -Tier 2/ Group 2 _

E/ APE s 1 Name 1 Safety Function K1 K2 K3 K4 K5 K4 A1 A2 A3 A4 G KIA Topic Imp. N RO Diff? . _ .

4 030 K5 08 Knowledge of the opershonalimphcahone as they 039 Men and Re*wst Steeat l apply to the MRSS: Effect of steem removal on reactMiy 3.6 1 053 Condenser Ar Remowel 0 ~~'

062 K4.10 Knonteege of ac distribuhon system design i 083 AC EhrencW Detreutum 1 We) ardor intenock(s) which prende for the foNowing uruntemeemse ac power sou cos 3.5 1 y 063 K3 01 Knowledge of the effect that a loss of the de 063 OC Enctncat Detntahan 1 electncal detnbubon system we have on the foNoamg-EDG 4.1 1 Y ~~

064 A4.06 Abimy to manuesy opersh! arwor monnor in the 064 Emergency Desel Geneestor 1 control room- Manuel etert, toedng, and stopping of the EDO. 3.9 1

~

073 K4.01 Knowledge of PRM design feature (s) erWor 073 Pmcese Rasaten Montonng 1 intersock(s) which pnMde for the foRowing: Reteeee tenm when redneson esomede eespomt. 4.3 1 073 Ceing We'e' O 079 Stann Ar 0 086 K6.04 Kmwledge of the effect of a loor or me!funchon of a the fonowing win heve on the Fire Protechon System: Fre,  ;

086 Fn Protection 1 emake, and heat % 2.9 1 t

K/A Category Totals: 1 0 2 4 2 2 1 4.5 1 1 1 Gfoup Point Total = 19.5 4 I

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_ _ _ _ _ _ _ _ _ _ . . . _ _ _ . . . _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ ________....______._m_ _ _ _ _ _ _ _ _ . _ _ _ . _ _ . _ _ _ _ . _ . _ . _ _ _ _

PWR SRO Examination Outline Plant Systems - Tier 2/ Group 3 -

E/ APE # / Name I Safety Function K1 K2 K3 K4 K5 K6 A1 A2 A3 A4 G K/A Topic imp. Points 005 A101 AbsNey to predict and/or monitor changes in .

parameters (to prwent onceeding design brruts) sesociated I QS Rendual Heat Removal (DPC8y Heat ANO) I with coerstmg the RHRS controts inceudog Hestup and f cooksown rue . 3.6 1

_ [

.005 K4 07 Knowledge of RHRS design feature (s) and/or I meeriock(e) which provide for the fotowing System protection 05 Res4uel Heat Removal (Decay Heat - ANO) 1 W, reset controis, and vesve intertocks. 3.5 1 t

007 A4.10 AbiNty to rnenuesy operate and/or morwtor in the j G7 Ressunm WN T*'* l control room: Recognihon of leelong PORV/ code safety.

i 3g j f 008 A3 08 Abinty to monitor automatic opershon of the f os component coc*ng water (intermeinte one wir - ANO) I ccws,inesuens Automatic actone associateo wth the i CCWS that ca:ur as a remut of a esfory infecten sW 3,7 j {

027 Cantonment todme Removai 0  ;

028 K6 01 Knowledge of the effect of a loss or maffuncton i 028 Hycogen Remmtwe and Rage Contml 1 on the foNowng wiE have on the HRPS: Hydrogen ,

Recomtuners 3,1 1 l

~ ~ ~

014 A2.07 Abdity to (a) predict the impede of the foRowng 034 Fue4 Handing Equipmert 1 malfundens...and (b) megate the consequences of; Loos of  !

reed outch. 2.9 1 i 034 A2 02 Abihty to (a) predict the impects of the followmg  !

034 Fuet Handimg Equenent 1 meNunciens...and (b) megate the consequences of : f' cropped caek. 3.9 1 y 041 steem CLmmstwne Ness Connal 0 045 A3.05 Atmlety to monitor automatic operaten of the MT/G 005 Osm Tu osnr Cercator system, inciuding: Electrohydraube eartros. 2.9 0 RO ONLY ,

045 K3.01 Knowiedge of the effect that a loss or malfunction 5 m Tm w j of the MTlG system wlR have on the followmg Romander of the plant. 3.1 1

[

l 076 A4.04 Ability to menuelly operate and/or monitor in the 076 Sennte Water (and Aux 9ery Ong Wtr - ANO) 9 control room: Emergency heat toeda. 3.5 1 g

2.1.28 Knowtedge of the purpose and functon of maior system components and coreois y 3,3 3 103 A2.05 Ability to (a)presset the irnpects of the following 103 Carasnmen: 1 malfunctens_.and (b) megate the consequences of-.:

Emergency contammere entry. 3.9 1 Y t Page 1 i

_ _ . _ - - _ _ _ - _ _ _ - _ - _ - _ _ _ _ - - __ -____ _ _ - _ .-- _ - - _ _ D

I I I I I I I I I I I I 'l I <

PWR SRO Examination Outline - _ _ _

Plant Systems - Tier 2/ Group 3 E/ APE # 1 Name 1 Safety Function K1 K2 K3 K4 K5 K6 A1 A2 A3 A4 G KIA Topic imp. Posnts RO Diff?

061 K4.02 Knowledge of AFW doelen feature (s) eruror insertoce(e) which provide ser the sesowing: AFw musomatic 1069 Emergency Feedmeter treaton arid Contrd (ANO) l etert upon lose of R$FW purnp, StG level, beideout, or sehty .

p 4.6 '1  !

059 A3.07 Absty to montor adometc opershon of the MFW wr2 ireogreted cered syWem (ANO) 1 system, inche3ng: ICS. 3.5 1 i

041 Ms.03 Mnowisdpe et the enact et e ions or mewunchon m3 IrnogrWed Cor*d SyWem (ANO) l '" I" I'*U"'"E * '"** I '"* "

.sosaionere inciumne ICs. ssG. CRDS. 2g j 012 K1.03 Knomeedse of the phyenced connochone ensor 1010 Diveraned Reector Overpressure Prceedian System j cause enact relatenships behusen tie RPS and the following (ANO) swetems: CRDS. 3O I K/A Category Totals: 1 0 1 2 0 2 1 2 3 2 1 Group Poird Total = 15 3  ;

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i PWR SRO Examination Outline Generic - Tier 3 E/ APE # / Name / Safety Function C1 C2 C3 C4 KIA Topic imp. Points RO Diff?

2.1 condue a openmon. 1 2.1.12 Absty to apply techncal specticatens for a system 4.0 1  !

2.5 condoa a op-.mm. 1 2.1.1 Knastedge of conduct of opwalmns W. 3.8 1 l 2.1.1o Knowledge of condemns and imimeons in the facmiy  !

2,%, 4 iianee. 3.9 1 2.1 Conduci a op-wen. 1 2.1.u W oness = one tour meanical e schon statements for systems 3.8 1 Y 2.2 Emupn=nt contrd 1 2.2.13 Knowledge of taggmg and clearance W us 3,g 3 ,

M knwhng coni bons opershons and '

2 2 Equipment Cored 1 safety umets. 4.1 1 .

2 2 Equipn=nt conted 1 2.2.H W W em m h consomns ownpwary changes 3.4 1 Y ,

• * * # l 2 2 EeW Control 1 fimeng cond*ons for operabans and aefety limits. 3.7 1 Y '

.A A ly pm n1 p e res % duce % M 2.3 Radiation Control 1 of redinhon and guard agamet personnet - pn-.==

3.3 1 2.3.1 Kn wiedge 10CFR20 and related fac4ty redishon control 2.3 Rah W 1 r*tuimments 2.9 1 &

2.3.4 Knowledge of radaten exposure brnes and 2.3 Radiation Contrd 1 antammemon contrd, including @ . * ' levWs in emmes of those authorized 3.1 1

. M he rW fW twawing and 2.3 Radiation Control 1 N Puntas 3.1 1 y I

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_ _ _ _ - - _ _ - - - _ . - _ - . . - _ _ _ . _ _ _ _ _ _ _ - - - ---__.__ _-__- - _ . _ - _ _ _ _ _ _ <__ _ - _ . - _ _ _ . _ - _ _ _ _ _ - - _ _ _ _ _ _ . . _ - - . . - _ _ - _ _ - _ . - _ _ _ - - _ -- , _ _ - _ _ . _ _ --_.-s

PWR SRO Examination Outline Generic - Tier 3 E/ APE # / NameISafety Function C1 C2 C3 C4 KIA Topic imp. Points ,

2.4.21 Knowledge of the parameters and kqpe used to aseems 2.4 Emmgency Pramduroseen 1 the statue of safety funchons including: 2. Core cooNng and heet renwel 4.3 1 2.4 Emegancy Pnxadures/Phm 1 4.6 1 Y 2 4 Emngency Pnxsdureseen 1 2.4.6 Knowledge of symptom bened EOP mmgebon straleyes 4.0 1 t t

2.4 Emngency Pnxadureseen 1 2.4.29 Knowledge of the emergency pion. 4g y 1 t 2.4.41 Knowledge of the emergency schon level thresholds 24E mwm 1 and closemcenons 4.1 1 Y ,

2.444 Knowledge of emergency plan protectwo acten 2 A Ernagency Pramdunmean 1 recommendehont 4.0 1 Y I t

K/A Category Totals: 4 4 4 6 Group Point Total = 18 18 8 r

i i

Page 2

ES-301 IM"idual Walk-Through Test Outline Form ES-301-2 i

Facility: Arkansas Nucleas.Qae Date of Examination:

Exam Level (circle one(R0 PRO (l) / SRO(U) Oparating Test No.: ._1 System / JPM Title Type Safety Planned Follow-up Questions:

Codes

• Function K/A/G-Importance- Description

1. ANO-1 JPM-RO-AOP21 D lil a. 006 K5.04 2.9/3.1 Knowledge of the operational Align Aux Spray during forced flow cooldown. implications of the following concepts as they apply to P A w tor

)' ECCS: Brittle fracture, includng causes and preventative R Pressure Etions.

A Control b. 006 K1.04 2.7/2.8 Knowledgeof thephysical connections and/or cause-effect relationships between the ECCS and the following systems: Auxiliary spray system.

2. ANO-1-JPM-RO-EFWO2 D IV a. 061 A1.02 3.3/3.6 Ability to predet and/or monitor Manual control of P7A. changes in parameters (to prevent exceedng design limits)

P Heat associated with operating the AFW controls includng: S/G R Removal p,,,,yr,

b. 061 K5.013.6/3.9 Knowledge of the operational implications of the following concepts as they apply to the AFW: Realtionship between AFW flow and RCS heat transfer.

3. ANO-1-JPM RO-ED012 0 VI a. 062 A3.03 2.3/2.3 Ability to monitor automatic operation inverter startup with load on altemate source. of the AC dstribution system,includng: Adequate P Electrical transformer / inverter operation.

b. 062 K5.03 2.4/2.6 Knowledge of the operational implications of the following concepts as they apply to the AC dstribution system: Principles involved with paralleling between two ac sources.

4. ANO-1-JPM-RO-RBC01 D V a. 022 A3.014.1/4.3 Ability to monitor automatic operation Maximize RB cooling. RT9. of the CCS,includng: initiation of safeguards mode of S CTMT operation.

Integrity b. 022 A4.04 3.1/3.2 Ability to manually operate and/or monitor in the control room: Dampers in the CCS.

5. ANC-1 JPM-RO-AOP18 M IV a. 005 K4.07 3.2/3.5 Knowledge of RHRS design feature (s)

Perform etions forloss of DHR. Heat and/or interiock(s) which provide for the following: System S

protection logics, includng high-pressure interlock, reset Removal controls, and valve interlocks.

L b. 005 K3.013.9/4.0 Knowledge of the effect that a loss or malfunction of the RHRS will have on the following: RCS.

6. ANO-1-JPM-RO-CRD02 D I a. 001 K4.02 3.8/3.8 Knowledge of CRDS design feature (s)

Transfer Group i to A6x Power Supply. and/or interiock(s) which provide for the following: Control S Restivity rod mode select control (movement control).

b. 001 A2.20 2.6/3.6 Ability to (a) predct the impacts of the following malfunction or cperations on the CRDS and (b)

., based on those predctions, use procedures to correct, control, or mitigate the consequences of those malfunctions or operations: Isolation of left coil on affected rod to prevent coil bumout..

Facility: Arkansas Nucles Qae Date of Examinadon:

Exam Level (circle one(RO,/)RO(l) / SRO(U) Operating Test No.: _1 System / JPM Title Type Safety Planned Follow-up Questions:

Codes

• Function K/A/G -Importance- Description

7. ANO-1-JPM-RO-AOP25 N Vill a. 008 K1.02 3.3/3.4 Knowledge of the physical connections Respond toloss ofloadcenter B2.

and/or cause4ffect relationships between the CCWS and Rant the following systems: Loads cooled by CCWS.

Service b. 008 A3.02 3.2/3.2 Ability to monitor automatic operation System of the CCWS, includng: Operation of the CCW pumps, includng interlocks and the CCW booster pump.

8. ANO-1-JPM-RO-EDOO9 D VI a. 062 A1.013.4/3.8 Ability to predet and/or monitor Shift buses to a S/U transformer during a changes in parameters (to prevent exceedng design limits)

S Electrical SGTR. associated with operating the AC dstribution system controls includng: Signifcance of D/G load limits.

A b. M7 A2.013.4/3.9 Ability to (a) predet the impacts of the ici ..g malfuncbon or opersbons on the AC dstribution syr& a and (b) based on those predcbons, use procedures to correct, control or mitigate the conaary wees of those malfunctions or opersbons: Types of loads that, if doenergized, would degrade or hinder plant operabon.

9. ANO-1-JPM-RO-RPS01 0 Vll a. 012 K4.06 3.2/3.5 Knowledge M RPS desgn feature (s)

Race RPS channelin Manual Bypass. g andfor interiock(s) which provide for the following: Automatic andfor manual dsable of RPS trips.

Instrumen- b. 012 K2.013.3/3.7 Knowledge of bus power supplies to tation the following: RPS channels, ceiipen6nts, and interconnections.

10. ANO-1-JPM-RO-EOP20 D li a. 004 K6.313.1/3.5 Knowledge of the effect of a loss or Initiate full HPl.

malfunction on the following CVCS cunvi,-its: Seal S Inventory injecbon system and lirnits on flow range,

b. 006 K6.03 3.6/3.9 Knowledge of effect of a loss or malfuncbon on the following will have on the ECCS: Safety injection Pumps Backup - None of the JPM's are repeated on the other operating test (except RPS01), use one of the JPM's from the other operating test.

I

• Type Codes: (D)irect from bank, (M)odified from bank, (N)ew, (A)lternate path, (C)ontrol room, (S)imulator, (L)ow-Power, (P)lant,(R)CA

ES-301 Individual Walk-Through Test Outline __

Form ES-301-2 Facility: Arkansas Nuclear One xamination:

Exam Level (circle one): ROlSRO(l) O perating Test No.: _1 System / JPM Title Type Safety Planned Follow-up Questions:

Codes

• Function KING-Importance- Description I 1. ANO-1-JPM-RO-AOP21 D I!! a. 006 K5.04 2.9/3.1 Knowledge of the operabonal l Align Aux Spray during forced flow cooldown. liiWUcr4 of the following concepts as they apply to P Reactor l ECCS: Brittle fracture, includng causes and preventatrve R da A Pressure b. 006 K1.04 2.7/2.8 Knowledge of the physcal l

l Control connections and/or cause-effect relationships between tre j l ECCS and the following systems: Auxiliary spray system.

l

2. ANO-1-JPM-RO-ED012 D VI a. 062 A3.03 2.3/2.3 Ability to monitor automatic operaton Inverte* start @ with load on altamate source p w of the AC dstrbubon system,includng: Adequale transformerAnverter operatxm.

b. 062 K5.03 2.4/2.6 Knowledge of the opershonal imphcotions of the following concepts as they apply to the AC datnbubon system Principles involved with paralleling between two ac sources l

3. ANO-1-JPM-RO-AOP18 D IV a. 005 K4.07 3.2/3.5 Knowledge of RHRS design feature (s)

Perform actions forloss of DHR. and/or interiock(s) which prowde for the following: System S Heat protecbon logics, includng high-pressure interlock, reset Removal controis, and valveinterlocks L b. 005 K3.013.9/4.0 Knowledge of the effect that a loss or malfuncbon of the RHRS will have on the following: RCS.

4. ANO-1-JPM-RO-AOP25 N Vill a. 008 K1.02 3.3/3.4 Knowledge of the phywcal connections to W WW B2. '

and/or cause4ffect i_- 7,# 44 between the CCWS and Pant the following systems: Loads cooled by CCWS.

I Serwoe b. 008 A3.02 3.2/3.2 Ability to monitor automatic operation  !

System of the CCWS,includng: Operation of the CCWpumps, includng interiocks and the CCW booster pump.

5. ANO-1-JPM-RO-RPS01 D Vll a. 012 K4.06 3.2/3.5 Knowledge of RPS design feature (s) j Place RPS channelin Manual Bypass. and/or interlock (s) which provide for the following: Automatic 3

and/or manualdadAe of RPS trips.

Instrumen- b. 012 K2.013.3/3.7 Knowledge of bus power s@phes to tation the following. RPS channels, components, and interconnections.

Back@ None of the JPM's are repeated on the other operating test (except RPS01), use one of the JPM's from the other operating i test.

I

• Type Codes: (D)irect from bank, (M)odified from bank, (N)ew, (A)lternate path, (C)ontrol room, (S)imulator, (L)ow-Power, (P)lant,(R)CA 1

ES-301 Individual Walk-Through T:st Outline Corm ES-301-2 Facility: Arkansas Nucl= nne Date of Examination:

J Exam Level (circle one(RO / R0(l) / SRO(U) Operating Test No.:_2 System / JPM Title Type Safety Planned Follow-up Questions:

Codes

• Function K/NG-Importance- Description

1. ANO-1-JPM-RO-AOP03 D IV a. 061 A1.02 3.3/3.6 Ability to predet and/or monitor .

Altemate SDN, CBO #2 Follow up changes in parameters (to prwent exceedng design limits)

P Heat l associated with operating the AFW contrds includng: S/G j pressure j duties: Sect.1D, Operate P7A manually. R Removal L. 061 K5.05 2.7/3.2 Knowledgeof theoperabonal implications of the following concepts as they apply to the

, AFW: Feed line voidng and water hammer

2. ANO-1-JPM-RO-EDG10 D VI a. 064 K1.04 3.6/3.9 Knowledge of the physical EDG #2, No DC start.

mm andforM@elaW km h EDIG system and the following systems: DC dstribubon system._

P Electncal b. 064 K4.05 2.8/3.2 Knowledge of ED/G system design feature (s) and/or interiock(s) which provide for the following:

Incomplete start relay.

3.ANO-1-JPM-RO-AOP08 D  !! a. 068 AK3.09 Knowledge of the reasons.for the following Perform RO #1 duties for Altemate SDN in responses as they apply to the Contrd Room Evacuation:

P RCS penthouse Transfer of the following to local contrd: charging pumps, Inventory charging header flow contrd valve, PZR heaters, and boric acid transferpumps

b. 068 AK3.12 4.1/4.5 Knowledge of the reasons for the following responses as they apply to the Control Room Evacuebon: Required sequence of acbons for emergency evacuation of contrd room.

4. ANO-1-JPM-RO-CF002 D V a. 006 K5.02 2.8/2.9 Knowledge of the operational Calculate feed & concentration for , implications of the following concepts as they apply to CTMT maketp to 'A' CFT. ECCS: Relationship between accumulator pressure and volume.

S Integrity b. 006 A1.13 3.5/3.7 Ability to prodct and/or monitor changes in parameters (to prevent exceedng design limits) associated with operating the ECCS contrds includng:

Accumulator pressure (level, boron concentration).

1

5. ANO-1-JPM-RO-AOP26 N 11 a. 004 K3.02 3.7/4.1 Knowledge of the effect that a loss or

]

malfunction of the CVCS will have on the following: PZR RW to Loss of thtw B6 LCS.

S RCS b. 004 K4.03 2.8/2.9 Knowledge of CVCS design feature (s)  ;

inventory and/or interlock (s) which provide for the following:  ;

Protection of ion exchangers (high letdown temperature wil isolateion exchangers)

Facility: Arkansas Nucinr one Date of Examination:

Exam Level (circle one(R0 /)R0(l) / SR0(U) Operating Test No.:_2 SystemlJPM Tide Type Safety Planned Follow-up Questions:

Codes

• Function K/A/G-Importance - Description

6. ANO-14JPM-ROL- ED001 D VI a. 062 A2.013.4/3.9 Ability to (a) prodct the impacts of the  !

Energize A2 from EDG #2 in Degraded f liowing malfunction or operations on the AC dstribubon S Electrical Power. system and (b) based on those predictions, use procedures to conect, control, or mitigste the consequences of those malfuncbons or operations: Types of loads that, if de-energized, would degrade or hinder plant operation.

I B. 062 K1.04 3.7/4.2 Knowledge of the physical connections ardor cause.effect relationships between the AC dstribution system and the following systems: Off-site 4 power sources  !

7, ANO-1-JPM-RO-DHR03 0 IV a. 005 K4.05 2.5/2.9 Knowledge of RHRS system design Establish DHR using P 34A. feature (s) and/w inWs) which pmede fw the following:

S Heat Relaban between RHR flowpeth and refuelmg cavity.

L Removal b. 005 K5.03 2.9/3.1 Knowledge of the opersbonal implicebens of the following concepts as they apply to RHRS: Reactivity effects of RCS fill water.

8. ANO-1-JPM-RO-EOP07 M i a. 024 AK3.02 4.2/4.4 Knowledge of the reasons for the l Perform Reactor Trip immodate actions, two foil wing reap nses as they apply to the Emergency S Reac6W rods stuck, Emergency Boration. Boration.

A b. 007 EA1.06 4.4/4.5 Ability to operate and monitor the J following as they apply to a reactor trip: venfication that the control and selety rods are in after the trip.

9. ANO-1-JPM-RO-PZR04 M 111 a. 010 K1.08 3.2/3.5 Knowledge of the physical Control RCS pressurein W S RCS connecbons and/w WM relabonships h the PZR PCS and the followmg systems: PZR LCS.

Pressure b. 010 K4.03 3.8/4.1 Knowledge of PZR PCS design feature (s) and/or interlock (s) which prowde for the following:

Overpressure contml

10. ANO-1-JPM-RO-RPS01 D Vil a. 012 K4.06 3.2/3.5 Knowledge of RPS design feature (s)

Fluon RPS channelin Manual Bypass. and/or interlock (s) which proude for the following:

3 Automabc e%for manual daable of RPS trips.

!nstrumen- b. 012 K2.013.3/3.7 Knowledge of bus power supplies to tation the ', allow ng: F PS channels, cormonents, and interconneebons j Backup None of the JPM's are repeated on i the other operating test (except RPS01), use l one of the JPM's from the other operating i test.

• Type Codes: (D)irect from bank, (M)odified from bank, (N)ew, 6)lternate path, (C)ontrol room, (S)imulator, (L)ow-Power,(P)lant,(R)CA j

ES-301 IndividualWalk Thro ghTe tOutline Form ES-301-2 Facility: Arkansas Nuclear One Examination:

Exam Level (circle one): RO/ SR0(l) SR0(U perating Test No.: 2 l

System / JPM Title Type Safety Planned Fo!Iow-up Questions:

Codes

• Function KIA/G-Importance- Description

1. ANO-1-JPM-RO-AOP03 0 IV a. 061 A1.02 3.3/3.6 Ability to predet andor monitor Altemate SDN, CBO #2 Follow-tp duties: changes in parameters (to prevent exceedng design limits)

P Heat Sect.1D, Operate P7A manually. associated with operating the AFW controls includng: S/G pressure l

R Removal b. 061 K5.05 2.7/3.2 Knowledge of the operational implications of the following concepts as they apply to the AFW: Feed line voidng and water hammer.

2. ANO-1-JPM-RO-EDG10 D VI a. 064 K1.04 3.6/3.9 Knowledge of the physical wiw cAsis EDG #2, No DW andor cause4ffect relabonships between the ED/G system and the following systems: DC dstribubon system P Electrical b. 064 K4.05 2.8/3.2 Knowledge of ED/G system design feature (s) and/or interlock (s) which provide for the following: i incomplete start relay. l l

3. ANO-1-JPM-RO-AOP26 N 11 a. 004 K3.02 3.7/4.1 Knowledge of the effect that a loss or l Respond to Loss of Loadcenter B6 malfunction of the CVCS will have on the following: PZR  ;

LCS. i S RCS b. 004 K6.36 2.9/3.1 Knowledge of the effect of a loss or  !

I Inventory malfunction on the following CVCS components: Letdown pressure control to prevent RCS coolant from flashing to steaminletdown piping.

4. ANO-1-JPM-RO-RPS01 D Vil a. 012 K4.06 3 ?/3 5 Knowledge of RPS design feature (s)

Place RPS channelin Manual Bypass. and/or intenccMt} which provde for the following: Automatic 3

andor mana dsable of RPS trips.

Instrumen- b. 012 K2.0113/3.7 Knowledge of bus power stpplies to tation a following: RPG channels, components, and intwccisiscuons.

5. ANO-1-JPM-RO-EOP07 M i a. 024 AK3.02 4.2/4.4 Know% ? d the reasons for the Perform Reactor Trip immedate actions, tw f 16 wing reap naes as they apply to the Erreg&cy j S RMvity rodsstuck EmergencyBoration. Boration.

A b. 007 EA1.06 4.4/4.5 Ability to operate and monitor the )

following as they apply to a reactor trip: venfication that the control and safety rods are in after the trip.

Backtp- None of the JPM's are repeated on the other operating test (except RPS01), use one of the JPM's from the other operating test.

• Type Codes: (D)irect from bank, (M)odified from bank, (N)ew, (A)lternate path, (C)ontrol room, (S)imulator, (L)ow-Power, (P)lant,(R)CA ,

- - - - .- . . - . . ... - . - .. . . . - . = . - . - ... . . - ..-.

COMPARISON WITH AVAILABLE, PREVIOUS EXAMS I Criteria from ES-301, D.3.b " ..no more than 30 percent of the walk-through test may be repeated from the last NRC exam."

Previous exam dates: 8/24/92 SRO/RO 2/28/94 RO

~ 2/6/95 SRO (only available JPM set as of 5/12/98)

JPM's used during 2/6/95 exam:

EDGOS  !

MUP01  :

CRD03 ESAS  ;

DHR01 -  !

SWOO2 Q1V01 AOP02 CRD04 MUP05 l None of the JPM's listed above were selected for use. l l

1 1

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l'

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. . - . . - - _ . - . _ - - .- - . . _ - . - - _ . - . - - . . - - - . ~ . - . .

1 ES-301 Administrative Topics Outline Form ES-301-1 t

I l

Facility: ANO Unit 1 Date of Examination: Sept 98  !

Examination Level (circle one): RO SRO Operating Test Number; .1 j Administrative Describe method of evaluation: ,

Topic / Subject 1. ONE Administrative JPM, OR Description

2. TWO Administrative Questions A.1 Conduct of Ops . Knowledge of Shift Turnover Practices Genenc (2.1.3) (Question-Closed) f (Shift Turnover) l Conduct of Ops Knowledge of System Criteria which requires notification of plant ~!

personnel . (Question-Open)

Generic (2.1.14 ) )

(system status) i Conduct of Ops Given conditions perform an RCS Leak Rate and determine actions  !

Generic (2.1.2) required. (JPM)  ;

(RCS Leakrate) >

l A.2 Equip. Control Identify the error in the attached hold card.  !

Generic (2.2.13) (JPM)  !

Hold Card Proc. [

l' l l l A.3 Radiation Control Knowledge of 10CFR:20 and related facility radiation control I Generic (2.3.1) requirements. (Question-Closed) l (10CFR:20) j Radiation Control Ability to Control Radiation Releases.

Generic (2.3.11) (Question-Open)

(Rad Release)

A.4 Emergency Plan Knowledge of the RO's responsibilities on emergency plan Generic (2.4.39) implementation. Given the attached information, what is needed by the (Responsibility) CRS to determine the proper EAL.

(JPM) l l'

1

- NUREG-1021 21of 26 Interim Rev. 8, January 1997

y t

ES-301 Administrasve Topics Outline Form ES-301-1 Facility: ANO Unit 1 Date of Examination: Sept 98 Examination Level (circle one): RO/ RO Operating Test Number: ,,2 Administrative Describe method of evaluation:

Topic / Subject 1. ONE Administrative JPM, OR Description

2. TWO Administrative Questions A.1 Conduct of Ops Knowledge of Shift Tum-over practices.

generic (2.1.3)

(Turnover) PW Conduct of Ops Ability to execute procedure steps.

Generic (2.1.20) (Question-Closed)

(Procedure)

Conduct of Ops Ability to locate and operate components including local controls.

Generic (2.1.30) (Question-Open)

(Operate)

A.2 Equip Control Identify the error in the attached hold card.

Generic (2.2.13)

PW (Hold Card Procedure)

A.3 Radiation Control Ability to perform procedures to reduce excessive levels of radiation Generic (2.3.10) and guard against personnel exposure.

(Reduce (Question-Closed) excessive Rad Levels)

Radiation Control Ability to Control Radiation Releases.

Generic (2.3.11)

(Question-Open)

(Rad release)

Emerg Plan / Proc Knowledge of operator response to loss of all annunicators.

A.4 Generic (2.4.32) (Question-Open)

(Response)

Emerg Plan / Proc Knowledge of the RO's responsibilities on emergency plan Generic (2.4.39) implementation.

(Responsibilities)

(Question-Closed)

NUREG-1021 21of 26 Interim Rev. 8, January 1997

ES-301 Administrative Topics Outline Form ES-301-1 Facihty: ANO Unit 1 Date of Examination. Sept 98 Examination Level (circle one): RO Operating Test Number: 1 Administrative Desenbe method of evaluation:

Topic / Subject

1. ONE Administrative JPM, OR Description

2. TWO Administrative Questions A.1 Conduct of Ops Ability to make accurate, clear and concise verbal reports. (ie. Fire in Generic (2.1.17) the Aux Building)

(Verbal Reports)

Conduct of Ops Knowledge of shift staffing requirements. One hour after shift tumover Generic (2.1.4) CBOR is called home on a medical emergency.

(Staffing)

(Question-Closed)

Conduct of Ops Ability to obtain and verify controlled procedure copy.

Generic (2.1.21) (Question-Closed)

(Procedure) -_

A.2 Equip. Control Knowledge of the process for conducting tests or experiments not Generic (2.2.7) described in the SAR. (Question-Open)

(Tests)

Equip. Control Knowledge of pre-and post-maintenance operability requirements.

Generic (2.2.21) (Question-Closed)

(Operability)

A.3 Radiation Control Knowledge of the process for preparing a radiation work permit.

Generic (2.3.7) (Question-Open)

(RWP)

Radiation Control Knowledge of the process for performing a planned gaseous radioactive Generic (2.3.8) release. (Question-Closed)

(Gaseous Release) l A.4 Emerg Plan / proc Knowledge of the SRO's responsibility in emergency plan i Generic (2.4.40) implementation. Given the attached information determine the EAL. l (Responsibility) (JPM) l l

l This JPM is listed as an option for the SRO as requested by NRC. l l

A.2 Equip. Control Identify the error in the attached hold card.

Generic (2.2.13) (JPM)

Hold Card Proc. I i

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NUREG-1021 21of 26 Interim Rev. 8, January 1997 j l

1

ES-301 Administrative Topics Outline Form ES-301-1 Facility: ANO Unit 1 Date of Examination: Sept Examination Level (circle one): RO SRO Operating Test Number: 2  ;

Administrative Describe method of evaluation:

Topic / Subject 1. ONE Administrative JPM, OR Description

2. TWO Administrative Questions i

A.1 Conduct of Ops Knowledge of Shift Tum-over practices.

Generic (2.1.3) (JPM)

(Tumover)

Conduct of Ops Ability to obtain and verify controlled procedure copy, Generic (2.1.21) (Question-Closed)

(Procedure)

Conduct of Ops Ability to execute procedure steps.

Generic (2.1.20) (Question-Open)

(Procedure)

A.2 Equip. Control Knowledge of the process for making changes in procedure described Generic 2.2.6 in the SAR. (Request to operate a system in a method not (Tests) proceduralized)

(JPM) >

3 Radiation Control Knowle*; of the process for preparing a radiation work permit.

Generic (2.3.7) (Question-Open)

(RWP)

Radiation Control Ability to control Radiation Releases.

"U" ~

(Rad Release) (Question-Closed)

A.4 Emerg Plan / Proc Knowledge of which events related to system operations / status should Generic (2.4.30) be reported to outside agencies.

(Reports)

(Question-Open)

Emerg Plan / proc Knowledge of the SRO's responsibility in emergency plan Generic (2.4.40) implementation.

(Responsibility) a l

l NUREG-1021 21of 26 Interim Rev. 8, January 1997

Appendix D Scenario Outline Form ED-D-1 Facility: ANO-1 Scenario No.: 1 Op-Test No.: 1 Examiners: Operators:

Objectives: Evaluate Reactor Trip immediate and follow up actions.

Evaluate use of Emergency Operating Procedure to correct and mitigate RCS Overcooling.

Evaluate use of Loss of Steam Generator Feed Abnormal Operating Procedure.

Evaluate use of Pressurizer System Failures Abnormal Operating Procedure.

Initial Conditions: Reactor Protection System failed to provide ATWS.

Manual Reactor trip push-button failed.

Emergency Feedwater supply and isolation valves from P-7A failed open.

'A' MFWP oil pump (P-26A) running.

Tumover:

Unit is at -80% power, steady state, equilibrium power, Current power level is at direction of system dispatcher to allow for Mablevale substation work. Work completion with release to raise power to 100%

is expected tomorrow.

Event Malf. No. Event Event No. Type

• Description 1 P27A_a0 C *A" MFWP standby oil pump failure resulting in the "A" MFWP trippin0 2 IOR -DO I MFW crosstie valve fails to indicate full open.

HS2827_G T 3 RX60410 1 ICS to EHC fails raising turbine load slowly.

R N

4 MS1331.0 M 'A' Main steam line rupture upstream of MSIV and outside of R420 C containment with EFW over feed condition.

5 RP246 C Reactor Protection System will fail to trip when any trip setpoint is RP247 M reached.

RP249 R Reactor Trip push-button fails to trip the reactor.

ICC0020 6 CV2645_a 1 EFW to 'A' OTSG control valve failed open CV2627_a 1 C EFW to 'A' OTSG isolation valve failed open.

7 TR05140 1 Pressurizer level transmitter (LT1001) fails to mid-scale.

R180 (N)ormal, (R)eactivity, (1)nstrument, (C)omponent (M)ajor

• input as initial scenario setup NUREG-1021 41 of 42 Interim Rev. 8, January 1997

Appendix D Scenario Outline Form ED-D-1 Facility: ANO-1 Scenario No.:.J Op-Test No.:_1_

Examiners: Operators:

Objectives:

. Evaluate Reactor Trip immedicte and follow-up actions.

. Evaluate usage of AOP loss of reactor coolant makeup.

. Evaluate actions required for control rod drive malfunctions and ESAS actuation following a Rx trip.

. Evaluate manualinitiation of ESAS and taking manual control of components actuated by ESAS.

Initial Conditions:

. ES channels 3 & 4 are failed and will not auto actuate.

• #1 EDG is cut of service for repair of its govemor.

• #1 EDG os put breakeris racked down.

. The 'B' Hh pump is the operating pump.

Tumover: The plant is at 80% power per dispatcher orders due to storm damaged power lines. #1 EDG OOS for govemor repair. Day 2 of 7 day time clock (LCO 3.7.2.C) Daily surveillance checks of #2 EDG are complete satisfactory.

Event Malf. No. Event Event No. Type

• Description INIT DG173 DO N/A #1 DG failure EDA 3080P Rack down A308 True D0 1 CV065100 C 100 gpm leak in 'B' HPl pump suction R60 DO N Place standby HPI pump in service.

2 CV018 DO C 'D' RCP Seal 1st stage will fail 3 TRS62 i *A* Loop RCS Flow instrumentation failure.

4 RD270 C Continuous control rod insertion.

R 5 CV022 C 'D' RCP Seal 2nd stage failure CV026 M 'D' RCP seal 3rd sta0e failure (LOCA)

RC006.4 (RCS Tc leak )

R120 DO 6 ES261 DO C ES channel 3 fail to auto actuate ES262 DO M ES channel 4 fail to auto actuate 7 OVF') l *B* OTSG level fails high. ,

i (N)ormal, (R)eactivity, (I)nstrument, (C)omponent (M)ajor 1

I NUREG-1021 41 of 42 Interim Rev. 8, January 1997

Appendix D Scenario Outline Form ED-D-1 Facility: ANO-1 Scenario No.:_3 Op-Test No.: 2 Examiners: Operators:

Objectives:

. Evaluate Reactor Trip and immediate follow-up actions.

. Evaluate usage of AOP for control rod drive malfunction, and pressurizer systems failures.

. Evaluate usage of EOP to correct Degraded Power condition.

Initial Conditions:

e EFIC will fail to automatically actuate EFW.

. Seismic alarm is spurious, I&C is investigating.

Tumover 100% power equilibrium xenon. The .01 seismic earthquake alarm is in and no other alarms or indications, l&C is investigating. Thunderstorm wamings for state.

Event Malf. No. Event Event No. Type

• Description 1 N Dispatcher directs down power due to sever weather damaging transformers at Mayflower substation 2 OVRD I P2A bearing temp failure.

3 ED180 M Start Up #1 lock out.

4 RD293 R Drop rod 7 - 3 5 TR458 i Controlling RCS pressure fails to 2280#

2280 R240 6 IOR -DO I PZR spray valve leaks by with closed indication.

HS1008_R C False ICM CV1008_a

.1 7 ED183 M Loss of Offsite Power 8 FW621 C EFIC channel A 8,D initiate module fails 9 DG175 C #1 EDG will not auto start.

(N)ormal, (R)eactivity, (l)nstrument, (C)omponent (M)ajor NUREG-1021 41 of 42 Interim Rev. 8, January 1997

( . _ - _ _ _ _ _ _ _

I.

Appendix D Scenario Outline Form ED-D-1 Facility: ANO-1 Scenario No.:_4 Op-Test No.: 2 l Examiners: Operators:

Objectives:

I e Evaluate Reactor Trip immediate and follow-up actions. l

. Evaluate usage of EOP for Steam Generator Tube Rupture.

. Evaluate usage for Loss of RCS Makeup and Loss of SG Feed.

, Initial Conditions:

i 100% power, MOL, Equilibrium Xenon.

Tumover:100% operations, equalibrium xenon, outside AO is cleaning screens, housekeepin0 is dustin0 and wiping down the #1 DG room.

Event Malf. Event Event No. No. Type

• Description 1 RX605 C False lowering cf the turbine EHC.

l 30 l 2 'N Retum to previous power directed by EOC Dispatcher.

l 3 FWO74 C Trip of 'A' Main Feed Pump 1 l 4 CV2820 i MFP trip + 10 sec FW cross-tie valve sticks at 95% open. l l a.95 l 5 RC001 C "A" OTSG tube leak i

l 0.001 '

6 RC001 M 'A' OTSG tube rupture.

l 0.4 R

7 CV095 i Heatup of ES HPl pump motor winding resulting in pump trip.

l C 8 OVRD 1 "A" OTSG level fails high slowly.

l l

T (N)ormal, (R)eactivity, (1)nstrument, (C)omponent (M)ajor i

i 1

NUREG-1021 41 of 42 Interim Rev. 8, January 1997

Appendix D Scenario Outline Form ED-D-1 Facility: ANO-1 Scenario No.:_5_ Op-Test No.: N/A

• Examiners: Operators: .

Objectives:

Evaluate Reactor Trip immediate and follow-up actions.

Evaluate proper monitoring of turbine generator Evaluate usage of EOP to mitigate degraded power.

Evaluate usage of EOP to correct Blackout.

Initial Conditions:

e The RPS is failed and will not cause an automatic trip, e #2 EDG will fail to respond to an automatic or manual start si0nal. #2 EDG can be started locally.

• HD4B is throttled to cause T400 level to rise above the HLD when >85% power Tumover:

Plant is at 100% power. SU2 transformer is OOS for maintenance to repair an oil leak. The time clock will end tonight at 10pm. The transformer is expected to be retumed to operation at Spm. All TKh Spec requirements for the inoperability have been met.

Event Malf. No. Event Event No. Type

• Description 1 RP246. C RPS failure to inp RP247 RP248 RP249 2 FWO87 N P88 heater drain pump bearing heat up and trip 3 RX599 i 'B' MFP fails to respond to power reduction signal from ICS.

73.8 C 4 OVRD 1 'A' MFWP suction pressure drops during power reduction.

5 IOR-Di M Turbine trips without an RPS trip PB9201_T R TRUE DO 6 ED180 C SU1 Lockout 7 DG176 C EDG #2 fails to auto start 8 IOR -DI C EDG #2 C10 start PB will not work CSI-DG2_S 9 DG173 M EDG #1 Trip (Blackout)

(N)ormal, (R)eactivity, (1)nstrument, (C)omponent (M)aior

• This exam is a replacement exam for Exam Set #1.

NUREG-1021 41 of 42 Interim Rev. 8, January 1997

I 1

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Appendix D Scenario Outline Form ED-D-1 l

j Facility: ANO-1 Scenario No.:_Q Op-Test No.: N/A

• l Examiners: Operators l 1

i

. l Objectives:

• Evaluate reactor trip immediate actions.

. Evaluate use of ICS Malfunction AOP.

. Evaluate use of Reactor Trip EOP.  :

. Evaluate use of ESAS EOP. l I

initial Conditions:

i e Reactor Protection system failed. l e P-34A, LPI pump will not auto start on ESAS signal.

l Tumover: Unit is operating at 100% steady state, equilibrium xenon.

1 Event Malf. No. Event Event ,

No. Type

• Description l 1 TR589 i Tc Drifts low over 5 minutes. I N

2 RP246 C RPS fails to auto trip. ,

RP247 R l RP248 M RP249 3 TR626 i *B* CFT level failure. j 4 RC005 C LOCA M

5 HS1417_M C P34A fails to start on ESAS. I l

I i

(N)ormal, (R)eactivity, (1)nstrument, (C)omponent (M)ajor

• This exam is a replacement for Exam Set #2.

l NUREG-1021 41 of 42 Interim Rev. 8, January 1997 j l

1

(

c ES401 Site-Specific Written Examination Form ES-401-7 Cover Sheet U.S. Nuclear Regulatory Commission Site-Specific Written Examination Applicantinformation Name: ,

Region: IV Date: Facility / Unit ANOUnitOne License Level: RO ReactorType: BW StartTime: Finish Time:

Instructions Use the answer sheets provided to document your answers. Staple this cover cheet on top of the answer sheets. The passing grade requires a final grade of atleast 80.00 percent. Examination papers will be collected four hours aRer the examination starts.

Applicant Certification All work done on this examination is my own. I have neither given nor received aid.

Applicant's Signature Results Examination Value /00 Points Applicant's Score Points Applicant's Grade Percent NUREG-1021 39 of 39 Interim Rev.8, January 1997

.___._______.._.._y ANO Unit 1 - 1998 Reactor Operator License Exam i

Question No.1 QlD: 0001 Point Value: 1 The following phnt conditions exist: l A manual plant runback to 40% of 902 MWe has been completed.

Group 7, Rod 3, stator 6%e-c is 193 T and rising.  :

All other Control Rod stator 4& ares are normal A stator temperature HI alarm on the plant computer alarm screen is in alarm.

How will the Group 7, Rod 3 stator temperature be reduced?

i

n. Manually trip the reactor due to Group 7, Rod 3 stator temperature evMng 190 T.

. b. Transfer Group 7, Rod 3 to the Aux Bus and pull programmer control fuses for the Aux Power Supply.

c. Drop Group 7, Rod 3 by removmg the six stator fuses for the rod in the CRD transfer cabinet.

d. Transfar Group 7, Rod 3 to the DC Hold Bus to reduce stator current.

Question No. 2 QID: 0002 Point Value: 1 Power asculation to 60% power is in progress. Current reactor power is 40%. There are 3 RCPs in service.

"A" RCP is out of service due to an electrical fault in breaker H-11 (Reactor Coolant Pump P-32A).'

Which of the following conditions would warrant a manual reactor trip?

a. Annuncintar "RCP MOTOR WDG TEMP HI" (K08-B3) is in alarm with "C" RCP winding temperature at 280 T and rismg.

b. Breaker B-7146 (ICW Booster Pump P-114A) trips open and P-114B fails to autostart causing a loss ofRCP Seal Cooling.

c. A----*ar "RCP TRIP" (K08-A6) is clear, RCS flow is lowering and "B" RCP amperage indicates 0 amps on SPDS.

d. Breaker H-21 (Reactor Coolant Pump P-32D) trips open due to an overcurrent condition causing a -

loss of the "D' RCP.

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l ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 3 QID: 0004 Point Value: 1 The plant is in a degraded power situation with natural circulation cooldown in progress. %c ERV isolation valve CV-1000 has been closed due to leakage past the ERV. Which of the following best describes the appropriate action concerning operation of CV-1000 during the cooldows?

a. CV-1000 should remain closed and the cooldown secured until repairs to the ERV are completed. '

b. CV-1000 should be cycled open and closed during cooldown to prevent thermal binding of the valve.

c. CV-1000 should be opened to allow the pressurizer to go solid and transition to a HPI Cooldown.

d. CV-1000 should be deenergized and hold carded to prevent operation of the valve during cooldown.

Question No. 4 QID: 0005 Point Value: 1 l

The reactor has tripped and 3 control rods failed to fully insert. The CRS has instmeted you to perform Emergency Boration in accordance with RT-12. Which of the following best desenks the initial setting on the batch controller?

a. Set the batch matroller to the batch size determined by the plant compute boron program to compensate for the reactivity worth of the stuck rods.

b. Set the batch controller to the maximum batch size setting of 999999 gallons and commence adding j boric acid to the make up tank.

l

c. Set the batch controller to the batch size required to obtain the boron concentration as deternuned by a reactivitybalance calculation.

d. Set the batch controller to the batch size required to maintain make up tank level between 55 and 86 l inches while maintaining pressunzer level >100 inches.

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l l ANO Unit 1 - 1998 Reactor Operator License Exam l

Question No. 5 QID: 0007 Point Value: 1 .

The plant is operating at 100% power and "A" RCP experiences a simultaneous loss of real cooling and seal injection flow. Attempts to restore seal cooling and/or seal injection flow to tie pump are unsuccessful. Ilow soon should action be taken to avoid damage to the pump seal due to overheating?

a. Within 1 minute

b. Within 2 minutes

c. Within 3 minutes

d. Within 4 minutes Question No. 6 QID: 0009 Polat Value: 1 Given the following plant conditions, choose the correct operator response:

- A loss of both Main Feedwater Pumps has caused an automatic reactor trip.

- Annunciator K02'-B6, A3 L.O. RELAY TRIP, is in alana.

- Steam Driven EFW Pump, P-7A, is tagged out and disassembled for corrective maintenance.

- OTSG levels are at 15 inches and slowly dropping.

a. Take manual control of the Electric EFW Pump, P-7B, flow control valves and control OTSG levels at 20 to 40 inches.

b. Start Auxiliary Feedwat r Pump, P-75, and control OTSG levels at 20 to 40 inches using the Startup Control Valves. 1 l c. Close the MFW Isolation Valves to prevent feeding with a Condensate Pump and allow the OTSGs l to boil dry.

d. Imer OTSG pressure to feed the OTSGs using a Condensate Pump to establish primary to secondary ,

beat transfer.

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I ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 7 QID: 0010 Point Value: 1  !

I Given the following plant conditions, choose the appropriate operator actions: l

-Plantis operating at 40% power

- E-11A North Waterbox is OOS for maintenance

- Condenser vacuum is degradmg rapidly l

l a. Trip the reactor and turbine if vacuum falls below 26.5 inches Hg.

1

b. Trip the reactor and turbine if vacuum falls below 24.5 inches Hg. i

c. Trip t~ne turbine if vacuum falls below 26.5 inches Hg.

d. Trip the turbine if vacuam Yalls below 24.5 inches Hg.

Question No. 8 QID: 0011 Point Value: 1 Due to severe weather the plant is in a station blackout condition. The steam driven emergency feedwater pump (P-7A) is feeding both steam generators. Under what conditions would an " Emergency RCS Cooldown" be pe: formed?

a. Imss of subcooling margin, no HPI available, and reactor vessel head voids are indicated.

b. Reactor vessel head voids are indicated and Core Exit Thermocouple temperature > 610 *F.

c. Imss of subcooling margin and steam generator tube to shcIl delta-T >100 *F (tubes colder).

d. Core Exit Thermocouple ^+.ime > 610 *F and steam generator tube to shell delta-T >100 *F l (tubes colder).

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ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 9 QID: 0012 Point Value: 1 Given the following plant conditions:

-Reactor is tripped

- NNI X Instrument Power Supply Status lights on Cl3 are OFF

- NNI Y Instrument Power Supply Status lights on C13 are ON ,

What is the expected position of CV-1235, the pressurizer level control valve?

' a. Failed 100% open.

b. Failed 50% open.

c. Failed 0%open.

d. Functioning normal.

l Question No.10 QID: 0013 Polet Value: 1 Which of the following would indicate a tube leak in Nuclear ICW Cooler, E28C?

I

a. Increase in SW system activity

b. IncreaseinICW Surge Tanklevel

c. Increasein SW header pressure

d. Decrease in Nuclear ICW header flow Questlom No.11 QID: 0014 Point Value: 1 A fire watch reported a fire in the lower South Electrical Equipment Room and the fire brigade has been dispatched. How can the control room staff quickly determine potentially affected components?

a. Conduct control board walkdowns and refer to the plant labeling to assist in determination.

b. Refer to procedure 1107.001, Electrical System Operations, breaker alignment attachments.

c. Determine affected components from the Fire Zone drawings maintained in the control room.

d. Refer to the ANO Pre-Fire Plan for the affected fire zone for a listing of affected components.

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1 ANO Unit 1 - 1998 Reactor Operator License Exam {

Question No.12 QID: 0015 Point Value: 1 l

A fire in the control room forced an imd=*a evacuation. An alternate shutdown is in progress and the crew is attempting to stabilize the plant at hot shutdown natural circulation conditions. It is desired to raise reactor

~

j- coolant system pressure How is this accomplished?

l

a. Energize all pressurizer heaters from their respective power supply breaker cubicles.

b. Reduce steaming rate at the Atmospheric Dump Valves to raise RCS temperature and pressure

c. Manually initiate High Pressure Insection to compress the pressunzer steam bubble.

d. Manually throttle open on the pressurizer makeup block valve to raise pressurizer level.

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Question No.13 QID: 0017 Point Value: 1 l

A large break LOCA and several equipment failures have placed the plant into an inadequate core cooling condition. Which of the following provides the best indication that core damage has occured?

a. Core Exit Thr M temperatures on the ICCMDS mimic display are flashing and rising.

b. Self Powered Neutron Detector (SPND) outputs demonstrate progressive high and low swings.

c. Source Range Monitors indicate higher than normal readings by more than a factor of ten.

d. The Reactor Vessel Level Monitoring System indicates voids present in the reactor vessel head.

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Question No.14 QID: 0018 Point Value: 1 Following a reactor trip the plant expenences a loss of subcooling margin. Why is it desirable to secure all l reactor coolant pumps within 2 minutes following a loss of meenaling margin?

l

a. To allow the void coenicient of reactivity to add negitive reactivity to the core.

b. To protect the mechanical seals on the reactor coolant pumps.

I

c. To prevent avdng a 70% void fraction and possible core uncovery. I

d. To reduce operator burden by eliminating the need for RCP services.

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l l ANO Unit 1 - 1998 Reactor Operator License Exam l

l Question No.15 QID: 0019 Point Value: 1 Fuel pin leakage has caused higher than normal activity in the reactor coolant system. Which of the following i indications on the Failed Fuel Monitor (RI 1237) would be indicative of failed fuel and require power reduction?

l l a. A marked rise by 20% in the IODINE / GROSS ratio.

I b. A marked rise by 40% in the GROSS / LODINE ratio.

1

c. A marked drop by 20% in the IODINE / GROSS ratio.

d. A marked drop by 40% in the GROSS / IODINE ratio.

i Question No.16 QID: 0020 Point Value: 1 l l

l Given the following indications / alarms

- SASS Mismatch alarm (fast flash)

-SG BTU Limit alarm (slow flash)

- SG "B" FW Terrp sig.al select switch selected to SASS Enabic with l the white indic". ring light out and the blue "Y" light on.

What operator actionis required?

a. Place the SG "B" FW Temp signal select switch to the "Y" position.

b. Depress the Auto pushbutton for SG "B" FW Temp on the SASS panel in C47-2.

c. No action necessary, SASS has automatically transferred to "Y" NNI.

d. Place both FW loop demands in manual.

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l ANO Unit 1 - 1998 Reactor Operator License Exam l

Question No.17 QID: 0021 Point Value: 1 The plant is operating at 100% power. A failure of an ICS module downstream of the SASS circuitry causes the Nuclear Instrumentation input to the Reactor Demand station to fail low resulting in a large negative neutron error. Assuming no operator action. how will this failure affect control rods and main feedwater flows?

a. Control rods will insert and main feedwater flows will increase

b. Control rods will withdraw and main feedwater flows will increase

c. Control rods willinsert and main feedwater flows will decrease.

d. Control rods will withdraw and main feedwater flows will decrease. j Questlom No.18 QID: 0022 Point Value: 1 ,

Which of the following dropped or misaligned control rod scenarios would require a reactor shutdown instead  !

of a control rod recovery attempt?

a. A fully dropped' rod at 38% power.  ;

i

b. A dropped rod at <2% power. l 1

c. A partially dropped rod at 10% power.

d. A rod misaligned for >24 hours.

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ANO Unit 1 - 1998 Reactor Operator License Exam l

l Question No.19 QID: 0023 Point Value: 1 j i

l The following conditions exist immediately after a reactor trip:

1

- Group 2, Rod 4 failed to fully insert into the core. J

- RCS pressure is at 1750 psig and trending down l

- Pressurizer level is at 50 inches and trending down l

- A OTSG pressure is at 880 psig and trending down 1

- B OTSG pressure is at 950 psig and trending down

- Subcooling margin is at 70 'F and trending up slowly Choose the appropriate operator response:

a. Manually actuate "A" MSLI and EFW.

b. CommenceemergencyborationperRT-12.

c. Trip all Reactor Coolant Pumps. j

d. Initiate High Pressure Injection per RT-2.

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Question No. 20 QID: 0024 Point Value: 1 The plant is operating at 100% power when a single rod drops and fully inserts into the core. ICS is in full automatic and commences a plant runback. Which of the following will determine how fast plant power can change?

a. The operator set rate of change.

b. The pre-set ICS runback rate of change.

c. The speed of the control rods and core age.

d. The rate of change in main feedwater flow. ,

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. ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 21 QID: 0025 Point Value: 1 The following plant conditions existedjust prior to an automatic reactor trip:

- Reactor power at 45%

- Loss of Bus H-1 due to an electrical fault

- "B" Main Feedwater Pump tripped

- Condenser vacuum at 24.5 inches Hg

- RCS pressure at 1950 psig Which of the following was the most likely cause of the automatic reactor trip?

a. Main turbine Anticipatory trip.

b. Power to Pumps trip.

c. VariableIowPressuretrip.

d. MainFeedwater Anticipatorytrip.

Question No. 22 QID: 0027 Point Value: 1 The following plant conditions exist: ,

Pressunzer te+.i e is 645 'F Pressurizer level is 225 iehas and rising RCS Pressureis 2150 psig and stable Quench Tank pressure is 10 psig and rising The ERV acoustic monitor indicates flow noise

- What would be the expected temperature as indicated on the ERV PSV-1000 Outlet Temp on the Safety Parameter Display System (SPDS)?

a. Approximately 193 'F

b. Approximately 212 'F

c. Approximately 239 'F

- d. Approximately 645 'F Page 10 l

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i ANO Unit 1 - 1998 Reactor O I,erator License Exam i

Question No. 23 QID: 0028 Point Value: 1 A small break LOCA cooldown is in progress with subcooling margin less than adequate.

Which of the following cooldowin limits apply?

a. 100 'F/hr when >300 *F

b. 50 'F/hr when 300 - 170 'F

c. 25 'F/hr when < 170 'F

d. No cooldownlimits apply Question No. 24 QID: 0029 Point Value: I Given the following plant conditions:

- Reactor trip from fullpower

- FullES actuation

- ICCMDS Display Subcooling Margin indicates 0 'F

- Reactor Coolant Pumps are OFF f7

s. .-

- ICCMDS CET temperatures are alternating between superheated and saturated conditions.

Which of the following best describes the mode of RCS cooling for these conditions?

a. Reflux Boiling

b. Forced Convection

c. Natural Circulation

d. Natural Conduction

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ANO Unit 1 - 1998 Reactor Operator License Exam Questlom No. 25 QID: 0030 Point Value: 1 During a small break LOCA cooldown, widch of the following criteria must be met before High Pressure Injection maybe secured?

a. Restoration of adequate subcooling marda

b. Totallow pressure injection flow >2800 gpm.

c. Restoration of forced flow cooling.

d. At least one OTSG is available as a heat sink.

Question No. 26 QID: 0031 Point Value: 1 The unit is operating at 100% power. SU-1 transformer is INOPERABLE. The Startup Tansformer Preferred Transfer Switches on C-10 for A1/H1 and A2/H2 are selected to SU-2 transformer. SU-2 feeder breakers to A1, A2, H1 and H2 are out of the pull-to-lock position. Which of the following best describes the electrical -

system response to a reactor / turbine trip?

- a. With SU-1 inoperable, the load shed protective circuitry will require a manual transfer of electrical buses to SU-2 due to the limited capacity of SU-2.

b. The reactor / turbine trip will actuate the generator lockout relay and result in a " slow transfer" of A1, A2, H1 and H2 electrical buses to SU-2 transformer.

c. The tie breakers between the vital and non-vital buses will open, the emergency diesel generators will start and supply the vital buses and SU-2 will power A1, A2, H1 and H2.

d. The generator lockout relay trip will cause a " fast transfer" to SU-2 transformer and applicable loads will be shed to limit the loading on SU-2 transformer.

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i ANO Unit 1 - 1998 Reactor Operator License Exam Point Value: 1 l Question No. 27 QlD: 0032 Given:

i

-Plant operating at 100% power

- P-36B in service -

-PZRleveltrending down slowly

-Letdown flow 45 gpm

-Makeup flow 0 gpm

-MUT level trending down

-Total sealinjection flow 70 gpm Which of the following would cause the above indications?

a. P-36B makeup pump has tripped

b. PZRleveltransmitter failed high l

c. Loss ofinstrument Airin LNPR l 1

)

d. Makeup line break upstream of CV-1235 j l

Questlea No. 28 Q1D: 0033 Polat Value: 1 l Which of the following is an i=Miate Action performed only for loss of DH Removal due to vortexing?

a. Close at least one DH suction valve from the RCS.

b. Stan the other DH pump to makeup to RCS from BWST.

c. Initiate containment closure per Att. G of 1203.028.

d. Stabilize flow by throttling one of the discharge flowpath valves.

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l ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 29 QID: 0034 Polat Value: 1 Which of the following best describes how the DROPS AMSAC signal trips the main turbine?

l a. Relays in the turbine trip circuitry energize the Auto-Stop Oil trip and Backup Trip Solenoids.

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b. Relays in the OPC circuitry energize the OPC Solenoids and close the Governor and Intercept Valves.

c. Relays in the EHC circuitry actuate the EHC Solenoid Trip Valve to trip tie main turbine,

d. Relays in the RPS cabinets actuate the Anticipatory Trip of the main turbine.

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Question No. 30 QID: 0036 Point Value: 1 l

l Given tie following plant conditions: l l 1

- Reactor Startup in progress

- Proper overlap between source and intermediate range detectors has been observed

- Stabilizing reactor power to obtain critical data

- NI-501 failslow i

Choose the correct operator response:

a. Trip the reactor due to the loss of NI-501.

b. Place plant in Hot Shutdown within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

c. Continue reactor startup per 1102.008, Approach to Criticality. l l d. Maintain present power level until NI-501 repaired.

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~ . . .. - . . . -- . .-- - . - - . - - - _ - . .- _. - _ .

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l ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 31 QID: 0037 Point Value: 1 1202.006, Tube Rupture, emergency operating procedure prosides guidance to

• Operate Pressun Heaters AND Pressurizer Spray valve (CV-1008) to maintain RCS pressure low within limits of Fi " hile l cooling down the RCS.

/

, What is the PRIMARY reason for maintaining RCS pressure low? 3

a. To prevent liAing main steam safetics.

b. To minimize thermal stresses on the steam generators.

c. To minimize the RCS leak rate into the steam generator,

d. To prevent cycling of the ERV (CV-1000). ,

Question No. 32 QID: 0038 Point Value: 1 The plant is shutdown and a cooldown is in progress due to a 200 gpm tube leak in the A OTSG.

- RCS temperature is 520 *F and lowering

- BWSTlevelis at 35 A andlowermg i

- A OTSGlevelis 290 inches and rising I

- Dose rates at site boundary are normal l Which of the following RCS cooldown limits apply? ,

i a lesF than or equal to 50 'F/ hour.

b. less than or equal to 100 *F/ hour,

c. Iess than or equal to 240 *F/ hour.

d. Less than or equal to 520 'F/ hour.

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ANO Unit 1 - 1998 Reactor Operator License Exam  !

Question No. 33 QID: 0039 Point Value: 1 ICS is in full automatic and the CBOR is verifying proper plant response to a main feedwater pump trip from 100% power. Which of the followmg is NOT an expected response?

, s. The main feedwater discharge crosstic valve will open automatically when the pump trips.  !

b. De main feedwater block valves will close in slow speed once power goes below 80%.

c. The pressunzer sprey valve will come open when RCS pre 6sure reaches 2080 psig.

d. The control rods will start inserting immediately due to a bias applied to the reactor demand signal.

i Question No. 34 QID: 0040 Point Value: 1  ;

An inadequate core cooling event is in pmgress. In order to establish primary to secondary heat transfer it is ,

desired to " bump" RCPs. Which of the following best desenh:s the correct method for " bumping" RCPs in l accordance with RT-117

a. Start the pump,'then imma4taly secure the pump.

b. Start the pump, when normal running amps are indicated on SPDS, then secure the pump.

c. Start the pump, ma the pump for 10 seconds, then secure the pump.

d. Staat the pump, run the pump for 1 minute, then secure the pump.

Questlos No. 35 QID: 0041 Polet Value: 1 A reactor trip has occured from 100% power following a loss of D01. Attempts to transfer 125V DC panel D11 to its emergency supply are un===r t. u Which of the following is the appropriate immediate action?

a. Crosstic D-11 and D-21 from panel C-10 in the control room to provide power to D11.

b. Manually actuate main steam isolation on both steam generators and verify proper actuaton and control.

c. Select main turbine control to "IURBINE MANUAL and close the governor valves in fast speed.

. d. Manually acutate emergency feedwater and verify proper actuation and control.

Page 16

ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 36 QID: 0042 Point Value: 1 The plant is operating at 100% power. A radioactive liquid release from a Treated Waste Monitoring Tank (T- l 16A) was co - -=+i by the previous shift. AAer reviewing the release permit paperwork, you discover that the setpoint on tle Liquid Radwaste Process Monitor (RI-4642) is set HIGHER than the setpoint called for on the release permit, j l

Which of the following best describes the appropriate actions in accordance with Technical Specifications?

a. A4iust the setpoint to the correct value and continue the release.

I

b. Continue the release since the incorsect setpoint is more conservative.

c. Stop the release and adjust the setpoint to the correct value.

d. Stop the release and sample the tank to obtain a new setpoint. l I

Question No. 37 QID: 0043 Point Value: 1 A radioactive gas release of WGDT T-18B has been termmated by Gaseous Radwaste Monitor, RE-4830, in l

! high alarm. Examination of the recorder paper shows RE-4830 had been trending steadily at ~2000 cpm when itjumped to 30,000 cpm and then dropped back to ~2000 cpm. 1 What action should be taken?

a. Submit Condition Report and check system alignment.

b. Notifiy Nuclear Chemistry to perform offsite dose projections via RDACS. l 1

c. Isolate T-18B and then re-submit sampling and release pennit.

d. Reset RE-4830 and re. establish T-18B gaseous release.

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ANO Unit 1 - 1998 Reactor Operator License Exam l

Question No. 38 QID: 0046 Point Value: 1  :

Given: l i

- Degraded Power l

. - Both EDGs operating

- ESAS has NOT actuated

- P4C hiled to start Which of the following actions should be accomplished?

s. Close SWImop IIIsolation Valve (SW-10C). f i

b. Open SW Imop I & Il Cmssoonnects (SW-5 and SW.6).  !

c. Close ACWI40pIsolation(CV-3643).

d. Cross-tic SW Loops at Makeup Pump (SW-14 thru SW 17).

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Question No. 39 QID: 0047 ' Potat Value: 1 In accordance with the EOP, when do the Pressurized Thermal Shock limits NO LONGER apply?

a. When the RCS pressure / temperature is to the right of the NDTT limit line on Figure 3.

6

b. Following restoration of RCP services and starting of Reactor Coolant Pump's. j

c. Upon tennination of High Pressure Injection to the Reactor Coolant System.

d. Following an evaluation which will allow normal RCS pressure control to resume.

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ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 40 QID: 0048 Point Value: 1 A Blackout has occurred.

1. 1 EDG has been placed in senice on a "No DC" start using 1104.036, Emergency Diesel Generator Operation.

What DG protection is operable to protect the only operable AC source?

a. positive crankcase pressure trip

b. Iowlubeoilpressuretrip

c. mechanicaloverspeed trip

d. high jacket water temperatiire trip Question No. 41 QID: 0050 Point Value: 1 A rapid plant shutdown at 4 % per rrdnute is in progress due to a RCS leak inside the reactor building. The CBOT reports that the RB Sump has risen 7% over the past 5 minutes.

Which of the following best describes the correct response? j

a. Continue the rapid plant shutdown at 4 % per minute.

b. Raise the shutdown inte to 8 % per minute. ,

l

c. Initiate HPI to maintain pressurizer level >200 inches.

d. Trip the reactor and turbine and perform immedia',e actions.

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l I' ANO Unit 1 - 1998 Reactor Operator License Exam l Point Value: 1 i l Question No. 42 QID: 0052 The plant had been operating at 100% power for 200 days. Following a plant trip, preparations for startup are in progress. The CBOR is performing a calculation for Estimated Critical Position (ECP). At a given boron concentration, which of the following times would result in the highest rod index due to the effects of Xenon?  ;

)

a. 4 to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />

b. 8 to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> '

r

c. 40 to 60 hours6.944444e-4 days <br />0.0167 hours <br />9.920635e-5 weeks <br />2.283e-5 months <br />

d. 70 to 90 houn Question No. 45 QID: 0055 Point Value: 1 Without operator action, which of the following incidents would have the most detrimental effect on RCP operation?

a. Imss of nucleariCW '

b. Main naam line breakinside RB

c. Imss ofRCP sealispection

d. Sealreturnlinebreakin AuxBldg Question No. 44 QID: 0055 Point Value: 1 Batch Controller Flow Control Valve (CV-1249) should normally be open no more than 20% when feeding boricacid. Why?

1

a. To prevent pump runout on the boric acid pumps

b. To prevent exceeding design flow through the batch controller.

c. To prevent overheating of the boric acid pumps d To prevent inaccurate readings on the batch totalizer.

Page 20

ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 45 QID: 0057 Point Value: 1 Which of the following would result in all ten (10) ESAS Digital Channels receiving an Analog Channel Trip signal?

a. Remmt of the low RCS Pressure Bistable from Analog Channel 1.

b. Removal of the RB Pressure Buffer Amplifier from Analog Channel 1.

c. Removal of the 30 psig RB Pressure Bistable fmen Analog Channel 2.

d. Removal of the RCS Pressure Buffer Amplifier from Analog Channel 2.

Question No. 46 QID: 0058 Point Value: 1 A startup is in pmgress. The reactor is critical and the CBOR is commencing power escalation to <2% reactor power. The following indications are observed:

NI-3 1 x 104 amps NI-4 8 x 10-7 amps NI-5 0.8%

(' NI4 1.1%

NI-7 1.3%

NI-8 1.2%

What conclusion should you deduce from the above indications?

a. Power Range channel 5 reqmres calibration.

b. The Intermediate Range channels are overcompensated,

c. The POAH has notyetbeen reached.

d. The Intermediate Range channels are u-Aiw pnsated.

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' ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 47 QID: 0059 Point Value: 1 During a large break IDCA the value on the ICCMDS CET Subcooling Margin Display is negative and flashing. What does thisindicate?

a. AnICCMDS communications error,

b. CET readings are invalid.

c. Core damage has occurred.

d. CET readings indicate superheat Question No. 48 QID: 0060 Point Value: 1 Which of the following load centers supply power to the five (5) Reactor Building Ventilation Fans?

a. B5, B6 and B7

b. B3, B4 and B2'

c. B3,B4 and B7

d. B5,B6 and B2 Page 22

ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 49 QID: 0062 Point Value: 1 Given the following plant conditions:

- 100% power

- CondensatePumpP 2AOOS

- K06-E7 "COND PUMP MTR WDG TEMP HI" is in alarm

- AO reports fire in P-2C motor The CRS instructs the CBOT to trip P-2C, which of the following best desenks the correct response?

a. Trip P-2C, perform immediate actions per 1203.027,less of Steam Generator Feed.

b. Trip P-2C, monitor ICS'rdsback to 40% power and dispatch the fire brigade per 1203.034, Smoke, Fire or Explosion.

I

c. Trip P-2C and reduce power per 1203.045, Rapid Plant Shutdown, to maintain adequate main feed pump suction pressure.

d. Trip P-2C thea trip the turbine and reactor and carry out immediate actions per 1202.001, Reactor Trip.

Question No. 50 QID: 0063 Point Value: 1 l f

Given:

- 100% power

- ICS in fullautomatic

'Ite CBOR places the ICS Delta T-Cold Hand Auto Station meter selection switch in "POS" (position). The meter reads 54% What does this mean in terms ofICS control of main feed water?

a. The average of feedwater loop A and feedwater loop B demand is $4%

b. Feedwater loop B demand is greater than feedwater loop A demand.

c. The feedwater loop B demand is being boosted by a 4 'F Delta T-Cold enor,

d. Feedwater loop A demand is greater than feedwater loop B demand.

Page 23

ANO Unit 1 - 1998 Reactor Operator License Exam Questlom No. 51 QID: 0064 Point Value: 1 Given:

- SmallBreak LOCAin progress

- RCS Pressure at 1500 psig and stablizing

- K11-B2, LPI Channel 3, annunciator alarm is clear Assuming no operator action, which of the following best describes the response of the EFIC/EFW system?

a. EFIC train A will actuate EFW train B, EFW pump P-7B is running.

b. EFIC train A will actuate EFW train A, EFW pump P-7A is running.

c. EFIC train B will actuate EFW train A, EFW pump P-7A is running.

d. EFIC train B will actuate EFW train B, EFW pump P-7B is runmng.

Question No. 52 QID: 0065 Point Value: 1 A radioactive liquid release is in progress. RI-4642, Liquid Radwaste Process Monitor, loses power due to an electrical fault.

What effect will this have on the release?

a. A loss of power will cause a process monitor trouble alarm to alert the control room staff to manually terminate the release.

b. A loss ofpower to RI-4642 will cause a high radiation alarm signal which will automatically terminate the release.

c. A loss of power to RI-4642 will align instrument air to the radwaste flow control valve, CV-4642, and automatically terminate the release.

d. A loss of power will cause the radwaste flow control valve, CV-4642, to fail open and require manual termination of the release.

Page 24

ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 53 QID: 0067 Point Value: 1 l Given:

- C-119A H2/02 Analyzer is 005 with repairs on pans hold

- C-119 H2/02 Analyzer is aligned to T-17

- T-18C Waste Gas Decay Tank is in senice l

Chemistry has requested Operations to vent the makeup tank to raise hydrogen purity. Which of the followmg  ;

best Afues the proper H2/02 Analyzer system operation during the makeup tank venting operations?

a. Makeup tank venting is not allowed unless both H2/02 Analyzers are operable in accordance with Technical Specifications.

b. Keep C119 aligned to T-11 and commence makeup tank venting operations,  !

align C119 to T-18C if high H2/02 concentrations occur.

l

c. Align C119 to T-18C and commence makeup tank venting operations while monitoring for high H2/02 concentrations. I

d. Keep C119 aligned to T-17 and have chemistry sample T-18C every 15 mins when venting the makeup tank.

Question No. 54 QID: 0068 Point Value: 1 Control Ventilation is in a normal alignment when the Unit 1 Control Room Inlet Air Radiation Monitor (2RITS4001A) comes into alarm. Which of the following describes the expected control room ventilation l system response?

a. AllIsolation dampers CIDSED, VSF-8A/B OFF,2VSF-8A/B ON, VSF-9 ON and 2VSF-9 OFF.

b. Unit 1 isloation dampers CLOSED, VSF4A/B OFF,2VSF-8A/B OFF, VSF-9 ON and 2VSF-9 ON.

c. AllIsolation dampers CLOSED, VSF4A/B OFF,2VSF-8A/B OFF, VSF-9 ON and 2VSF-9 ON.

d. Unit 1 isloation dampers CLOSED, VSF4A/B OFF,2VSF4A/B OFF, VSF-9 ON and 2VSF-9 OFF.

Page 25 l'

h ANO Unit 1 - 1998 Reactor Operator License Exam 7 i

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- Questlos No. 55 QID: 0069 Point Value: 1 Given: j

- Manual reactor trip has taken place, and inunaante actions are complete

- OTSG *B" level is increasing above 390"

- OTSG *B" pressure is decreasing below 900 psig rapidly 1

- - Picssunzer pressure and level are A A ,

- Steam line high range whation monitor RI-2682 is in alarm l Which of the follomng events is in progress?

l l a. OTSG tube rupture and stuck open MSSV l'

b. OTSG tube rupture and' excessive EFW flow L

I c. Small break LOCA and excessive EFW flow

d. Small break LOCA and stuck open ERV .

Q=eatia= No. 56 QID: 0070 Point Value: 1 .

' A SBIDCA is m progress mth RCS prasure stablized at 1400 psig.

1

! In this d'. which of the following systems is designed to maintain clad temperature <2200*F per i l 10CFR50? ]

1

a. Reactor Protection System l l

l . b. Imv Pressure Injection System .

I

c. High PressureIssection System  !

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d. . Core Flood Tank System 1

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I ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 57 QID: 0071 Point Value: 1 l

Given:

-P36B out of senice

-IDCA in progress

-RCS pressure 1250 psig  :'

-4160vbus A3 deenergized

-HPI flows: A = 90 gpm i B = 100 gpm i C = 250 gpm ,

D = 75 gpm i Which of the following actions is required? i

a. Throttle "C" flow to within 20 gpm of"B" ,

I

b. Throttle "C" flow to within 20 gpm of"D"

c. 'Ihrottle all to within 20 gpm of each other

d. Throttle "C flow to within 20 gpm of"A" Question No. 58 QID: 0072 Point Value: 1 Given:

RCS pressure 1950 psig and decicasing

- RELIEF VALVE OPEN", K09-A1, in alarm

-ERVindicates closed

- Acoustic monitor indicates ERV is leaking You immediately close ERV Isolation valve, CV-1000. RCS pressure continues to decrease What should your next action be?

a. Begin plant runback

b. CycletheERV

c. InitiatefullHPI

d. Trip the reactor Page 27 j

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i ANO Unit 1 - 1998 Reactor Operator License Exam j t

i Question No. 59 QID: 0073 - Point Value: 1 {

' A reactor trip occurs from 100% power.  ;

TBV setpointbias does NOT function. ,

You observe all of the PZR heaters turmng off.  !

i Why did this occur?  :

a. 4160v bus transfer from Unit Aux to S/U #1 i

b. RCS pressure is greater than heater setpoint i

c. PZR level decreased due to cooldown  ;

I

d. PZR swelled, squeezinj; tE steam bubble i P

i Question No. 60 QID: 0075 Point Value: 1 l l

Given: .

- C" RPS is placed in Channel Bypass for I&C troubleshooting

-Plantis at 40% power

- A" MFW pump in semcc Which of the following would cause an automatic reactor trip with the given conditions? l

a. Contact monitor module pulled in "C" RPS and "A" RPS taken to Shutdown

- i

b. Turbine trip contact buffer module pulled in "C" RPS and N1-6 power range test module taken to " test operate" in Channel "B".

c. Shutdown Bypass 5% power module taken to " test operate" in channel "C" and "D" channel placed in Shutdown Bypass. j i

d. IAC doenergizes "C" RPS cabinet and "A" MFW pump contact buffer trip test switch operated in "A" cabinet.

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. ~ .- . .- .. .- . _ - - _ . . - . _ _ - . . - - . - - - . . . -- -. ..

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t ANO Unit 1 - 1998 Reactor Operator License Exam 1 1

Question No. 61 QID: 0076 Point Value: 1 l

' i

! At 100% power, a CRD in Group 6 with a history of faulty API has been determined by Incore detectors to be

~50 inches inserted. It has been in this position for at least 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.

How would you re-align the rod with the rest of Group 67

a. Reduce power to 90% then withdraw rod, while keeping power rate <5%/hr.

b. Hold power and withdraw rod while keeping power <100%.

c. Reduce power to 60% ofMWt for RCP combination then withdraw rod, keeping rate <3%/hr.

d. Reduce power to 40% of 902 MWe then withdraw rod, keeping rates to 0% /15%

Question No. 62 QID: 0077 Point Value: 1 Given-

-Loop A RCS flow 68,000,000 lbm/hr

-Imop B RCS flow 63,000,000 lbm/hr

-Loop A Tave 5787

-Loop B Tave 5807

-Unit Tave 579'F ,

Which Tave will be selected by the SASS Auto / manual transfer switch and why?

a.. Unit Tave due toImop B flow

b. loop A Tave due to Loop B flow

c. Imop B Tave due to Loop B flo v

d. Unit Tave, flows are within tolerances l

'* Page 29

l ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 63 QID: 0078 Point Value: 1  ;

If an ESAS occurs simultaneously with a Loss of Offsite Power, tie start of RB Spray pumps is delayed by 35 sec. Why?

a. To allow the EDGs to come up to speed.

b. To allow SW pumps to start for spray pump cooling.

]

l

c. Toprevent overload of the EDGs

d. To prevent water hammer of the spray headers.

Question No. 64 QID: 0079 Point Value: 1 Given:

I Unit operating at 100% j Reactor Building pressure is 15.9 psia and stable  ;

No other abnormalconditions exist l J

What action should be taken to lower RB pressure?

I

a. Open RB purge inlets first, then open outlets.

b. Vent RB via H2 sample lines.

c. Use vent flowpath via RB leak detector.

d. Open RB purge outlets first, then open inlets.

Question No. 65 QID: 0060 Point Value: 1 Which of the following design features allows for the safe storage of new fuel in the spent fuel pool?

a. Spent fuel cooling system is designed to maintain pool temperature <l50 'F.  !

I

b. Spent fuel boron concentration is maintained >1600 ppm boron.  !

c. A syphon break is incorporated into system piping to prevent inadvertent draining.  !

d. Fuct racks designed with boraflex plates and adequate spacing.

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Page 30 l

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ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 66 QID: 0061 Point Value: 1 Which of the following are performed by RFR?

I) Closes MFW block valves in fast speed

2) Inserts a zero demand signal into both FW loop demands

3) Inserts a negative error into the S/U and I4w Load valve controllers

4) Throttles S/U valve to 40% open

5) ShiAs MFW pump contro)to high FW loop DP

6) Closes thelowloadblockvalve

7) Holds S/U and Iow Imad valves shut if MSLI is also present

a. 2,3, and 7 .,

b. 1, 2, and 6

c. 1,3, and 7

d. 2,5,.and 6 Question No. 67 QID: 0083 Point Value: 1 A reactor startup is in progress with the reactor CRITICAL at I E-8 amps power. An atmospheric dump valve fails OPEN. Which one of the following dem.iil,es the initial primary plant response?

a. Reactor power will INCREASE, temperature will DECREASE, and pressure will DECREASE.

' b. Reactor power will DECREASE, temperature will INCREASE, and pressure will DECREASE.

c. Reactor power will INCREASE, temperature will INCREASE, and pressure will INCREASE.

d. Reactor power willINCREASE, temperature will DECREASE, and pressure will INCREASE.

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ANO Unit 1 - 1998 Reactor Operator License Exam l l

l Question No. 68 QID: 0084 Point Value: 1 l'

A loss of 125v DC bus D02 has occurred The reactor subsauently trips.

Which of the following conditions will be present?

a. EDG 2 running with A4 bus deenergized

b. EDG 2 running wih A4 bus energized I

I

c. EDG 2 stopped with A4 bus energized

d. EDG 2 stopped with A4 bus doenergized I

Question No. 69 QID: 0086 Point Value: 1 The plant is at 70% power. Which of the following DC buses / panels, if deenergized, would cause a reactor trip?

a. PanelD41

- b. PanetRAI

c. MCCD15

d. PanelD21 Question No. 70 QID: 0088 Point Value: 1 The CRS directs you to perform Supplement 1 of 1104.036, #1 EDG Monthly Test. You depress the start pushbutton on CIO, nothing happens, tien the 'EDG 1 OVERCRANK" annunciator K01-E2 alarms. 'Ihe CRS duccts the inside AO to check the EDG out and then depress the local RESET pushbuttan.

Which of the following would occur after the AO depresses the RESET pushbutton?

a. EDG would be ready for another manual start.

b. EDG will not manually or automatically start.

c. EDG output breaker will be locked out.

t

d. EDG will immediately start cranking.

Page 32 I

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ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 71 QID: 0069 Polat Value: 1 Given:

- Treated Waste Monitor Tank, T16A, release in progress

- PROC MONTIOR RADIATION HIGH", K10-B2, in alann

- Liquid Radwaste Process Monitor, RI-4642, in alarm What should your Immediate Action be?

a. Verify no flow on Discharge to Flume, FI-4642

b. Trip the running Radwaste Transfer pump, P-53 A/B

c. Close Liquid Waste to Flunic nive, CV-4642

d. Reset RI-4642 to verify alarm is valid Question No. 72 . QID: 0090 Polat Value: 1 The yellow trouble LED is ON on #1 EDG flame detector module on C463 and has been acknowledged on C463. Subsequently, a #1 EDG smoke detector alarms.

Which of the following annunciators would you expect to see? I

a. " FIRE WATERFLOW", K12-A2

b. " FIRE PROTECT SYSTEM TROUBLE", K12 - D1

c. " FIRE",K12-Al

d. " FIRE PUMP AUID START", K12-B2 Page 33 1

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l ANO Unit 1 - 1998 Reactor Operator License Exam I l

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Questlos No. 73 QID: 0091 Point Value: 1 I

1 Given:

-Plant cooldowsin progress l - "A"DHRemovalpumpin senice j - A" and "C" RCFs running i What is the maximum allowable cooldown rate in tids condition?

a. 5'F/hr

b. 25'F/hr

c. 50*F/hr )

1 i

d. 100'F/hr l l

l Question No. 74 QID: 0092 Polet Value: 1 The white light above the handswitch for CV-1410, DH Suction from RCS, is ON.

What does this indicate?  ;

a. 'Ihe intedock will allow valve opening.

b. DC Control Power is avadable.

c. "B" CFT Outlet valve is open.

i d.The MOVs breaker has tripped.

i Question No. 75 QID: 0093 Point Value: 1 Which of the following parameters would indicate a leaking PZR code safety?

a. QuenchTankIcvel7500 gallons

b. QuenchTank pressure 5 psig

c. Code safety tailpipe temperature 200 *F

d. Quench Tank temperature 155 'F Page 34 o

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1 ANO Unit 1 - 1998 Reactor Operator License Exam I

Question No. 76 QID: 0094 Point Value: 1 ICW Booster pump P-114A is in senice and trips due to breaker overcurrent with a suction pressure of 24 psig.

, How is seal cooling to RCP's maintained?

l

a. ICW pump P-33B will start due to low disch press of <35 psig.

b. Bypass Control valve CV-2287 will open to maintain flow to seal coolers.

c. ICW Booster pump P-114B will start due to low disch press of <105 psig i

d. ICW Booster pump P-114B will start due to low suction press of <45 psig. )

l Question No. 77 QID: 0096 Point Value: 1 Which of the following Reactor Building systems are required to be operable wben:ver Pil Integrity is required?

a. Both trains of RB Coolers

b. HydrogenRecombiners l

l

c. BothRB SprayPumps

d. RB Purge Questlom No. 78 QID: 0097 Point Value: 1 What is the purpose of the load setpoint of 1200-1500 pounds on the Spent Fuel hoist?

a. Prevents a fuel assembly from being dropped while grapple is engaged.

r 1

b. Prevents damage to a fuel assembly ifit is stuck in place.

c. Keeps the bridge from moving in fast speed while transporting an assembly.

d. Stops downward motion of hoist to allow the grapple to be engaged.

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1 l ANO Unit 1 - 1998 Reactor Operator Liceuse Exam l

Question No. 79 QID: 0099 Point Value: 1-Which one of the following indications implies proper transfer of EHC from Speed Control to Load Control?

l

a. Opciator Auto indicatinglight turns ON. i

b. GV controlindicating light turns ON.

c. TV-GV Transfer indicating light turns OFF.

d. Reference counter hidicates GV demand voltage.

Question No. 80 QID: 0100 Point Value: 1 The plant is operating at 90% power when a malfunction of the Main Turbine EH control system causes a spurious OPC actuation.

Which of the following would occur during the transient?

. l

a. RCP sealinjection flow would drop.

b. PZR spray flow would drop.

c. PZR makeup flow would drop. ,

d. FW flow to both OTSG's would rise.

Question No, dl QID: 0101. Point Value: 1 Which of the following is NOT an action to take with a loss of Service Water with only one SW pump running?

a. Close Generator H2 Temperature Control Valve

b. Trip the runmng Spent Fuel Cooling pump l- c. Isolate both Condenser Vacuum Pump coolers l

d. Reduceletdown flow to nunimum Page 36 l

l ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 82 QID: 0102 Point Value: 1 Instrument Air pressure has fallen to 70 psig, which of the following will be in use to restore or conserve Inst.

Air pressure?

a. Inst. Air to Serv. Air X-over valve, SV-5400

b. Use of HPI Block valve vs. Makeup valve, CV-1235 I

c. Breathing Air toInst. Air X-connection, HS-5503

d. IfICW available, isolate Seal Injection by closing CV-1206 Question No. 83 QID: 0104 Point Value: 1 Following an ESAS actuation the CBOT is directed to perform RT-10 to verify proper actuation. Step G states: " Verify each component properly actuat-d on C16, CIS, and C26, except those overridden in presions steps."

Ilow is this accomplished for containment isc Jon valves?

a. Verify all containment isolation valve " closed" indication lights are illuminated,

b. Compare containment isolation valve positions to positions listed on chart in RT-10.

c. All containment isolation valves have the same color coding for case of verification.

d. Verify containment isolation valves are in position marked with black tape background-Page 37 ,

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ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 84 QID: 0106 Point Value: 1 Given:

- Unit at 100% power

- A" OTSG pressure initiate bistable trips in "A" EFIC cabinet 4

- B" OTSG pressure initiate bistable trips in "C" EFIC cabinet What willthe EFIC responsebe?

a. Half trip onboth trains

b. Train "A" MSLl/EFW actuation

c. Train "B" MSLI/EFW 'ac'tuation

d. Both trains will actuate MSLI I

Question No. 85 QID: 0107 Point Value: 1 The plant is operating at 60% power with Delta Tc H/A station in Hand. All other ICS stations are in Auto.

If one RCP has to be tripped due to high winding temperature, how will the ICS respond?

Assume no operator action other than tripping the RCP.

a. The ICS will runback the plant to 45% lyd at 50%/ min.

b. The Delta Tc Integral is blocked so no re-ratio of FW occurs

c. Demand is less than the RCP runback limit, no changes occur to FW.

d. The RC flow difference will re-ratio the FW flow demand.

p.

Page 38 l

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ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 86 QID: 0108 Point Value: 1 Given:

Plant operating at 100% power.

The instnanent air line to Turbine Byapss Valve (CV-6688) valve operator is severed during pre-outage scaffolding erection.

What affect will this have on CV-6683 operation?

a. CV 6688 fails OPEN.

~"

b. CV6688 fails AS-IS.

c. CV-6688 fails CLOSED.

d. CV-6688 will function normally.

Question No. 87 QID: 0109 Point Value: 1 Given:

- Plant operatmg at 95% power.

- Group 6 programmer's W 24v power supply has failed.

What would h p ifIAC tests DROPS channel 27

a. Nothing, DROPS outputs are defeated during testing.

b. An AMSAC test would result in tripping the turbine.

c. A DSS test would cause Goup 6 rods to drop.

d. A DSS test would cause a turtune trip.

l Page 39

l ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 88 QID: 0110 Point Value: 1

'Ihe ONLY action statement in Tech Specs regarding Hydrogen concentration instruments operability (3.14.4) states:

-" With one of two hydrogen concentration instruments inoperable restore the inoperable analyzer to OPERABLE status within 30 days or be in at least hot shutdown within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />."

Which of the following actions would be applicable if BOTH hydrogen concentration instruments were inoperable?

a. Within one hour. restore at least one inoperable analyzer to operable status.

b. T="-*aly invoke Technical Specification 3.03.

c. Restore at least one anafyr'$r to operable status in 15 days or be in Hot Standby within 6 hrs.

d. Within two hours, initiate action to place the unit in Hot Standby within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

Question No. 89 . QID: 0111 Polet Value: 1 A SmallBreak LOCA has occurred.

- RCS pressure 1890 psig and fathng slowly

- RB pressure is 1.5 psig and rising slowly Which of the following operator actions is appropriate for these conditions?

a. Manually actuate ESAS and announce this action to CR personnel

b. Obtain concurrence from CRS, then manually actuate ESAS and make announcement.

c. A==_ r. au and imminent ESAS actuation, then verLt proper automatic actuation.

d. Obtain concurrence from CRS and then bypass ESAS prior to automatic actuation.

Page 40

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l ANO Unit 1 - 1998 Reactor Operator License Exam Questlom No. 90 QID: 0112 Point Value: 1 During a FW transient, the CBOT manually controls FW to stabilize the plant.

Rx power is 101.5% for approximately 10 minutes while the plant is brought under control.

Is this acceptable or ; = q;41e7

a. This'is acceptable to mitigate transients for short periods of time per Conduct of Operations.

b. This is == Wale due to limitations on our fuel as specified by Babcock & Wilcox.

c. This is acceptable for short periods of time as specified by NRC correspondence with Licensing.

d. This is ; = - , ante due to exceeding the maximum thermal output in our operating license.

Question No. 91 QID: 0114 Point Value: 1 Which of the following actions involving a carded MCC breaker is allowable per 1000.027, Hold and Caution Card Control?

a. Removing "a" and "b" contact terminations.

b. Racking a breaker up and down but not closing it.

c. Leaving the door open as long as breaker is removed

d. Performing a PM to lubricate contacts.

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ANO Unit 1 - 1998 Reactor Operator Licensa Exara j Questlos No. 92 QID: 0115 Pniet Vase: 1 i

Section 3.0 of Tech Specs contains provisions for exceeding a Limiting Condition of Operation where an action statement does not exist. .l l Section 2.0 does NOT contain any action for exceeding a safety limit. l i

What action would you take if you discover that a safety limit had been exceeded?

l l

a. Immediately begin a rapid shutdown at a rate of at least 10%/ min.

l l

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l l b. Maintain stable plant conditions until management and engineering determine a correct course of action. -

l C. Immediately begin a slow, conservative shutdown at <5%/ min.

d. Immadiately trip the reacto'r and venfy immediate actions.

Question No. 93 QID: 0116 Point Value: 1 Dunng an INITIAL approach to ciriticality, if criticality is NOT achieved within of the ECP, insert and .

L

a. plus or minus 1.0% delta k/k l control rods to achieve 1.5% SD margin establish hot shutdown conditions'

b. ' plus or minus 1.0% delta k/k regulating groups I notify ReactorEndneering j i

c. plus or minus 0.5% delta k/k l control rods to achieve 1.5% SD margm  ;

venfycalculation j

d. plus or minus 0.5% delta k/k i reg i=*ia: groups verify caladation Page 42 l

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ANO Unit 1 - 1998 Reactor Operator License Exam 1

Question No. 94 QID: 0118 Point Value: 1 ]

Which of the following describes a Channnel Check as defined by Tech Specs?

a. A test oflogic elements in a protection channel to verify their associated trip action.

b. Adjustment of a channel such that it responds accurately to known values.  ;

c. Verification of acceptable channel perfonnance by observation of other available indications.  !

I

d. Injection of a simulated signal into the channel to verify proper response.

l Question No. 95 'QID: 0120 Point Value: 1 ,

Given:

- A Site Area Einergency has been declared on Unit 1. l

- An Emergency Medical Team must enter a 50 REM /hr area to rescue a critically injured employee.

-The team members have NO previous exposure for the year. l, Which of the following is the MAXIMUM time the team can stay in this area? f a.15 minutes f

b. 30 minutes 1- c. 45 minutes

d. 60 minutes l l t

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

ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 96 QlD: 0121 Point Value: 1 Unit One refuelingis in progress. ,

A Unit Two WCO resource shared fuel handler is assigned to the Main Fuel Bridge from 0700 to 1200 on Friday, September 11.

The localarea dose rateis 25 mR/hr.

He has an accumulated yearly dose of 1.8 Rem.

Whose permission must the WCO have to work on the Main Fuel Bridge?

a. Exceeding the Administrative Dose ControlImel can NOT be authorized.

b. Manager, Radiation Protection and Chemistry AND General Manager, Plant Operations

c. Manager, Radiation Protection and Chemistry AND General Manager, Plant Operations AND Vice President, Operations

d. Manager, Radiation Protection and Chemistry Question No. 97 QID: 0122 Point Value: 1 A WCO is assigned to align "A" Decay Heat Removal during a shutdown.

It is estimated thejob will take 40 minutes.

High RCS activity has created a whole body dose rate of 2.5 R/hr in this area.

The WCO has an accumulated exposure of 0.225 Rem for the year.

The WCO makes the statement that he can complete thejob without exceeding exposure limits.

Do you agree or disagree with the WCO's statement?

a. Agree, the WCO will NOT receive a dose sufficient to exceed the Administrative Dose ControlIntl.

b. Disagree, the WCO will exceed the Administrative Dose ControlIcel after 38 minutes.

c. Agree, the WCO is allowed to exceed the Administrative Dose ControlIxvel by a maximum of 500 mR.

d. Disagree, the WCO will exaed the Administrative Dose Control 1;,' vel after 12 minutes.

Page 44

ANO Unit 1 - 1998 Reactor Operator License Exam Question No. 98 QID: 0124 Point Value: 1 The reactor was at 90% power,100% flow, and a core delta T of 43*F when a Blackout occurred.

Natural circulation was established with Tave at 545'F and a core delta T of 40*F.

With natural circulation cooldown establisled, you would expect to see:

a. core exit temperature continuing to deum

b. core delta T continuing to increase

c. demand for EFW decrease to zero.

d. TBVs opening periodically to maintain pressure.

Question No. 99 QIP: 0125 Point Value: 1 During an Alternate Shutdown requiring an immediate control room evacuation, which of following is performed by an extra operator (RO#1 or #2)? r

a. Start and load EDG's to power vital components

b. Start and stop HPI pump to maintain PZR level

c. Throttle EFW to SG's to maintain heat sink

d. Strip 6900vH1 and H2 buses Page 45

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

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l ANO Unit 1 - 1998 Reactor Operator License Exam Question No.100 QID: 0127 Point Value: 1 t

Given:

-Large Break LOCAin progress

- Core exit temperatures indicate an ICC condition in Region II of Figure 4 l (Figure 4 is on following page)

-EFW is available CoralMng the above conditions, which of the following strategies would be used in 1202.005, Inadequate Core Cooling, to lower core exit temperatures from Region II to Region I of Figure 4?

)

a. Raise primary to secondary Delta-T to 90 to 110'F.

b. Start and run one RCP in each loop.

c. Open loop, Rx vessel, and PZR high point vents.

d. Open ERV until RCS to SG DP is less than or equal to 100 psig.  ;

i 9

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Page 46 i l

1202.013 E0P FIGURES REV 2 PAGE 4 cf 6 I 1

1 1

FIGURE 4 1

. . Core Exit Thermocouple Temperature for I Inadequate Core Cooling l 2600 .. . . . . . . .

..l......... ......u.. ...

..4.. .. ..

wm uur

...i.SUBCOOLED._!.J SUPERHEATED mg=

4 ..

.7..,....

., p. .. . 7.. .g $.3 7{p44g g. g . 44;. yg

.44;.e .

4 .; 4-

..l... ..?..{ .. ...l. .

l:

p.

..{.q ! ~. Je g ..

4.J{'. 44 gf.,; .gag

.f' y;.aa.

.Lg.4m a

g 9 aug

/g gr:4.;, y

_m .

pp i nh A

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...t. . l .. . l ..;

...l k. ' 44,.]@e. 444,.4 kgt et. j;. 14 ' --

ACs?.

2200 a. SATURATION .9.'g

. .. ' .' - --". Curve 1 '.

mys.4 ..; .

.-..n y ,a., . - .4m4 hu ,v g, %yt^fy -

i UNC

4. 6m +,

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+ -

. TCMD >1400gF .& ,e,.;  :

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..j... .... . 9 a

. . .p. .; . . . .t .

i'~ Of.a.=*

1. t t 9t Y * ;'N , - . d. +.

2 E4 r .

u.,**w.nw.,

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+^<- ' uwe.e.

d . ^M$

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4 i .JJa.

.I N.4  :*.;g

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c c4+ m..:.4A..r.w.,

<L 4 . 4 syf4. .;f. n++tr f .s. ^ vp-g

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ll REGION 1C IREGION 2I. 1% 3 REGION 36 nM.,C WP, E

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. .w. . i 44 ....gg gg. gg;g;;. g.. ggjl gg gg

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O.

'i 7.. 11d:d;.. i' ,Pi kkJ4Ms' M,EtM$.

.L. . . 3.. t ....- i_4.. , . ..... t' .{.1, 4 ?tsu. 4 #.24.m

. 1 N _ w% A m.gw.% mmg.

m 1000 -

o , .. .j..j .  ;..y... _j.y..p g.. gg j;gg ggg g;hy wN et+=;

c- .. . . . ;..,..g.t- 7te+- t.Q:q.. tm.y, m ge-; yy..

Curve 2  ?

t..-

3 . . .[. .g. y" - %,

800

- , ,-t-. - + e- , - ter-. .e Tcan>1800 F ;__

..;. 4_ 2 4.a .L ..p.;4 5  : 7 _ .

g.~.. .y.gig g" . mgg gg

. . } . _ . . .(( .j..j g.. "pp.p g. .q. j'.ad;.f

.l. .._ n .

. b 'M

..f...0..' .E I ' ' [ .. .M Is . ., l k*b3.51,d.1 "*'*h.;

• N hi N6. ..

~^ * **^ -* '

• * "' f*hhh "

600 g"g ggg

4.  ;...

' ..j' . a-

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' j..:g gg gpgg gg g nQ QQ QQ:, Q$y. g.g Q

..l... -f .

L  %:4 4.[Q v tf:7n-s*w g.Qf 499

- r-r- xm yn a.w w u. ,, . . .

_.: :. r w ". Jaaa:  ;.u.,a.a rr n: uw * =

g gjg

}g.gg gg{ gg Qg Q.h ;.Qga. Qui

.d..i .. '

1. _ .. . . ~85 _ . . , . .- .

. , W+ k 9'D

• J. f , .- f'b -l gjg(.'g g%g' ;, .g

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~~...,.7- gl}y p'O.- 7.j 7.b -~?? g',.. g ' 'O -.g,y Q. .

pqgg 400 500 600 700 800 900 1000 1100 1200 1300 Core' Exit Thermocouple Temperature (20'F Increments)

1998 ANO Unit 1 Initial RO Exam Key Question No.1 QID: 0001 Point Value: 1 Answen

b. Transfer Group 7, Rod 3 to the Aux Bus and pull programmer control fuses for the Aux Power Supply.

Question No. 2 QID: 0002 Point Value: 1 Answer:

c. Annunciator "RCP TRIP" (K08-A6) is clear, RCS flow is lowering and "B" RCP amperage indicates 0 amps on SPDS.

Question No. J QID: 0004 Point Value: 1 Answen

b. CV-1000 should be cycled open and closed during cooldown to prevent thermal binding of the valve.

Question No. 4 QID: 0005 Point Value: 1 Answer:

b. Set the batch controller to the maximum batch size setting of 999999 gallons and commence adding boric acid to tie'make up tank.

Question No. 5 QID: 0007 Point Value: 1 Answen

b. Within 2 minutes Question No. 6 QID: 0009 Point Value: 1 Answen

b. Start Aux hary Feedwater Pump, P-75, and control OTSG levels at 20 to 40 inches using the Startup Control Valves.

Question No. 7 QID: 0010 Point Value: 1 Answer:

d. Trip the turbine if vacuum falls below 24.5 inches.

Question No. 8 QID: 0011 Polet Value: 1 Answer:

a. less of subcooling margin, no HPI available, and reactor vessel head voids are indicated.

l l

1998 ANO Unit 1 Initial RO Exam Key Question No. P QID: 0012 Point Value: 1 Answen

b. Failed 50% open.

Question No.10 QID: 0013 Point Value: 1 Answen

b. Increase inICW Surge Tank level l Question No.11 QID: 0014 Point Value: 1 Answen

d. Refer to the ANO Pre-Fire Plan for the affected fire zone for a listing of affected components.

Question No.12 QID: 0015 Point Value: 1 Answen

c. Manually initiate Iligh Pressure Injection to compress the pressurizer steam bubble.

Question No.13 QID: 0017 Point Value: 1 Answen

b. SelfPowered Neutron Detector (SPND) outputs demonstrate progressive high and low swings.

Question No.14 QID: 0018 Point Value: 1 Answen

c. To prevent exceeding a 70% void fraction and possible core uncovery.

Questlom No.15 QID: 0019 Point Value: 1 Answen I d. A marked drop by 40% in the GROSS / IODINE ratio.

Question No.16 QID: 0020 Point Value: 1 l

Answer:

a. Place the SG *B" FW Temp signal select switch to the (Y) position.

I

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1998 ANO Unit 1 Initial RO Exam Key l

Question No.17 QID: 0021 Point Value: 1 I 1

. Answen )

d. Control rods will withdraw and main feedwater flows will decrease i Question No.18 ~QID: 0022 Point Value: 1 Answen i

b. A dropped rod at <2% power.

Question No.19 QID: 0023 Point Value: 1 Answen

a. Manually actuate "A" MSLI and EFW.

Questlom No. 20 QID: 0024 Point Value: 1 l l

Answen

c. The speed of the control rods and core age.

Question No. 21 QID: 0025 Point Value: 1 Answen I

a. Mainturbine Anticipatorytrip.

Question No. 22 QID: 0027 Point Value: 1 Answen

c. Approxirnately239'F Question No. 23 QID: 0028 Point Value: 1 Answen

d. No cooldownlimits apply Question No. 24 QID: 0029 Point Value: 1 Answen

a. RefluxBoiling l

l

1998 ANO Unit 1 Initial RO Exam Key Question No. 25 QID: 0030 Point Value: 1 Answen

a. Restoration of adequate subcooling margin.

Question No. 26 QID: 0031 Point Value: 1 Answen

d. The generator lockout relay trip will cause a " fast transfer" to SU-2 transformer and applicable loads will be shed to limit the loading on SU-2 transformer.

Question No. 27 QID: 0032 Point Value: 1 Answen ,

c. Loss ofInstrument Airin LNPR Question No. 28 QID: 0033 Point Value: 1 Answen

d. Stabilize flow by throttling one of the discharge flowpath vahes.

Question No. 29 QID: 0034 Point Value: 1 Answen a, Relays in the turbine trip circuitry energize the Auto-Stop Oil trip and Backup Trip Solenoids.

Question No. 30 QID: 0036 Point Value: 1 Answen

c. Continue reactor startup per 1102.008, Approach to Criticality.

Question No. 31 QID: 0037 Point Value: 1 Answen

c. To minimize the RCS leak rate into the steam generator.

l Question No. 32 QID: 0038 Point Value: 1 Answen i b. Less than or equal to 100 *F/ hour.

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l

i 1998 ANO Unit 1 Initial RO Exam Key Questloa No. JJ QID: 0039 Point Value: 1 Answer:

b. The main feedwater block valves will close in slow speed once power goes below 80%.

Question No. 34 QID: 0040 Point Value: 1 Answen

c. Start the pump, run the pump for 10 seconds, then secure the pump.

Question No. JJ QID: 0041 Point Value: 1 Answen

c. Select main turbine control to TURBINE MANUAL and close the governor valves in fast speed.

Questloa No. 36 QID: 0042 Point Value: 1 Answen j c. Stop the release and adjust the setpoint to the correct value.

i l Q A No.37 QID: 0043 Point Value: 1 a

)

Answen

d. Reset RE-4830 and re-establish T-18B gaseous release.

]

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Question No. 38 QID: 0046 Point Value: 1 Answen

! c. Close ACWLoopisolation(CV-3643). '

t )

Qwlam No. 39 QID: 0047 Point Value: 1 Answen

d. Following an evaluation which will allow normal RCS pressure control to resume

!_ Question No. 40 QID: 0048 Polet Value: 1 1

Answen

c. mechanicaloverspeed trip

I a

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

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1992 ANO Unit 1 Initial RO Exam Key ,

l l

Question No. 41 QID: 0050 Point Value: 1 l i

Answen l

a. Continue the rapid plant shutdown at 4 % per minute.

l Question No. 42 QID: 0052 Point Value: 1 Answen

b. 8 to 12 Ic,urs l

Question No. 43 QID: 0053 Point Value: 1 Answen

b. Main steamline breakinside RB

.s l

Questlos No. 44 QID: 0055 Point Value:' 1 Answer:

d. To prevent inaccurate readings on the batch totalizer. j i

l Question No. 45 QID: 0057 Point Value: 1 l Answen I

b. Removal of the RB Pressure Buffer Amplifier from Analog Channel 1.

l Questlom No. 46 QID: 0058 Point Value: 1 Answen

b. The Intermediate Range channels are overcompensated.

l Question No. 47 QID: 0059 Point Value: 1 j Answen

d. CET readings indicate superheat.

l I

l Question No. 48 QID: 0060 Point Value: 1 l Answer:

i a. B5, B6 and B7 j

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i

l 1998 ANO Unit 1 Initial RO Exam Key Question No. 49 QID: 0062 Point Value: 1 Answer:

b. Trip P-2C, monitor ICS mnback to 40% power and dispatch the fire brigade per 1203.034, Smoke, Fire or Explosion.

Question No. 50 QID: 0063 Point Value: 1 Answen

d. Feedwater loop A demand is greater than feedwater loop B demand.

l l

Question No. 51 QID: 0064 Point Value: 1 Answen

c. EFIC train B will actuate EFW train A, EFW pump P-7A is running.

Question No. 52 QID: 0065 Point Value: 1 Answen

b. A loss of power to RI-4642 will cause a high radiation alarm signal which will automatically ternunate the release.

Question No. 55 QID: 0067 Point Value: 1 Answen

b. Keep C119 aligned to T-17 and commence makeup tank venting operations, align C119 to T-18C if high H2/02 concentrations occur.

Question No. 54 QID: 0068 Point Value: 1 Answen

a. AllIsolation dampers CLOSED, VSF-8A/B OFF,2VSF-8A/B ON, VSF-9 ON and 2VSF-9 OFF.

Question No. 55 QID: 0069 Point Value: 1 Answen

a. OTSG tube rupture and stuck open MSSV Question No. 56 QID: 0070 Point Value: 1 Answen

c. High PressureInjection System

1998 ANO Unit 1 Initial RO Exam Key Question No. 57 QID: 0071 Point Value: 1 Answen

a. Throttle "C" flow to within 20 gpm of"B" Question No. 58 QID: 0072 Point Value: 1 Answen

d. Trip the reactor Qwlam No. 59 QID: 0073 Point Value: 1 Answen

c. PZR level decreased due to cooldown Question No. 60 QID: 0075 Point Value: 1 Answen

d. IAC deenergizes "C" RPS cabinet and "A" MFW pump contact buffer trip test switch operated in "A" cabinet.

Question No. 61 QID: 0076 Point Value: 1 Answen.

c. Reduce power to 60% of MWt for RCP combination then withdraw rod, keeping rate <3%/hr.

Question No. 62 QID: 0077 Point Value: 1 Answen

b. Imop ATave due toIoop B flow Question No. 63 QID: 0078 Point Value: 1 Answer:

c. To prevent overload of the EDGs.

Question No. 64 QID: 0079 Point Value: 1 Answen

c. Use vent flowpath via RB leak detector.

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'1998 ANO Unit 1 Initial RO Exam Key l

Question No. 65 QID: 0080 Polet Value: 1

, Answen

d. Fuel racks designed with boraflex plates and adequate spacing.

Question No. 66 QID: 0081 Point Value: 1 Answen

a. 2,3, and 7 Question No. 67 QID: 0083 Point Value: 1 Answen

a. Reactor power will INCREASE, temperature will DECREASE, and pressure will DECREASE. l Question No. 66 QID: 0084 Point Value: 1 Answen

d. EDG 2 stopped with A4 bus deenergized Question No. 69 QID: 0086 Potat Value: 1 Answen

b. PanelRAI Question No. 70 QID: 0088 Point Value: 1 Answen

d. EDG willinunediately start cranking.

Question No. 71 QID: 0089 Polet Value: 1 l Answen

a. . Verify sio flow on Discharge to Flume, FI-4642  :

l Questlom No. 72 QID: 0090 Polet Value: 1

'Answen  ;

c. ' FIRE",K12-Al

1998 ANO Unit 1 Initial RO Exam Key Question No. 73 QlD: 0091 Point Value: 1 Answer:

c. 50*F/hr Questlom No. 74 QID: 0092 Point Value: 1 Answen

a. The interlock will allow valve opening.

Questloa No. 75 QID: 0093 Point Value: 1 Answen

c. Code safety tailpipe temperature 200 'F Question No. 76 QID: 0094 Point Value: 1 Answen

b. Bypass Control valve CV-2287 will open to maintain flow to seal coolers.

Questlom No. 77 QID: 0096 Point Value: 1 Answen

b. Hydrogen Recombiners Question No. 78 QID: 0097 Polat Value: 1 Answen

a. Prevents a fuel assembly from being dropped while grapple is engaged.

Question No. 79 QID: 0099 Point Value: 1 Answen

d. Reference counter indicates GV demand voltage.

Question No. 80 QID: 0100 Polat Value: 1 Answen

c. PZR makeup flow would drop.

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

1998 ANO Unit 1 Initial RO Exam Key l

Question No. 81 QID: 0101 Point Value: 1 l l

Answen  ;

c. Isolate both Condenser Vacuum Pump coolers l

)

l l

Question No. 82 QID: 0102 Point Value: 1 l

l Answen

c. Breathing AirtoInst. AirX-connection,IIS-5503 )

l Question No. 83 QID: 0104 Point Value: 1 l i

Answen j l d. Verify containment isolation valves are in position marked with black tape background. j

\ ..

l Question No. 84 QID: 0106 Point Value: 1 Answen ,

b. Train "A" MSLI/EFW actuation 1

l Question No. 85 QID: 0107 Point Value: 1 Answen

d. The RC flow difference will re-ratio the FW flow demand.  !

I Question No. 86 QID: 0108 Polet Value: 1 Answen

a. CV-6688 fails OPEN.

Questlos No. 87 QID: 0109 Point Value: 1 Answen

c. A DSS test would cause Goup 6 rods to drop.

Question No. 88 QID: 0110 Point Value: 1 Answen

b. Immediately invoke Technical Specification 3.03.

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1998 ANO Unit 1 Initial RO Exam Key Question No. 89 QID: 0111 Point Value: 1 Answen

b. Obtain permission from CRS, then manually actuate ESAS and make announcement.

Question No. 90 QID: 0112 Point Value: 1 Answen ,

d. This is unacceptable due to exceeding the maximum thermal output in our operating license.

l Question No. 91 QID: 0114 Point Value: 1 Answen

d. Performing a PM to lubricate mutacts.

Question No. 92 QID: 0115 Point Value: 1 Answen

d. Immediately trip the reactor and verify immediate actions.

Question No. 93 QID: 0116 Point Value: 1 Answen

c. plus or minus 0.5% delta k/k control rods to achieve 1.5% SD margin verify calculation Question No. 94 QID: 0118 Point Value: 1 Answen

c. Verification of acceptable channel performance by observation of other availabic indications.

Question No. 95 QID: 0120 Point Value: 1 Answen

b. 30 minutes Question No. 96 QID: 0121 Point Value: 1 Answen l d. Manager, Radiation Protection and t'hmiMry L

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1998 ANO Unit iInitial RO Exam Key Question No. 97 QID: 0122 Polat Value: 1 Answer:

a. Agree, the WCO will NOT receive a dose sufficient to exceed the Administrative Dose ControlIntl.

Question No. 98 QID: 0124 Point Value: 1 Answer:

a. core exit temperature continuing to decrease Question No. 99 QID: 0125 Point Value: 1 Answer:

c. Throttle EFW to SG's to maintain heat sink Questica No.100 QID: 0127 Point Value: 1 Answer:

a. Raise primary to secondary Delta-T to 90 to 110*F.

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ES-401 Site-Specific Written Examinhtion Form ES-401-7 Cover Sheet U.S. Nuclear Regulatory Commission Site-Specific l Written Examination l

l AppEcantInformation Name: -

Region: IV Date: Facility / Unit ANOUnitOne Ucense Level: SRO ReactorType: BW StartTime: FinishTorne:

Instructions Use the answer sheets provided to document your answers. Staple this cover sheet on top of the answer sheets. The passing grade requires a final grade of at least 80.00 percent. Examination papers will be collected four hours after the examination starts.

ApplicantCertification All work done on this examination is my own. I have neither given nor received aid.

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Applicanfs Signature Results Examination Value /00 Points '

Applicanfs Score Points Applicant's Grade Percent

- NUREG-1021 39 of 39 Interim Rev.8, January 1997 l

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i ANO Unit 1 - 1998 Senior Reactor Operator License Exam l

Question No.1 QID: 0001 Point Value: 1 The following plant conditions exist:

A manual plant runback to 40% of 902 MWe has been completed.

Group 7, Red 3, stator temperature is 193 T and rising.

All other Controi Rod stator 6,,..hus are normal A stator temperature HI alarm on the plant c+ei-ter alarm screen is in alarm.  ;

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How will the Group 7, Rod 3 stator W. hue be reduced?

a. Manually trip the reactor due to Group 7, Rod 3 stator temperature exceeding 190 T.

b. Transfer Group 7, Rod 3 to the Aux Bus and pull programmer control fuses for the Aux Power Supply.

c. Drop Group 7 Rod 3 by remonng the six stator fuses for the rod in the CRD transfer cabinet.

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d. Transfer Group 7, Rod 3 to the DC Hold Bus to reduce stator current.  !

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Question No. 2 QID: 0003 Point Value: 1 The followmg plant conditions exist:

Reactoris tripped l

. All4 RCPs are OFF RCS pressureis 1950 psig and rising l RCS Thatis 560 Y RCS Tooldis $45 Y "A" and "B" OTSG pressures are ~980 psig The CBOR reports that RT-5 (Verification of EFW Actustion and Control) is completed. Which of the j following desenks the expected EFIC system response?

a. OTSG levels will be rising at a rate of-4 inches per minute to 370 to 410 inches

b. OTSG levels will be rising at a rate of 4 inches per minute to 300 to 340 inches.

c. OTSG levels will be rising at a rate of 4 inches per minute to 370 to 410 inches.

d. OTSG levels will be rising at a rate of-4 inches per minute to 300 to 340 inches.

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ANO Unit 1 - 1998 SenSr Reactor Operator License Exam Questlom No. J QID: 0004 Point Value: 1 The plant is in a degraded power situation with natural circulation cooldown in progress. The ERV isolation valve CV-1000 has been closed due to leakage past the ERV. Which of the following best describes the appropriate action concerning operation of CV-1000 during the cooldown?

a. CV-1000 should remain closed and the cooldown secured until repairs to the ERV are completed. ,

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b. CV-1000 should be cycled open and closed during cooldown to prevent thermal binding of the valve.

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c. CV-1000 should be opened to allow the pressurizer to go solid and transition to a HPI Cooldown.

d. CV-1000 should be deenergized and hold carded to prevent operation of the valve during cooldown.

Question No. 4 QID: 0006 Point Value: 1 I

Following a reactor trip, which of the following plant conditions would require " Emergency Boration"?

a. All rods are fully inserted into the core and reactor power is dropping.

b. Use of the CRD Power Supply Breaker Trip Pushbuttons is required to trip the reactor.

c. One safety group control rod fails to fully insert and reactor power is dropping.

d. Failure of more than one rod to fully insert into the core and reactor power dropping.

Question No. J QID: 0008 Polet Value: 1 Given:

- Process Radiation Monitor RI-2236, Nuclear ICW, is in alarm.

-NucicarICW flow rate is >3100 gpm

-Iocal reports of Nuclear ICW Surge Tank overflowing Which of the following components would be capable of causing the above conditions?

a. RCP Seal Return Coolers

b. SpentFuelCoolers

c. Letdown Coolers

d. Pressurizer Sample Cooier Page 2

ANO Unit 1 - 1998 Senior Reactor Operator License Exam Questlos No. 6 QID: 0009 Polet Value: 1 ,

Given the following plant conditions, choose the correct operator response: .

- A loss of both Main Feedwater Pumps has caused an automatic reactor trip. 1

- Annunciator K02-B6, A3 L.O. RELAY'IRIP, is in alarm.  !

- Steam Driven EFW Pump, P-7A, is tagged out and disassembled for corrective maintenance. ,

- OTSG levels are at 15 inches and slowly dropping. l

a. Take manual control of the Electric EFW Pump, P-7B, now control valves and control OTSG levels . l i

at 20 to 40 inches.

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b. Start Auxiliary Feedwater Pump, P-75, and control OTSG levels at 20 to 40 inches using the Startup I Control Valves. ..  !

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c. Close the MFW Isolation Valves to prevent feeding with a Condensate Pump and allow the OTSGs l

- to boil dry.

d. Lower CTSG pressuit to feed the OTSGs using a Condensate Pump to establish primary to secondary heat transfer.

1 Question No. 7 QID: 0010 Point Value: 1 Given the following plant conditions, choose the appropriate operator actions:

-Plantis operating at 40% power

- E-11 A North Waterbox is OOS for maintenance

- Condenser vacuum is degrading rapidly

a. Trip the reactor and turbine if vacuum falls below 26.5 inches Hg.

b. Trip the reactor and turbine if vacuum falls below 24.5 inches Hg.

c. Trip the turbine if vacuum falls below 26.5 inches Hg.

d. Trip the turbine if vacuum falls below 24.5 inches Hg.

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l ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No. 8 QID: 0011 Point Value: 1 Due to severe weather the plant is in a station blackout condition. 'Ihe steam driven emergency feedwater pump (P-7A) is feeding both steam generators. Under what conditions would an " Emergency RCS Cooldown" be performed?

a. Loss of subcooling margin, no IIPI available, and reactor vessel head voids are indicated.

b. Reactor vessel head voids are indicated and Core Exit Thermocouple temperature > 610 'F.

c. Iass of subcooling margin and steam generator tube to shell delta-T >100 *F (tubes colder).

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d. Com Exit Thermocouple temperature > 610 'F and steam generator tube to shell delta-T >100 *F (tubes colder). ..

Question No. 9 QID: 0012 Point Value: I Given the following plant conditions:

-Reactoris tripped

- NNI X Instrument Power Supply Status lights on Cl3 are OFF l - NNI Y Instrument Power Supply Status lights on Cl3 are ON What is the expected position of CV-1235, the pressunzer level control valve?

a. Failed 100% open.

b. Failed 50% open.

c. Failed 0% open.

d. Functioning normal Page 4

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ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No.10 QID: 0013 Point Value: 1 Which of the following would indice.e a tube leak in Nuclear ICW Cooler, E28C7

a. Increasein SW system activity

b. IncreaseinICW Surge Tanklevel

c. Increasein SW header pressure

d. Decrease in Nuclear ICW header flow 1

Question No,11 ' UID: 0014 Polet Value: 1 l

A fire watch reported a fire in the Lower South Electrical Equipment Room and the fire brigade has been l dispatched. How can the control room staff quickly determine potentially affected components?

1

a. Conduct control board walkdowns and refer to the plant labeling to assist in determination.

b. Refer to procedure 1107.001, Electrical System Operations, breaker alignment attachments.

c. Deternune affected components from the Fire Zone drawings maintained in the control room.

d. Refer to 0.c ANO Pre-Fire Plan for the affected fire zone for a listing of affected components.

Question No.12 QID: 0016 Point Value: 1 To coordinate ' plant activities during a remote shutdown, what is the primary means of communications?

a. Dial 111 on the plant telephone system to access the pasty line.

b. Portable radios available in the alternate shutdown cabinet.

c. The plant gaitronics phoncs located throughout the plant.

d. Cellular phones available in the control room extension.

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ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No.13 QID: 0017 Polat Value: 1 A large break LOCA and several equipment failures have placed the plant into an inadequate core cooling condition. Which of the following provides the best indication that core danage has occured?

a. Core Exit 'Ihermocouple temperatures on the ICCMDS mimic display are flashing and rising.

b. Self Powered Neutron Detector (SPND) outputs demonstrate progressive high and low swings.

c. Source Range Monitors indicate higher than normal readings by more than a factor of ten.

d. The Reactor VesselI.evel Monitoring System indicates voids present in the reactor vessel head.

Questlom No.14 QID: 0018 Point Value: 1 ,

Following a reactor trip the plant experienms a loss of chling margin. Why is it desirable to secure all reactor coolant pumps within 2 minutes following a loss of subcooling margin?

a. To allow the void coefficient of reactivity to add negitive reactivity to the core.

b. To protect the mechanical seals on the reactor coolant pumps.

c. To prevent exmeding a 70% void fraction and possible core uncovery,

d. To reduce operator burden by climinating the need for RCP services.

Question No.15 QID: 0019 Point Value: 1 Fuel pin leakage has caused lugher than normal actisity in the reactor coolant system. Which of the following indications on the Failed Fuel Monitor (RI-I237) would be indicative of failed fuel and require power reduction?

a. A marked rise by 20% in the IODINF/ GROSS ratio.

b. A marked rise by 40% in the GROSS / LODINE ratio.

c. Amarked dropby20%intheIODINFJGROSS ratio.

d. A marked drop by 40% in the GROSS / IODINE ratio.

Page 6

ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No.16 QID: 0020 Point Value: 1 -

Given the following indications / alarms:

-SASS Mismatch alarm (fast flash)

-SG BTU Limit alarm (slow flash)

- SG "B" FW Temp signal select switch selected to SASS Enable with the white indicating light out and the blue "Y" light on.

What operatoractionis required?

a. Place the SG "B" FW Temp signal select switch to the "Y" position.

b. Depress the Auto pushbutton for SG "B" FW Temp on the SASS panel in C47-2.

c. No action swunry, SASS has automatically transferred to "Y" NNI.

d. Place both FW loop demands in manual.

Question No.17 QID: 0021 Point Value: 1 The plant is operating at 100% power. A failure of an ICS module downstream of the SASS circuitry causes the Nuclear Instrumentation input to the Reactor Demand station to fail tow nesulting in a large negative neutron error. A= =iaa no operator action, how will this failure affect control rods and main feedwater flows?

a. Control rods will insert and main feedwater flows will increase.

b. Control rods will withdraw and main feedwater flows will increase

c. Control rods will insert and main feedwater flows will decrease

d. Control rods will withdraw and main feedwater Dows will decrease Page 7

ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No.18 QID: 0022 Point Value: 1 Which of the following dropped or misaligned control rod scenarios would require a reactor shutdown instead of a control rod recovery attempt?

a. A fully dropped rod at 38% power.

b. A dropped rod at <2% power

c. A partially dropped rod at 10% power.

d. A rod misaligned for >24 hours.

Question No.19 QID: 0023 Polat Value: 1 The following conditions exist immediately after a reactor trip:

- Group 2, Rod 4 failed to fully insert into the core.

- RCS pressure is at 1750 psig and trending down

- Fiwhcilevel is at 50 inches and trending down

- A OTSG pressure is at 880 psig and trending down

- B OTSG pressure is at 950 psig and trending down

- Submoling margin is at 70 'F and trending up slowly Choose the appropriate operator response

a. Manually actuate "A" MSLI and EFW.

b. Commence emergency boration per RT-12.

c. Trip allReactor Coolant Pumps

d. Initiate High Pressure Injection per RT-2.

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1 ANO Unit 1 - 1998 Senior Reactor Operator License Exam i

Question No. 20 QID: 0024 Point Value: 1 The plant is operating at 100% power when a single rod drops and fully inserts into the core. ICS is in full automatic and commences a plant runback. Which of the following will determine how fast plant power can change?

a. The operator set rate ofchange.

b. The pre-set ICS runback rate of change.

c. The speed of the control rods and core age,

d. The rate ofchange in main feedwater flow.

Questlom No. 21 Q1D: 0026 Point Value: 1 Which of the followmg best describes the purpose of adding the Anticipatory Trips to the Reactor Protection System original design?

a. To limit plant cooldown followmg a loss of heat sink.

b. To limit reactor power to prevent exceeding linear heat rate limits.

c. To limit reactor power to prevent exceeding DNBR limits.

d. To limit plant heatup followmg a loss of heat sink.

Questlom No. 22 QID: 0028 Point Value: 1 A small break LOCA cooldown is in progress with subcooling margin less than adequate.

Which of the following cooldown limits apply?

a.100 T/hr when >300 T

b. 50 T/hr when 300 - 170 T

c. 25 T/hr when < 170 T

d. No cooldownlimits apply i

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ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No. 23 QID: 0029 Point Value: 1 Given the following plant conditions:

- Reacter trip from fullpower

- FullES actuation

- ICCMDS Display Subcooling Margin indicates 0 'F

- Reactor Coolant Pumps are OFF

- ICCMDS CET temperatures are alternating between superheated and saturated conditions.

Which of the following best describes the mode of RCS cooling for these conditions?

a. ReflaxBoiling

b. Forced Convection

c. NaturalCirculation

d. Natural Conduction l

Question No. 24 QID: 0030 Point Value: 1 During a small break LOCA cooldown, which of the following criteria must be met before High Pressure Injection maybe secured?

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a. Restoration of adequate =LWing margin.

b. Total low pressure injection flow >2800 gpm.

c. Restoration of forced flow cooling.

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d. At least one OTSG is available as a heat sink.

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ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No. 25 QID: 0031 Point Value: 1 i The unit is operating at 100% power. SU-1 transformer is INOPERABLE. The Startup Transformy Preferred Transfer Switches on C-10 for Al/H1 and A2/H2 are selected to SU-2 transformer. SU-2 feeder bredccrs to A1, A2, H1 and H2 are out of the pull-to-lock position. Which of the following best describes the electrical system response to a reactor / turbine trip?

a. With SU-1 inoperable, the load shed protective circuitry will require a manual transfer of electrical l

buses to SU-2 due to the limited capacity of SU-2.

l

b. The reactor / turbine trip will actuate the generator lockout relay and result in a " slow transfer" of A1, A2, H1 and H2 electrical buses to SU-2 transformer.

c. The tie breakers between the vital and non-vital buses will open, the emergency diesel generators

.will start and supply the vital buses and SU-2 will power A1, A2, H1 and H2.

L d. The generator lockout relay trip will cause a " fast transfer" to SU-2 transformer and applicable loads will be shed to limit the loadmg on SU-2 transformer.

Question No. 26 QID: 0032 Point Value: 1 l Given: i l

-Plant operating at 100% power

-P-36B in service

-PZRleveltrending down slowly  ;

-Imlown flow 45 gpm

-Makeup flow 0 gpm

-MUTleveltrending down l -Total sealinjection flow 70 gpm Which of the followmg would cause the above indications? j

a. P-36B makeup pump has tripped

b. PZRleveltransmitter failed high

c. IAss ofInstrument Air in LNPR

d. Makeup line break upstream of CV-1235 l

Page 11

ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No. 27 QID: 0033 Point Value: 1 Which of the following is an Immediate Action performed only for loss of DH Removal due to vortexing?

a. Close at least one DII suction valve from the RCS.

b. Start the other DH pump to makeup to RCS from BWST.

c. Initiate containment closure per Att. G of 1203.028.

d. Stabilize flow by throttling one of the discharge flowpath valves.

Questlom No. 28 DID: 0035 Point Value: 1 The plant is at 100% power when "B" MFW pump trips.

FW pumps discharge crosstic valve, CV-2827, fails to open due to mechanical binding.

The CBOR depresses the manual reactor trip pushbutton.

All rods remain out.

Which one of the following actions should be the number one priority?

a. Manually trip the turbine and venfy GVsfrVs closed.

b. Open BWST outlet valve to running Makeup pump.

c. Open CRD power supply breakers on C03.

d. Manually insert rods and send operator to locally trip CRD breakers.

Page 12

ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No. 29 QID: 0037 Point Value: 1 1202.006, Tube Rupture, emergency operating procedure provides guidance to " Operate Pressurizer Heaters AND Pressurizer Spray valve (CV-1008) to maintain RCS pressure low within limits of Figure 3" while cooling down the RCS.

What is the PRIMARY reason for maintaining RCS pressure low 1

a. To prevent liRing main steam safetics.

b. To minimize thermal stresses on the steam generators.

c. To minimize the RCS leak rate into the steam generator.

d. To prevent cycling of the NRV (CV-1000).

Question No. 30 QID: 0038 Point Value: 1 The plant is shutdown and a cooMown is in progress due to a 200 gpm tube leak in the A OTSG.

- RCS temperature is $20 'F and lowering

- BWSTlevelis at 35 A andlowering

- A OTSGlevelis 290 inches and rising

- Dose rates at site boundary are normal Which of the following RCS cooldown limits apply? j

a. Less than or equal to 50 'F/ hour. I

b. Less than or equal to 100 'F/ hour.

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c. Less than or equal to 240 'F/ hour.

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d. Less than or equal to 520 'F/ hour.

Page 13

i ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No. 31 QID: 0040 Point Value: 1 An inadequate com cooling event is in progress. In order to establish primary to secondary heat transfer it is desired to " bump" RCPs. Which of the following best describes the correct method for " bumping" RCPs in accordance with RT-117

a. Start the pump, then immediately secure the pump.

b. Statt the pump, when normal tunning amps are indicated on SPDS, then secure the pump.

c. Start the pump, run the pump for 10 seconds, then secure the pump.

d. Start the pump, run the pump for 1 minute, then secure the pump.

Question No. 32 QID: 0041 Polet Value: 1

' A reactor trip has occured from 100*/. power following a loss of D01. Attempts to transfer 125V DC panel D11 to its emergency supply are unsuccessful. Which of the following is the appropriate immediate action?

a. Crosstic D-Il and D-21 from panel C-10 in the control room to provide power to Dll.

b. Manually actuate main steam isolation on both steam generators and verify proper actuaton and control.

c. Select main turbine control to 'IURBINE MANUAL and close the governor valves in fast speed.

d. Manually acutate emergency feedw1 ster and verify proper actuation and control.

Question No. JJ QID: 0044 Point Value: 1 Events are in progress which haw resulted in an unplanned gaseous radioactive release to the environment which is expected to be limited to a small fraction of the EPA Protective Action Guideline exposure levels.

What emergency classification would you recommend to the shift superintendent?

a. Notification ofUnusualEvent

b. Alert

c. Site AreaEmergency

d. GeneralEmergency Page 14

ANO Unit 1 - 1998 Senior Reactor Operator License Exam Questlom No. 34 QID: 0045 Point Value: 1 Refuelingisin progress "B" Decay Heat Removal system is in service.

The following indications are reported:

-Transfer canalleveldecreasing

- Reactor Building sump icvel increasing

- Water running down primary shield wall Which procedure should be entered?

a. 1203.028, Imss of Decay Heat Renoval

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b. 1203.042, Refueling Abnormal Operations c.1203.039, Excess RCS T rakage

d. 1502.004, Control of Unit 1 Refueling Question No. JJ QID: 0046 Point Value: 1 Given:

- DegradedPower

. Both EDGs aparating

- ESAS has NOT actuated

- P4C failed to start Which of the following actions should be accomplished?

a. Close SW Loop IIIsolation Valve (SW-10C).

b. Open SW Loop I & II Crossconnects (SW-5 and SW-6).

c. Close ACWImopIsolation(CV-3643).

d. Cross-tic SW Loops at Makeup Pump (SW-14 thru SW-17).

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ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No. 36 QID: 0047 Point Value: 1 In accordance with the EOP, when do the Fie Lai 'Ihermal Shock limits NO LONGER apply?

a. -When the RCS pressureA-w.hus is to the right of the NDIT limit line on Figure 3.

b.- Following restoration of RCP services and starting of Reactor Coolant Pump's.

c. Upon termination of High Pressure Ingection to the Reactor Coolant System.  !

d. Following an evaluation which will allow normal RCS pressure control to resume.

Question No. 37 ' DID: 0048 Point Value: 1 A Blackout has occurred.

1. 1 EDG has been placed in service on a "No DC" start using 1104.036, Emergency Diesel Generator J Operation. i i

i-What DG protection is operable to protect the only operable AC source?

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a. positive cr==1rc==a pressure trip

b. Iowlubeoilpressuretrip

c. mechanical overspeed trip

d. highjacketwater-+.; e trip Question No. 38 QID: 0049 Point Value: 1 Lake Dardanelle icvel is rMag due to severe weather and heavy rains. Which of the following is the minimum level at which consideration would be given to commencing a plant shutdown in accordance with 1203.025, NaturalE.-c , is?

a. Lake level >330 A. and forecasted lake level at site >340 A.

b. Lake level >340 A. and forecasted lake level at site >350 A.

c. Lake level >350 A. and forecasted lake level at site >360 A.

d. Lake level >360 A. and forecasted lake level at site >370 A.

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ANO Unit 1 - 1998 Senior Reactor Operator License Exam I

Question No. 39 QID: 0051 Point Value: 1 i i

An earthquake has caused structural damage to the plant. The shiA superintendent has announced a plant I evacuation. Which of the following actions should be performed? l I

a. All crew members should log into the nearest security card reader using the specia!

accountability code "0000". I l

b. All crew members, with the exception of the control mom staff, should report to the l Operations Support Center.

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c. All off shiA operations personnel should report to the Technical Support Center.

d. All operations personnel, with the exception of the operating crew should evacuate the plant.

Point Value: 1 j Questlos No. 40 QID: 0052 The plant had been operating r.t 100% power for 200 days. Following a plant trip, preparations for startup are in progress. The CBOR is performing a calculation for Estimated CriticalPosition (ECP). At a given boron l concentration, which of the follomag times would result in the highest rod index due to the effects ofXenon?  ;

a. 4 to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />

b. 8 to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> t I

c. 40 to 60 hours6.944444e-4 days <br />0.0167 hours <br />9.920635e-5 weeks <br />2.283e-5 months <br /> ,

I

d. 70 to 90 hours0.00104 days <br />0.025 hours <br />1.488095e-4 weeks <br />3.4245e-5 months <br /> j

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l ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No. 41 QID: 0054 Point Value: 1 l

Given the following plant conditions:

1 i

- Power at 27%..

- ICS in fullautomatic I

- D Reactor Coolant Pump trips {

Which of the following best describes ICS response to the change in RCS flow? l i

a. Delta-Tc will remain at zero (0) due to the response of the total flow controller,

b. A Delta-Tc error will develop with Imop A Tc < Imop B Tc due to the response of the total flow controller,

~

c. 'A Delta-Tc error will devel'op with Imop B Tc < IAop A Tc due to the response of the total flow controller.

f l d. Delta-Tc will not be effected due to the total flow controller signal being blocked.  !

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Qaestion No. 42 QID: 0056 Point Value: 1 l Fig.iions for reactor startup are in progress. Which of the following best describes the performance and i review requuements for the calculation of Estimated Critical Rod Position (ECP) per 1102.008, Approach to .  :

)

Criticality?

a. The r=hd=tian shall be performed by a licensed operator and reviewed

. by a seniorlicensed operator,

b. The calculation shall be performed by a hcensed operator and senior hcensed operator and reviewed by the startup reactor engineer.

c. The ahdat=n shall be performed and reviewed by the licensed operator and )

senior licensed operator performing the startup  !

. d. The ahdation shall be performed by the startup reactor engineer and licensed

l. reactor operator and reviewed by the senior licensed operator.

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ANO Unit 1 - 1998 Senior Reactor Operator License Exant Questlos No. 43. QID: 0057 Point Value: 1 Which of the following would result in all ten (10) ESAS Digital Channels receiving an Analog Channel Trip ,

signal?

a. Removal of the low RCS Pressure Bistable from Analog Channel 1.

b. Removal of the RB Pressure Buffer Amplifier from Analog Channel 1.

. c. Removal of the 30 psig RB Pressure Bistable from Analog Channel 2.

d. Removal of the RCS Pressure Buffer Ampliner from Analog Channel 2. f I

i Question No. 44 'QID: 0059 Point Value: 1 During a large break IDCA the value on the ICCMDS CET Subcooling Margin Display is negative and

. B-"ag What does this indicate?

a. An ICCMDS rammunistiane error, j

b. CETreadmgsareinvalid.

c. Core damage has occurred. ,

d. CET readags innhmk superheat.

Question No. 45 QID: 0061 Point Value: 1 Which of the followmg Reactor Building y.i.iiwers are trended on the Safety Parameter Display System (SPDS) primary grapluc display for Reactor Building Conditions (RB)?

a.' RB pressure, RCS pressure, RB flood level b.RB;  ; e, RB pnssure, RB hydrogen concentration

c. RB radiation levels, RB pressure, RB humidity

d. RB flood level, RCS hot leg level, hydrogen concentration P

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j ANO Unit 1 - 1998 Senior Reactor Operator License Exam ,

Question No. 46 QID: 0063 Polet Value: 1 l Given:

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1 - 100% power l - ICS in fullautomatic The CBOR places the ICS Delta T Cold Hand Auto Station meter selection switch in "POS" (position). The j meter reads 54% What does this mean in terms ofICS control of main feed water?

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a. The average of feedwater loop A and feedwater loop B demand is 54% .

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b. Feedwater loop B demand,is greater than feedwater loop A demand.

c. The feedwater loop B demand is being boosted by a 4 'F Delta T-Cold error.

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d. Feedwater loop A demand is greater than feedwater loop B demand.

QID: 0064 Point Value: 1 i Q-=*ia= No. 47 I

Given:

- SmallBreak LOCAin progress  !

- RCS Pressure at 1500 psig and stablizing

- Kil-B2, LPI Channel 3, annunciator alarm is clear  !

Assuming no operator action, which of the following best desenh:s the response of the EFIC/EFW system?

a. EFIC train A will actuate EFW train B, EFW pump P-7B is nmning.

b. EFIC train A will actuate EFW train A, EFW pump P-7A is running.

c. EFIC train B will actuate EFW train A, EFW pump P-7A is running.

L

d. EFIC train B will actuate EFW train B, EFW pump P-7B is running.

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ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No. 48 QID: 0066 Polet Value: 1 It is desired to release the contents of Treated Waste Monitoring Tank T-16A. FI-4642, Discharge Flow to .

Flume,is OOS.

To comply with Technical Specifications, what must be done in order to complete the release?

a. Repairs must be made and FI-4642 must be operable to conduct releases via that pathway.

i b. Take iMat samples and conductI *-i--- =t analyses and valve lineups prior to the release. ,

h c. Estimate release flow rate using pump curves at least every 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> during the release. l

d. Verify RI-4642, liquid radwaste process monitor, is operable and proceed with the release.

f Question No. 49 QID: 0068 Point Value: I

[

Control Ventdation is in a normal alignment when the Unit 1 Control Room Inlet Air Radiation Monitor l

(2RITS4001A) comes into alarm. Which of the following describes the expected control room ventilation system response?

a. AllIsolaten dampers CLOSED, VSF4A/B OFF,2VSF4A/B ON, VSF-9 ON and 2VSF-9 OFF.

b. Unit 1 isloation dampers CLOSED, VSF4A/B OFF,2VSF4A/B OFF, VSF-9 ON and 2VSF-9 ON.

e

f. . c. AllIsolation dampers CIDSED, VSF4A/B OFF,2VSF4A/B OFF, VSF-9 ON and 2VSF-9 ON.

d. Unit 1 islantion dampers CIDSED, VSF4A/B OFF,2VSF4A/B OFF, VSF-9 ON and 2VSF-9 OFF.

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ANO Unit 1 - 1998 Senior Reactor Operator License Exam 1 1

l Question No. 50 QID: 0069 . Point Value: 1 Given:

1

- Manual reactor trip has taken place, and immediate actions are complete

- OTSG "B" level is increasing above 390"

- OTSG "B" pressure is decreasing below 900 psig rapidly

- Pressunzer pressure and level are decreasing

- Steam line high range radiation monitor RI-2682 is in alarm Which of the following events is in progress? l

a. OTSG tube rupture and stuck open MSSV f

b. OTSG tube rupture and'exhive EFW flow

c. Small break LOCA and excessive EFW flow

d. SmallbreakIDCA and stuck open ERV Question No. 51 QID: 0070 Point Value: 1 A SBLOCA is in progn:ss with RCS prusure stablized at 1400 psig.

In this accident, which of the following systems is designed to maintain clad temperature <2200"F per j 10CFR507

a. ReactorProtection System

b. Low PressureInjection System i i

c. High PressureInjection System

d. CoreFlood Tank System Page 22

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I i ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No. 52 QID: 0071 Point Value: 1 Given:

-P36B out of service

-LOCA in progress l

-RCS pressure 1250 psig

-4160vbus A3 deenergized j

-HPI flows: A = 90 gpm B = 100 gpm f

C = 250 gpm D = 75 gpm 1

Which of the followmg actiong is required?  !

a. Throttle "C" flow to within 20 gpm of"B" ]

b. Throttle "C" flow to within 20 gpm of"D"

c. Throttle all to within 20 gpm of each otler l

d. Throttle "C flow to within 20 gpm of"A" Ii Question No. 53 QID: 0072 Polat Value: 1 i Given-

- RCS pressure 1950 psig and decreasing  ;

- RELIEF VALVE OPEN", K09-A1, in alarrn

-ERVindicates closed

- Acoustic monitor indicates ERV is leaking You immediately close ERVIsolation valve, CV-1000. RCS pressure continues to decrease What should your next actionbe?

a. Begin plant runback

b. Cycle the ERV

c. Initiate full HPI

d. Trip the reactor Page 23 1

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ANO Unit 1 - 1998 Senior Reactor Operator License Exam Questlos No. 54 QID: 0074 Point Value: 1 Plant steady at 90% power with:

- pressurizer spray isolation valve closed,

- makeup tank level 85 inches,

- pressunzer level indications on C04 are diverging What operator action should be taken?

a. Take manual control of CV-1235 and open.

b. Take manual control of CV-1000 and close.

c. Monitor makeup tank leNrecorder for recent slope changes.

d. Detennine valid levelindicator and select it for contml.

Question No. 55 QID: 0075 Point Value: 1 Given:

- C" RPS is placed in Channel B3pass for IAC troubleshooting

-Plant is at 40% pour

- A" MFW pump in senice Which of the followmg would cause an automatic reactor trip with tle given conditions?

a. Contact monitor module pulled in "C" RPS and "A" RPS taken to Shutdown Bypass.

b. Turbine trip contact buffer module pulled in "C" RPS and NI-6 power range test module taken to " test operate" in Channel "B".

c. Shutdown Bypass 5% power module taken to " test operate" in channel "C" and "D" channel plamd in Shutdown Bypass.

d. I&C deenergues "C" RPS cabinet and "A" MFW pump contact buffer trip test switch operated in "A" cabinet.

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l ANO Unit 1 - 1998 Senior Reactor Operator License Exam r

Question No. 56 QID: 0076 Point Value: 1 l

l At 100% power, a CRD in Group 6 with a history of faulty API has been deternuned by Incore detectors to be l ~50 inches inserted. It has been in this position for at least 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.

How would you re-align the rod with the rest of Group 67

a. Reduce power to 90% then withdraw rod, while keeping power rate <5%/hr.

b. Hold power and withdraw rod while keeping power <100%.

c. Reduce power to 60% of MWt for RCP combination then withdraw rod, keeping rate <3%/hr.

d. Reduce power to 40% of 902 MWe then withdraw rod, keeping rates to 30% /15% / 5%.

i Question No. 57 QID: 0077 Point Value: 1 Given:

-Loop A RCS flow 68,000,000 lbm/hr

-Loop B RCS flow 63,000,000 lbm/hr

-Imp A Tave 578'F

-Loop B Tave 580*F

-Unit Tt.ve 579'F ]

Which Tave will be selected by the SASS Auto / manual transfer switch and why?

a. Unit Tave due toImp B flow

b. Loop ATave due to Loop B flow

c. Imp B Tave due toImp B flow

d. Unit Tave, flows are within tolerances

! Page 25

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ANO Unit 1 - 1998 Senior Reactor Operator License Exam l Question No. 56 QID: 0078 Point Value: 1 )

If an ESAS occurs simultaneously with a loss of Offsite Power, the start of RB Spray pumps is delayed by 35 sec. Why?

a. To allow the EDGs to come up to speed. ,

b. To allow SW pumps to start for spray pump cooling.

c. To prevent overload of the EDGs.

d. To prevent water hammer of the spray headers.

f Question No. 59 QID: 0079 Point Value: 1 Given:

Unit operating at 100%

Reactor Building pressure is 15.9 psia and stable No other abnormalconditions exist What action should be taken to lower RB pressure?

a. Open RB purge inlets first, then open outlets,

b. Vent RB via H2 sample lines.

I

c. Use vent flowpath via RB leak detector. 1

d. Open RB purge outlets first, then open inlets. l l

Question No. 60 QlD: 0080 Point Value: 1 j l

Which of the following design features allows for the safe storage of new fuct in the spent fuel pool?

a. Spent fuel cooling system is designed to maintain pool temperature <150 'F.

b. Spent fuel boron conantration is maintained >1600 ppm boron.

c. A syphon break is incorporated into system piping to prevent inadvertent draining.

d. Fuel racks designed with boraflex plates and adequate spacing.

I Page 26  !

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3 ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No. 61 QID: 0062 Point Value: 1 Given tie following conditions:

- Startup from Cold Shutdown in progstss.

- A steam bubble has been formed in the pressunzer.

- Nitrogen is being vented from the pressurizer.

Which of the following indications demonstrates that nitrogen has been vented from tie pressurizer?

a. Pi im pressure stops decreasing.

b. Quench tank pressure stops increasing.

c. Pressunzer spray causes's significant RCS pressure decrease,

d. Proportional pressunzer heaters can maintain a steady RCS pressure merease Question No. 62 QID: 0083 Point Value: 1 o

A reactor startup is in progress with the reactor CRITICAL at 1 E-8 amps power. An atmospheric dump valve fails OPEN. Which one of the following describes the initial primary plant response?

a. Reactor power will INCREASE, temperature will DECREASE, and pressure will DECREASE.

b. Reactor power will DECREASE, temperature will INCREASE, and pressure will DECREASE.

c. Reactor power will INCREASE, temperature will INCREASE, and pressure will INCREASE.

d. Reactor power will INCREASE, temperature will DECREASE, and pressure will INCREASE.

Question No. 65 QID: 0085 '*oist Value: 1 Which of the following power supplies is the normal source for RPS channel D7

a. Inverter Y22 from B61

b. InverterY22 from D01

c. InverterY24 fmm B61

d. InverterY24 from DOI Page 27

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ANO Unit 1 - 1998 Senior Reactor Operator License Exam i

l Question No. 64 QID: 0087 Point Value: 1 i

During a Blackout condition, it may become necessary to perform an EDG start without DC control power. j In this condition, how is the generator output voltage a(justed (no battery chargers are loaded)?

l

a. A4 justing engine speed via speed setting knob on governor. ,

i l b. The automatic voltage adjuster will still function.

i

c. Using the manual voltage a4 juster on Exciter Control Panel.

l

d. Using voltage adjuster handswitch on C10. 1 1 l Question No. 65 QID: 0088 Polet Value: 1 T!w CRS directs you to perform Supplement 1 of 1104.036, #1 EDG Monthly Test. You depress the start l pushbutton on CIO, nothing happens, then the 'EDG 1 OVERCRANK" annunciator K01 B2 alarms. The CRS directs the inside AO to check the EDG out and then depress the ',ocal RESET pushbutton.

Which of the following would occur after the AO 4w the RESET pushbutton?

a. EDG would be ready for another manual start.

b. EDG will not manually or automatically start.

l

c. EDG output breaker will be locked out.

d. EDG will immediately start cranking. 3 5

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ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No. 66 QID: 0069 Point Valac: 1 Given:

- Treated Waste Monitor Tank, T16A, release in progress

- PROC MONITOR RADIATION HIGH", K10-B2, in alarm

- Liquid Radwaste Process Monhor, RI-4642, in alarm i What should your immediate Action be?

a. Verify no flow on Discharge to Flume, FI-4642

b. Trip the running Radwaste Transrer pump, P-53A/B l .,

c. Close Liquid Waste to Flume valve, CV-4642 i f

d. Reset RI-4642 to. verify alarm is valid ,

(

i Q=* atla = No. 67 - QID: 0090. Point Value: 1 i- The yellow trouble LED is ON on #1 EDG flame detector module on C463 and has been acknowledged on C463. Subsequently, a #1 EDG smoke detector alarms.

Which of the following annunciators would you expect to see?

a. " FIRE WATERFLOW",K12-A2 l b. "FIREPROTECTSYSTEMTROUBLE",K12-D1 l I

c. " FIRE', K12-Al

d. " FIRE PUMP AUIO START", K12-B2 I

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ANO Unit 1 - 1998 Senior Reactor Operator License Exam Questlom No. 68 QID: 0091 Point Value: 1 Given:

-Plant cooldown in progress

- A" DH Removal pump in senice

- A" and "C" RCP's running What is the maximum allowable cooldown rate in this condition?

a. 5'F/hr

b. 25'F/hr

c. 50*F/hr d.100*F/hr Question No. 69 QID: 0092 Point Value: 1 The white light above the handswitch for CV-1410, DH Suction f:om RCS, is ON.

What does thisindicate?

s. The interlock will allow valve opening.

b. DC Control Power is available.

c. "B" CFT Outlet valve is open.

d. The MOVs breaker has tripped.

Question No. 70 . QID: 0093 Point Value: 1 Which of the following parameters would indicate a leaking PZR code safety?

a. Quench Tanklevel7500 gallons

b. Quench Tankpressure 5 psig

c. Code safety tailpipe temperature 200 *F

d. Quench Tank temperature 155 'F Page 30

1 ANO Unit 1 - 1998 Senior Reactor Operator License Exam i 1

l Question No. 71 QID: 0095 Point Value: 1 1 l

l ESAS has actuated due to a LOCA.

RCS pressure has dropped to approximately 1200 psig within live minutes of actimtion.

Which of the following best describes the effects on the IC4 system or the components it cools?

a. All RCP's must be secured due to loss of seal cooling.

b. CRD cooling pumps must be secured due to isolation o f discharge path.

c. ICW Booster pumps are protected by opening of bypm valve.

d. ICW pumps must be securqd due to isolation of SW ts ICW coolers.

Question No. 72 QID: 0096 Point Value: 1 )

Which of the following Reactor Building systems are required to be operable whenever RB Integrity is required? -

a. Both trains ofRB Coolers l

b. Ilydrogen Recombiners

~c. Both RB SprayPumps

d. RB Purge Question No. 73 QID: 0097 Point Value: 1 What is the purpose of the load setpoint of 1200-1500 pounds on the Spent Fuel leist?

a. Prevents a fuel assembly from being dropped while grapple is engaged.

b. Prevents damage to a fuel assembly if it is stuck in place.

c. Keeps the bridge from moving in fast speed while transporting an assembly.

d. Stops downward motion of hoist to allow the grapple to be engaged.

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'ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No. 74 QlD: 0098 Polet Value: 1 What type of dose rate is expected to be the highest following a fuel handling accident causing damage to a I spentfuelassembly? )

a. Skin dose rate .

b. Whole body dose rate

c. Extremities dose rate .

d. Izas of the eye dose rate --

l Question No. 75 QID: 0100 - Point Value: 1 The plant is operating at 90% power when a malfunction of the Main Turbine EH control system causes a spurious OPC actuation.

Which of the following would occur during the transient?

a. RCP sealinjection flow would drop.

b. PZR spray flow would drop.

c. PZR makeup flow would drop.

L d. FWflow to both OfSG's would rise.'

Question No. 76 QID: 0101 Point Value: 1 Which of the following is NOT an action to take with a loss of Service Water with only one SW pump running?

a. Close Generator H2 Lw.me Control Valve j' ,

b. Trip the running Spent Fuel Cooling pump l' c. Isolate both Condenser Vacuum Pump coolers

d. Reduceletdown flow to minimum l

Page 32 I'

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ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No. 77 QID: 0103 Point Value: 1 Instrument Air pressure has been degrading for approximately 30 minutes. Suddenly, Inst. Air pressure drops to <60 psig.

What actionis required?

a. Isolate S/U Boiler ~ air system from Unit 1 Ins. Air

b. Isolate Unit 2 Inst. Air from Unit 1

c. Place VSF-9 Outside Air damper in RESERVE position

d. Trip the reactor and full actuate EFW to both SGs Question No. 78 QID: 0105 Point Value: 1 Who would be responsible for implementing a damage repair team into Containment during an emergency event?

a. ShiA Superintendent ,

l l

b. TSCDirector

c. OSCDirector  :

l

d. EOFDirector l

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Pag:33

1 ANO Unit 1 - 1998 Senior Reactor Operator License Exam Questlom No. 79 QID: 0106 Polet Value: 1 Given:

-Unit at 100% power

- A" OTSG pressure initiate bistable trips in "A" EFIC cabinet

- B" OTSG pressure initiate bistable trips in "C" EFIC cabinet What willthe EFIC response be?

a. Half trip on both trains

b. Train "A" MSLI/EFW armi=Ma -

c. Train"B"MSLI/ElWbon

d. Both trains will actuate MSLI Qwiam No. 80 QID: 0107 Point Value: 1 De plant is operstmg at 60% power with Delta Tc H/A station in Hand. All other ICS stations are in Auto.

If one RCP has to be tripped due to high winding ^w.i.,c, how will the ICS respond?

Assume no operator action other than tripping the RCP.

a. De ICS will runh=<* the plant to 45% load at 50%fmin.

b. The Delta Tc Integral is blocked so no re-ratio of FW occurs.

c. Demand is less than the RCP runback limit, no changes occur to FW.

d. The RC flow difference will re-ratio the FW flow demand.

Page 34

ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No. 81 QlD: 0108 Point Value: 1 Given:

Plant operating at 100% power.

The instnunent air line to Turbine Byapss Valve (CV-6688) valve operator is severed during pre-outage scaffolding erection.

What affect will this have on CV-6688 operation?

a. CV.6688 fails OPEN.

b. CV-6688 fails AS-IS.

c. CV-6688 fails CIESED.

d. CV-6688 will function normally.

Question No. 82 QID: 0109 Point Value: 1 Given:

-Plant operating at 95% power

- Group 6 programmer's 'A' 24v power supply has failed.

What would hapen ifI&C tests DROPS channel 27

a. Nothing, DROPS outputs are defeated during testing.

b. An AMSAC test would result in tripping the turbine.

c. A DSS test would cause Goup 6 rods to drop.

d. A DSS test would cause a turbine trip.

Page 35

ANO Unit 1 - 1998 Senior Rete.f or Ohrator License Exam Question No. 83 QID: 0110 Point Value: 1 The ONLY action statement in Tech Specs regarding Hydrogen concentration instruments operability (3.14.4) states:

"With one of two hydrogen concentration instruments inoperable restore the inoperable analyzer to OPERABLE status within 30 days or be in at least hot shutdown within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />."

Which of the following actions would be applicable if BOTH hydrogen concentration instruments were inoperabic?

a. Within one hour, restore at least one inoperable analyzer to operable status.

b. T=Mi*1y invoke Technical Specification 3.03.

c. Restore at least one analyzer to operable status in 15 days or be in Hot Standby within 6 hrs.

d. Within two hours, initiate action to place the unit in Hot Standby within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

Question No. 84 QID: 0111 Point Value: 1 A SmallBreakLOCA has occurred.

- RCS pressure 1890 psig and falling slowly

-RB pressure is 1.5 psig and rising slowly Which of the following operator actions is appropriate for these conditions?

a. Manually actuate ESAS and announce this action to CR personnel.

b. Obtain concurrence from CRS, then manually actuate ESAS and make announcement.

c. An== par.sm and imminent ESAS actuation, then verify proper automatic actuation.

d. Obtain concurrence from CRS and then bypass ESAS prior to automatic actuation.

Page 36

ANO Unit 1 - 1998 Senior Reactor Operator License Exam  ;

i Question No. 85 QID: 0112 Point Value: 1 I

i

! ' During a FW transient, the CBOT manually controls FW to stabilize the plant.

Rx power is 101.5% for approximately 10 minutes while the plant is brought under control. I i

l Is this maMe or 7- -

,2 Ale?

l a. This is acceptable to mitigate transients for short periods of time per Conduct of Operations.

f b. This is - - ,2A4 due to limitations on our fuel as specifuxiby Babcock & Wilcox.

c. This is acceptable for shoit periods of time as specined by NRC correspondcace with Licensing. I

d. This is ==+ 2nle due to ev=vlMg the maximum thermal output in our operating heense.

Question No. 86 QID: 0113 Point Value: 1 The unit is operatmg at 100% power. A system engineer enters the control room with a condition report stating the PZR code safety valve (PSV-1002), replaced during the last outage, was set by the vendor using out of calibration equipment. The condition report estimates the setpoint for PSV-1002 could be as high as 2790 P8i-8 What action would >winitiate?

a. Direct the CBO'f, to begin shutting down, and place the unit in Hot Shutdown j within 12 hrs.

b. Within one hour initiate a shutdown to be in Hot Standby within 6 hrs and be in Hot Shutdown within another 6 hrs.

c. Restore the safety to operable status within 6 hrs or place the unit in Hot Shutdown within  ;

the followmg 12 hrs. l

d. Restore safety to operable status within 12 hrs or place the unit in Hot Shutdown within the following 12 hrs.

Page 37

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ANO Unit 1 - 1998 Senior Reactor Operator License Exam

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Question No. 87 QID: 0114 Point Value: 1 Which of the following actions involving a carded MCC breaker is allowable per 1000.027, Hold and Caution Card Control?

a. Removing "a" and "b" contact terminations.

b. Racidng a breaker up and down but not closing it.

c. I4aving the door open as long as breaker is removed.

d. Performing a PM to lubncate contacts Q-sela= No. 88 QID: 0115 ' Point Value: 1 Section 3.0 of Tech Specs contains provisions for e-iing a Limiting Condition of Operation where an action statement does not exist.'

Section 2.0 does NOT contain any action for exceeding a safety limit.

What action would you take if you discover that a safety limit had been exceeded?

a. Im=whately begin a rapid shutdown at a rate of at least 10Wmin.

b. Maintain stable plant conditions until management and engineering determine a correct course of action.

. c. Imn=liately begin a slow, conservatrve shutdown at <5Wmin.

d. imnwhately trip the reactor and verify imawhate actions.

Q==81a= No. 89 QID: 0117 Point Value: I Which of the following would NOT require the use of a Temporary Alteration Package?

a. Installatian of a test gauge for a survallanne

b. Temporary power cables supplying w y equipment.

c. Installing ajumper to prevent a --Weia=ia: instrument loop from actuating equipment.

d. Pey= == of a blank flange with a vent flange Page 38

ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No. 90 QID: 0119 Point Value: 1 Given the following "A" Core Flood Tank (CFr) parameters with the plant is at 100% power.

-leveltransmitter out cf service

- CFrlevelis 12.5 feet

- Boric acid cona:ntration is'2300 ppm

-CFr pressureis 585 psig Which of the above W m.. makes the "A" CFr INOPERABLE 7

a. leveltransmitter

b. CFrlevel , . ,

c. Boric acid concentration

d. CFrpressure Question No. 91 QID: 0120 Point Value: 1 Given:

- A Site Area Emergency has been declared on Unit 1.

- An E.-,.gy Medical Team must enter a 50 REM /hr area to rescue a critically injured employee.

- Ihc team members have NO previous exposure for the year.

Which of the following is the MAXIMUM time the team can stay in this area? ,

s.15 minutes

b. 30 minutes

c. 45 minutes

d. 60 minutes Page 39

l ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No. 92 QID: 0121 Point Value: 1 l Unit One refuelingisin progress.

A Unit Two WCO resource shared fuel handler is assigned to the Main Fuel Bridge from 0700 to 1200 on l Friday, Ef- -M 11.

Thelocalarea dose rateis 25 mR/hr.

He has an accumulated yearly doec of 1.8 Rem.

l-Whose permission must the WCO have to work on the Main Fuel Bridge?

i

a. Frrwding the Administrative Dose ControlIxvel can NOT be authorized.

b. Manager, Radiation Protection and Chemistry AND General Manager, Plant Operations

c. Manager, Radiation ProkEtion and Chemistry AND General Manager, Plant Operations AND Vice l

! T.A Operations l

d. Manager, Radiation Protection and rwmi*y Question No. 93 QID: 0122 Point Value: 1 A WCO is assigned to align "A" Decay Heat Removal during a shutdown.

It is estimated thejob will uike 40 minutes. '

i High RCS activity has created a whole body dose rate of 2.5 R/hr in this area.

l The WCO has an amimidated exposure of 0.225 Rein for the year.

The WCO makes the statement that he can complete the job without er-ding exposure limits.

l Do you agree or disagree with the WCO's statement?

l

a. Agree, the WCO will NOT receive a dose sufficient to exceed the Administrative Dose Controllevel.

b. Disagree, the WOO will exceed the Administrative Dose Controllevel aAer 38 minutes.

c. Agree, the WCO is allowed to exceed the AdmimWrative Dose ControlIAvel by a maximum of 500 mR.

d. Disagree, the WCO will exceed the Administrative Dose ControlIAvel aAer 12 minutes.

Page 40 l

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l ANO Unit 1 - 1998 Senior Reactor Operator License Exam l

l l Question No. 94 QID: 0123 Point Value: 1 ,

Given:

- Plant shutdown and cooldown in progress

-RCS Tave 1857

! - RB Purge in progress to lower RB atmospheric activity )

- RB Purge projected release duration is 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />  !

l

- RB Purge release commenced two (2) hours ago l

- Nuclear Chemistry stated gaseous releases projected to exceed quarterly objectives by 30% i l.

! - Release report preliminary release rate 4.1 E4 cfm l j -Design flow rate 3.6 E4 cfm to 4.1 E4 cfm l Which of the following would reqmre RB Purge termination?

1 l

a. Actual (stable) RB purge flow rate of 3.9 E4 cfm. I

b. RB Atmosphere Gaseous Detector trending upward.

c. SPING lindicates stack activiity approaching NUE criteria over next 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />.

d. Loss of Decay Heat Removal results in RCS temperature at 2207. j i

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Question No. 95 QlD: 0124 Point Value: 1

The reactor waspt 90% power,100% flow, and a core delta T of 487 when a Blackout occurred, Natural circulation was established with Tave at 5457 and a core delta T of 407.

l With natural circulation cooldown established, you would expect to see:

l a. core exit temperature continuing to decrease l

b. core delta T continuing to increase.

c. demand for EFW decrease to zero, j

d. 'IT3Ys opening periodically to maintain pressure l

l Page 41 l

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ANO Unit 1 - 1998 Senior Reactor Operator License Exam i

j Question No. 96 QID: 0126 Point Value: 1 Given:

- N-16 monitor R-2691 in alarm

-Small SG Tube Leak AOPin progress

-Ixtdown at 45 gpm

-Makeup at 66 gpm and rising l

A reactor trip occurs and while performing his actions the CBOR announces SCM is 30'F.

Which of the following EOPs would provide guidance to best mitigate this event?

a. ReactorTrip 1202.001 ..

1 I b. Ioss of Subcooling Margin 1202.002

c. Tube Rupture 1202.006

d. ESAS 1202.010 Question No. 97 QID: 0127 Point Value: 1 l

Given-

-Large Break LOCAin progress

- Core exit temperatures indicate an ICC condition in Region II of Figure 4 i (Figure 4 is on following page) l- -EFW is avadable l

Considering the above conditions, which of the following strategies would be used in 1202.005, Inadequate Core Cooling, to lower core exit temperatures from Region II to Region I of Figure 47 l

a. Raise primary to secondary Delta-T to 90 to 110'F.

b. Start and run one RCPin each loop.

c. Open loop, Rx vessel, and PZR high point vents. l

d. Open ERV until RCS to SG DP is less than or equal to 100 psig.

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Page 42 l

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ANO Unit 1 - 1998 Senior Reactor Operator License Exam Question No. 98 QID: 0128 Point Value: 1 Which of the following would be classified as a fission product barrier failure?

a. RCS Icakage indicates greater than 45 gpm.

b. EOF Director believes the RB is breached.

c. CNTMT radiation levels equal to Alert level from CNTMT Radiation EAL.

d. The inability to monitor two Fission Product Barriers.

Question No. 99 ' hID: 0129 Point Value: 1 A small break LOCA has occurred with the following indications:

-HPIflow ~250 gpm total

- CNTMT High Range Rad Monitors reading 5000 REM

- Indications ofleakage past RB Purge isolations What Emergency Action Imel should be declaned?

a. NUE

b. Alert

c. SAE

d. GE Question No.100 QID: 0130 Potat Value: 1 For which EAL is a PAR required to be made?

a. NUE

b. ALERT c.SAE

d. GE Page 43

i 1202.013 E0P FIGURES REV 2 PAGE 4 ef 6

. i 1

FIGURE 4

. Core Exit Thermocouple Temperature for Inndequate Core Cooling 2600 )

RC RC e.t."i. "ri-+-

.tt". . - :p ...i-

..I.. .

c.t4".-a. . .

.4: SUPERHEATED raw.., . :.4*-:.-p y 9.

SUBCOOLED..-1.4

.. . . . . . . y.....

.. . . . ..; 7 .p g v.g .q m3gg3.an.n. v ,: m u g g. a..

. as ];. -1..pr.A.c.aaea ; ;4 y ' ~ w;. asaw;. ny

.4. .... 4..}... J.. a4,.3,c.

y. ., -

..;g..a p n4:.m@

.. g .

.g j 4 .4444.. .q.J.q.q g y f gy,

. . . . ..!. J ..i .. ..

Curve 1 2200 .]4: :4. a&4,4 i J . 444 ,. '"

SATURATION J-O h 1 14EF l LINE .t*4 J'. ", . . 4 cuo> a => cu  !

gn

.. .. . . . 7. 9 . . ..q... 9

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g;- ggi gg'g

.am.  :. .z .

4 4.. gp gg

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c 1800

.W

. . . . .. m.- ,

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m E ilREGIONIll. lREGION 2I: I1 REGION 3N- 5 g" Ng g . j . . . . ,. .. ...j . .;... 9. 7.q. g . gi g gpgg y 1600

'~~ ~~~I'~~ b( ~~I" 3... ~J 1" "N## " ' "

c 4?,'. xy. asmx a.la;w. ; a "W O

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4 ia

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-14 4

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p

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m 1200  ! I REGION 4F*

M m

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9. a g

.T.

=  !. ym. .n e.w. .g . w y; ;gg j a-

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.;..... 9 .;..j...g...

s .,,4 . - . +.a.,e. -- -

zw: .:

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. i. . .. . . . j . .. .. ' ;d. .. . 4 2. ;..q.

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-- x 4 m

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74.p;_p.

. g;. ~y Curve 2 *

~'

' I ~*

~

~" # ^^ O'~~** "" cuo >1800,F ;,

i 800 ..; .N .C .

4- 42..p.144.4 4.A.;.4

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. . . . ~ .

l 4;.,p:q., .1.g ;;,p}gg.

...

ja..;..

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y...

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.-M -

- :: = u .. ..

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.7

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gj$ gjy h

4. 4 QTJi vid;ie @. gigg @hQ gg 400 500 600 700 800 900 1000 1100 1200 1300 Core Exit Thermocouple Temperature (20* F increments) 4

i PAGE: 123 of 124 l PROC.MORK PLAN NO. PROCEDUREMORK PLAN TITLE:

REY: 34 1903.010 EMERGENCY ACTION LEVEL CLASSIFICATION PC-1 CHANGE:

I ATTACHHENT 5 UNIT 1 CONTAINMENTRADIATION EAL PLOT 1E+06 ,

4' .

2 1E+05 4 A 2 m 1E+04 RH1 4 2-1E+03, 45 2 .

1E+02 4 A g AREA 2-12 14 16 18 20 22 24 0 2 4 6 6 10 ThE N HCut INSTRUCTIONS CAUTION

• In the absence of a significant containment temperature transient, monitor g(/g readings should be considered valid.

• In the event of a significant containment temperature transient, monitor readings may be erratic for a short duration (Ref.IN-97-45, Supplement 1)

A. Determine the contamment radiation level.

1. If the plant has been operating at 100% for the past 30 days, use the reading from RE-8060 or RE-8061.

2. If the plant has been operating at less than 100% power for the past 30 days, detennine the radiaitonlevel as follows:

Rad level = Readmg from RE-8060 or RE-8061 X 100 %

f estimated ave. power for the past 30 days B. Determine the time after shutdown (in hours).

C. Find the intersection of the values from A and B on the graph.

l D. Determine the emergency class.

1. SITE AREA EMERGENCY - intersection is between the two curves

2. GENERAL EMERGENCY - intersection is above the upper curve i

1998 ANO Unit 1 Initial SRO Exam Key Question No.1 QID: 0001 Point Value: 1 Answen

b. Transfer Group 7, Rod 3 to the Aux Bus and pull programmer control fuses for the Aux Power Supply.

Question No. 2 QID: 0003 Point Value: 1 Answen

b. OTSG levels will be rising at a rate of-4 inches per minute to 300 to 340 inches.

Question No. 3 QID: 0004 Point Value: 1 Answen

b. CV-1000 should be cycled open and closed during cooldown to prevent thermal binding of the valve.

Question No. 4 QID: 0006 Point Value: 1 Answen

d. Failure of more than one rod to fully insert into the core and reactor power dropping.

Question No. J QID: 0008 Point Value: 1 Answen

c. Letdown Coolers Question No. 6 QID: 0009 Point Value: 1 Answen

b. Start Auxiliary Fecdwater Pump, P-75, and control OTSG levels at 20 to 40 inches using the Startup Control Valves.

Question No. 7 QID: 0010 Point Value: 1 Answen

d. Trip the turbine if vacuum falls below 24.5 inches.

Question No. 8 QID: 0011 Point Value: 1 Answen

a. Loss of tubcooling margin, no HPI available, and reactoritssel head voids are indicated.

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1998 ANO Unit 1 Initial SRO Exam Key Questlos No. 9 QID: 0012 Point Value: 1 Answen 1

b. Failed 50% open.

l l Question No.10 QID: 0013 Point Value: 1 Answen

b. IncreaseinICW Surge Tanklevel l

i Question No. Il QID: 0014 Point Value: 1 Answen

' d. Refer to the ANO Pre-Fire Plan for the affected fire zone for a listing of affected components.

i Question No.12 -QID: 0016 Point Value: 1 Answen

b. Portable radios available in the alternate shutdown cabinet.

Question No.13 QID: 0017 Point Value: 1 Answen

b. Self Poutred Neutron Detector (SPND) or. puts demonstrate progressive high and low swings.

Question No.14 QID: 0018 Point Value: 1 Answen  !

c. To prevent exceeding a 70% void fraction and possible core uncovery.

n Question No.15 QID: 0019 Point Value: 1 Answen

d. A marked drop by 40% in the GROSS / IODINE ratio.

Question No.16 QID: 0020 Point Value: 1 Answen

a. Place the SG "B" FW Temp signal select switch to the (Y) position.

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I 1998 ANO Unit 1 Initial SRO Exam Key Question No.17 QlD: 0021 Point Value: 1 Answen

d. Control rods will withdraw and main feedwater flows will decrease.  ;

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' Questlom No.18 QID: 0022 Point Value: 1 Answen

b. A dropped rod at <2% power.

Questlom No.19 QID: 0023 Polet Value: 1 Answen

a. Manually actuate "A" MSLI and EFW.

Question No. 20 QID: 0024 Point Value: 1

~ Answen

c. The speed of the contml rods and core age.

l Question No. 21 QID: 0026 Point Value: 1 Answen

d. To limit plant heatup following a loss of heat sink.

Question No. 22 QID: 0028 Point Value: 1 l Answen

d. No cooldownlimits apply Question No. 23 QID: 0029 Point Value: 1 Answen

a. RefluxBoiling Question No. 24 QID: 0030 Point Value: 1 Answen l- a. Restoration of adequate subcooling margin.

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1998 ANO Unit 1 Initial SRO Exam Key 1

Qeestlos No. 23 QID: 0031 Point Value: 1 Answen

d. The generator lockout relay trip will cause a " fast transfer" to SU-2 transformer and applicable loads will be shed to limit the loading on SU-2 transformer.

Questlom No. 26 QID: 0032 Point Value: 1 Answen

c. Loss ofInstrument AirinLNPR Questlom No. 27 QID: 0033 Point Value: 1 Answen

d. Stabilize flow by throttling one of the discharge flowpath valves.

Question No. 28 QID: 0035 Point Value: 1 Answen

c. Open CRD power supply breakers on C03.

Question No. 29 QID: 0037 Point Value: 1 Answen

c. To sr.inimize the RCS leak rate into the steam generator.

Question No. ~30 QID: 0038 Point Value: 1 Answen

b. Less than or equal to 100 'F/ hour.

Questlos No. 31 QID: 0040 Point Value: 1

'Answen

c. Start the pump, run the pump for 10 seconds, then secure the pump.  !

Question No. 32 QID: 0041 Point Value: 1 Answen

c. Select main turbine control to TURBINE MANUAL and close the governor valves in fast speed.

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1998 ANO Unit 1 Initial SRO Exam Key Question No. 33 QID: 0044 Point Value: 1 Answen

b. Alert Question No. 34 QID: 0045 Point Value: 1 Answen b.1203.042, Refueling Abnormal Operations Questlom No. 33 QID: 0046 Polet Value: 1 Answen

c. Close ACWLoopisolation(CV-3643).

Question No. 36 QID: 0047 Point Value: 1 Answen

d. Following an evaluation which will allow normal RCS pressure control to resume Questlom No. 37 QID: 0048 Point Value: 1 Answen

c. mechanicaloverspeedtrip Question No. 38 QID: 0049 Point Value: 1 Answen

b. Lake level >340 ft. and forecasted lake level at site >350 ft.

Question No. 39 QID: 0051 Point Value: 1 Answer: i

a. All crew re 1ss should log into the nearest security card reader using the special l accountability code "0000".

Question No. 40 QID: 0052 Polet Value: 1 Answen

b. 8 to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 1

1 1998 ANO Unit 1 Initial SRO Exam Key Question No. 41 QID: 0054 Polat Value: 1 Answer:

c. A Delta-Tc error will develop with Loop B 'A c < Loop A Tc due to the response of the total flow controller.

Question No. 42 QID: 0056 Point Value: 1 Answen

c. 'Ihe calculation shall be performed and reviewed by the licensed operator and senior licensed operator performing the startup. 1 l

l Question No. 43 QID: 0057 Point Value: 1 Answen

b. Removal of the RB Pressure

• Buffer Amplifier from Analog Clannel 1.  ;

Question No. 44 QID: 0059 Point Value: 1 Answen

d. CET readmgs indicate superheat.

I Question No. 45 QID: 0061 Point Value: 1 Awwen

b. RD %.p..hus, RB pressure, RB hydrogen concentration Question No. 46 QID: 0063 Polet Value: 1 Answen

d. Feedwater loop A demand is greater than feedwater loop B demand.

Question No. 47 QID: 0064 Point Value: 1 Answen

c. EFIC train B will actuate EFW train A, EFW pump P-7A is running.

Question No. 48 QID: 0066 Point Value: 1 Answer:

c. Estimate release flow rate using pump curves at least every 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> during the release.

l  !

1998 ANO Unit 1 Initial SRO Exam Key  !

j' Questlos No. 49 QID: 0068 Point Value: 1  !

l Answen

a. AllIsolation dampers CLOSED, VSF-8A/B OFF,2VSF-8 A/B ON, VSF-9 ON and 2VSF-9 OFF. i l

Question No. 50 QID: 0069 Point Value: 1

! Answen l

a. .OTSG tube rupture and stuck open MSSV t

I l Question No. 51 QID: 0070 Point Value: 1 Answen

c. High PressureInjection System l

Question No. 52 QID: 0071 Polet Value: 1 -

Answen

a. Throttle "C" flow to within 20 gpm of"B" Question No. 55 QID: 0072 Point Value: 1 Answen l

d. Trip the reactor j Questlos No. 54 QID: 0074 Palat Value: 1  !

Answen

d. Determine valid level indicator and select it for control.

)

Q=*=*la= No. 55 QID: 0075 Point Value: 1 Answen

~ d. IAC deenergizes "C" RPS cabinet and "A" MFW pump contact buffer trip test switch operated in "A" cabinet.

Questlos No. 56 QID: 0076 Point Value: 1 Answen

c. Reduce power to 60% of MWt for RCP combination then withdraw rod, keeping rate <3%/hr.

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1998 ANO Unit 1 Initial SRO Exam Key i

Question No. 57 QID: 0077 Point Value: 1 l l l' Answen l . b. Loop A Tave due to Loop B flow Question No. 56 QID: 0078 Point Value: 1 Answen -

c. To prevent overload of the EDGs.

Question No. 59 QID: 0079 Point Value: 1 Answer:

c. Use vent flowpath via RB leak detector.

Question No. 60 QID: 0080 Point Value: 1 Answer:

d. Fuel racks designed with boraflex plates and adequate spacing.

Question No. 61 QID: 0082 Point Value: 1 Answen

b. Quench tank pressure stops increasing.

Qwlam No. 62 QID: 0083 Point Value: 1 Answen

a. Reactor power will INCREASE, temperature will DECREASE, and pressure will DECREASE.

Question No. 63 QID: 0085 Point Value: 1 Answen

c. InverterY24 fromB61 Question No. 64 QID: 0087 Point Value: 1 Answen

b. 'Ihe automatic voltage adjuster will still function.

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1998 ANO Unit 1 Initial SRO Exam Key Question No. 65 QID: 0088 Point Value: 1 Answen

d. EDG will immediately start cranking.

l Question No. 66 QID: 0089 Point Value: 1

[ Answen

a. Verify no flow on Discharge to Flume, FI-4642 l

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i Point Value: 1 Question No. 67 QID: 0090 Answen

c. " FIRE",K12 Al l

Question No. 68 QID: 0091 Point Value: 1 1

Answen

c. 50*F/hr Question No. 69 QID: 0092 Point Value: 1 Answen

a. The interlock will allow valve opening.

l Question No. 70 QID: 0093 Point Value: 1  ;

Answen l

c. Code safety tailpipe temperature 200 *F Question No. 71 QID: 0095 Point Value: 1 Answen

b. CRD cooling pumps must be secured due to isolation of discharge path.

Question No. 72 QID: 0096 Point Value: 1 Answen i

b. HydrogenRecombiners i

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1998 ANO Unit 1 Initial SRO Exam Key QuestlomNo. 73 QID: 0097 Point Value: 1 Answen

a. Prevents a fuel assembly from being dropped while grapple is engaged.

l Question No. 74 QID: 0098 Point Value: 1 Answen

a. Skin dose rate Question NO. 75 QID: 0100 Point Value: 1 Answen

c. PZR makeup flow would drop.

Question No. 76 QID: 0101 Point Value: 1 Answer:

c. Isolate both Condenser Vacuum Pump coolers Question No. 77 QID: 0103 Point Value: 1 Answen

b. Isolate Unit 2 Inst. Air from Unit 1 Question No. 78 QID: 0105 Point Value: 1 Answen

c. OSC Director Questlom No. 79 QID: 0106 Polet Value: 1 Answen

b. Train "A" MSLI/EFW actuation Question No. 80 QID: 0107 Polet Value: 1 Answen

d. 'Ihe RC flow ddrerence will re-ratio the FW flow demand.

1998 ANO Unit 1 Initial SRO Eram Key l~ Questlos No. 81 QID: 0108 Point Value: 1 Answen

a. CV-6688 fails OPEN.

Questlom No. 82 QID: 0109 Point Value: 1 Answen

c. A DSS test would cause Goup 6 rods to drop.

Questlos No. 83 QID: 0110 Point Value: 1 l Answen '

l' ' b. bnnwhatdy invoke Technical Specification 3.03.

Question No. 84 QID: 0111 Point Value: 1 Answer:

b. Obtain penmssion from CRS, then manually actuate ESAS and make announcement.

Q==elam No. 85 QID: 0112 Point Value: 1 Answen

d. His is : =+/41e due to exceeding the maximum thermal output in our operating license.

Q=stla= No. 86 QID: 0113 Polet Value: 1 Answen

a. Direct the CBO's to begin shutting down, and place the unit in Hot Shutdown within 12 hrs.

Question No. 87_ QID: 0114 Point Value: 1 Answen

d. Performing a PM to lubricate contacts.

Question No. 88 QID: 0115 Point Value: 1 Answer:

d. imnwhataly trip the reactor and verify immediate actions.

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1998 ANO Unit 1 Initial SRO Exam Key 1

Question No. 89 QID: 0117 Point Value: 1 Answen

a. Installation of a test gauge for a surveillance.

Question No. 90 QID: 0119 Point Value: 1 Answen

b. CPTlevel Question No. 91 QID: 0120 Point Value: 1 l Answen l

b. 30 minutes l

)

Questlos No. 92 QID: 0121 Point Value: 1 Answen

d. Manager, Radiation Protection and. Chemistry Question No. 93 QID: 0122 Point Value: 1 Answen

a. Agree, the WCO will NOT receive a dose sufficient to exceed the Administrative Dose ContmlImel.

Question No. 94 QID: 0123 Point Value: 1 Answen d.14ss of Decay Heat Renoval ret.ults in RCS temperature at 220'F.

Question No. 95 QID: 0124 Polat Value: 1 )

l Answen 1

a. core exit temperature continuing to decrease.

Question No. 96 QID: 0126 Point Value: 1 Answen

c. Tube Rupture 1202.006 l

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l 1998 ANO Unit 1 Initial SRO Exam Key f Question No. 97 QID: 0127 Point Value: 1 Answer:

a. Raise primary to secondary Delta-T to 90 to I10'F.

Question No. 98 QID: 0128 Point Value: 1 Answer:

. b. EOF Director believes the RB is breacted.

l Question No. 99 QID: 0129 Point Value: 1  ;

Answer:

d.GE 1

Question No.100 QID: 0130 Point Value: 1  !

Answer:

d. GE i

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DYNAM C l

t OPERAT NG l

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TESTS 1

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Appendix D Scenano Outline Form ED-D-1 Facility: ANO-1 Scenano No.: 1 Op-Test No.: 1 Examiners: Operators:

Objectives: Evaluate Reactor Trip immediate and follow up actions.

Evaluate use of Emergency Operating Procedure to correct and mitigate RCS Overcooling.

Evaluate use of Loss of Steam Generator Feed Abnormal Operating Procedure.

Evaluate use of Pressurizer System Failures Abnormal Operating Procedure.

Initial Conditions: Reactor Protection System failed to provide ATWS.

Manual Reactor trip push-button failed.

Emergency Feedwater supply and isolation valves from P-7A failed open.

• A* MFWP oil pump (P-26A) running.

Tumover:

Unit is at ~80% power, steady state, equilibrium power. Current power level is at direction of system dispatcher to allow for Mablevale substation work. Work completion with release to raise power to 100%

is expected tomorrow.

Event Malf. No. Event Event No. Type

• Description 1 P27A_a0 C *A* MFWP standby oil pump failure resulting in the "A" MFWP tripping.

2 IOR -DO I MFW crosstie valve fails to indicate full open.

HS2827_G T 3 RX60410 l ICS to EHC fails raising turbine load slowly.

R N

4 MS1331.0 M *A* Main steam line rupture upstream of MSIV and outside of R420 C containment with EFW over feed condition.

5 RP246 C Reactor Protection System will fail to trip when any trip setpoint is RP247 M reached.

RP249 R Reactor Trip push-button fails to trip the reactor.

ICC0020 6 CV2645_a 1 EFW to "A" OTSG control valve failed open CV2627_a 1 C EFW to *A* OTSG isolation valve failed open.

7 TR05140 i Pressurizer level transmitter (LT1001) fails to mid-scale.

R180 (N)ormal, (R)eactivity, (1)nstrument, (C)omponent (M)ajor

• input as initial scenario setup NUREG-1021 41 of 42 Interim Rev. 8, January 1997

s

\

l Appendix D Scenario Outline Form ED-D-1 Simulator instructions for Scenano #1 Page 2 of 9 Event Malf No. Value/ Ramp / Event Description No. Input Command Delay l Inst IMF RP246 N/A Reactor Protection System channel"A" failure.  !

iMF RP247 N/A Reactor Protection System channel "B" failure. i IMF RP248 N/A Reactor Protection System channel"C" failure. l IOR -DI ICC0020_T FALSE DO Reactor Trip push-button failure.

ICM P26A_a O DO R0 *A" MFWP Siby Oil Pump fail to start.

ICM CV2645_a 1.00 DO RO EFW to "A" OTSG Control Valve fail open. l lCM CV2627_a 1.00 D0 RO EFW to "A" OTSG isolation Valve fail open.

ICM P27_a O D0 RO "A" MFWP running oil pump fails.

IOR -DO HS2827_G TRUE DO MFW Crosstle valve indicates mid-position.

IMF RX604 10 R0 ICS to EHC fails raising turbine load slowly.

IMF MS133 1.0 R7:00 Main Steam Line Break outside containment. I IMF TR051 40 R180 Pressurizer level transmitter fails.

NUREG-1021 41 of 42 Intenm Rev 8 January 1997

Appendix D Scenario Outline Form ED-D-2 Op-Test No.:,_1, Scenario No.: LES-1 Event No.: 1&2 Page 4 of 9 Event

Description:

"A" MFWP trip with stuck FW Cross-tie valve Time Position Applicants Actions or Behavior CBOR/T Identify and respond to A MFP TURBINE TRIP annunciator (K07-A7).

CBOR Venfit "A* MFWP indicates tripped.

CBOR/T Verify FW Cross-tie valve (CV 2827) opening.

CBOR Verify ICS begins reducing plant load.

CBOT Verify turbine responds to ICS demand.

CRS Obtain Loss of Steam Generator AOP (1203.027)and direct crew response.

CBOT Identify FW Cross-tie valve (CV-2827) not fully open.

CBOR Verify adequate feed water to both OTSG's as evidenced by both UTSG's remaining

>15' and feedwater is not lost completely to either OTSG.

ROLE PLAY As Auxiliary Operator, when asked to investigate cause of the MFW pump oil pump trip wait ~2 minutes then report that there N nof apparent cause for the trip. The DC oil pump is running.

As Auxiliary Operator, wnen asked to investigate the feedwater cross-tie valve wait ~3 minutes then delete the over-ride to allow the valve to fully open. Report the valve appeared to be full open and no movement was observed when taken to manual.

CBOR Venfy RCS pressure is controlled by PZR heaters and spray valve.

CBOR/T Monitor plant runback to 40% of 902 MW (~360 Mwe).

EVENT TERMINATION CRITERIA Plant is stable at -40% (-360 MWe).

NUREG-1021 42 of 42 Interim Rev. 8. Janu:uy 1997 I ... . . . ...

I I

Appendix D , Scenario Outline Form ED-D-2 Op Test No.:,,1, Scenano No.: LE S-1 Event No.: 3 Page 5 of 9 Event

Description:

ICS to EHC fails raisina turbine load slowly Time PoLtion Applicants Actions or Behavior CBOT Identify EHC attempting to raise load.

CBOT Place Turbine EHC in Oper-Auto or Manual and stabilize power below the ICS runback limit of 40% of 902MW(-360mwe).

EVENT TERMINATION CRITERIA Plant is stable at ~40% (~360MWe).

NUREG-1021 42 of 42 Interim Rev. 8. January 1997

T l

Appendix D Scenano Outline Form ED-D-2 l l

Op-Test No.:1 Scenano No.: LE S-1 Event No.: 4/5 Page 6 of 9 Event Desenption: Main Steam line break outside containment buildino.

Time Position Applicants Actions or Behavior CBOR Determine report *A* OTSG pressure dropping.

l CBOR Determine and report current RB pressure and tcmperature.

CRS Direct Rx Trip and actuation of MSLI for *A* OTSG. i

~~ ~ ~~

ton CBOR a ----- i CBOT Depress tke Turbine Trip pushbutton on C01. Venfy Turbine throttle and govemor valves closed.

CBOR Reduce letdown by closing Letdown Bypass Orifice control valve, CV-1223 on C04.

CBOR Check RCS Subcooling Margin is adequate at >30*F.

CBOR Actuate MSLI using the remote inp switch matnx *A* MSLI push-buttons on C09. (4 l push-buttons)

CRS Obtain Reactor Trip Emergency Operating procedure (1202.001) and direct crew l response.

CRS Direct reporting of immediate Actions.

CBOR Report the reactor is tripped.

CBOT Report the turbine is tripped.

CBOR Report letdown flow is minimized.

NUREG-1021 42 of 42 Interim Rev. 8, January 1997

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Appendix D Scenano Outline Form ED-D-2 Op-Test No.:_1 Scenano No.: 1 Event No.: 4/5 Page 7 of 9 Event

Description:

Main Steam line break outside containment buildino.

Time Position Applicants Actions or Behavior CBOR Report current RCS Subcooling Margin and adequacy. (RCS SCM is expected to be adequate at this time.)

CBOR Report "A" MSLI actuated.

CRS Transition to and direct crew actions per Overcooling Emergency Operating procedure (1202.003).

CBOR Check RCS SCM adequate.

CRS Provide RT6 to CBOR to venfy proper MSLI and EFW actuation and control.

CBOR Venfy proper MSLI and EFW actuation and control per RT6.

l CBOT When directed by CRS open BWST Outlet valve to operating HPl pump. 7 l

CBOR Verify PZR level control valve (CV-1235) operates to maintain PZR level >55*.

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I EVENT TERMINATION CRITERIA This event will continue through remainder of scenario.

4 NUREG-1021 42 of 42 Interim Rev. 8. January 1997 l

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7 Appendix D Scenano Outline Form ED-DT Op-Test No.: 1 Scenano No.: LES-1 Event No.: 6 Page 6 of 7 Event

Description:

EFW failure to *A* OTSG results in continued overcoolino condition.

Time Position Applicants Actions or Behavior CBOR Determine and report that EFW to 'A' OTSG control valve (CV-2645) is failed open.

CRS Direct CBOR to place CV 2645 in mtnual and attempt to close.

CBOR Place CV-2645 in manual using hand-auto control station on C09 and attempt to l close.

Report that CV 2645 does not respond to a manual demand.

CRS Direct CBOR to place EFW to "A* OTSG isolation valve (CV-2627) in manual and close.

CBOR Place CV-2627 in manual using man-auto push-button on C09 and attempt to close.

Report that CV-2627 is not closing.

l CRS Direct CBOR to verify the motor driven EFW pump (P-7B) is providing adequate flow to the 'B' OTSG.

CBOR Report that P-78 is functioning property.

l l CRS Direct CBOR to stop the steam driven EFW pump (P-7A) by any of the following l means; l e Close the MS to P-7A isolation valves (CV-2617 and CV-2667).

l

. Place in manual and close P-7A steam admission valves (CV-2613 and CV2663).

1 CBOR Close appropriate, valves as directed.tVerify Pf7A stopsfyofify EFW flow to '6'@i; l OTSG stops fV!fMM pfsgjj;$$g g

,$2h.[e;3%gsggpMjyftpglkk$$$$;sg wa t e c.:v.Q**:

M5 w k s nf+ M ?w:w m Ors2&MBLewdazw Q g* *QQyyX%g4%c.;

l NUREG-1021 42 of 42 Interim Rev. 8. January 1997 i

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Appendix D Scenano Outline Form ED-D-2 Op-Test No.:1 Scenario No.: 1 Event No.: 6 Page 8 of 9 Event

Description:

EFW failure to 'A' OTSG results in continued over coolina condition.

Time } Position j Applicants Actions or Behavior ROLE PLAY If directed as Waste Control Operator to manually isolate P-7A to "A" OTSG wait -4 minutes before reporting that you are unable to physically move the valve.

CBOR When steam to P7A is isolated, report EFW flow to *A* OTSG is stopped.

EVENT TERMINATION CRITERIA EFW flow from P7A is stopped.

NUREG-1021 42 of 42 Interim Rev. 8. January 1997 1.

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l Appendix D Scenano Outline Form ED-D-2 l

l Op-Test No.:1 Scenano No.: LES-1 Event No.: 7 Page 9 of 9

]

Event

Description:

PZR level transmitter (LT1001) fails to midscale i Time Position Applicants Actions or Behavior CBOR Determine and report that PZR level indications are mismatched. LT1001 appears to have failed CRS Direct CBOR to select valid PZR level indicator for PZR level control.

, CBOR Select LT1002 to control PZR level control valve (CV-1235) using hand switch on

( upright section of C04. i CBOR Verify CV-1235 opens to control PZR level at setpoint.

EVENT TERMINATION CRITERIA Pressurizer level control is selected to LT1002 and PZR level control valve is contro!!in0 level in auto. I I l SCENARIO TERMINATION CRITERIA This scenario may be terminated when the "A" OTSG has boiled dry and RCS pressure, temperature, and inventory are being controlled l

OR As directed by the lead examiner.

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NUREG-1021 42 of 42 Interim Rev. 8. January 1997 l

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Appendix D Scenano Outline Form ED-D-1 Facility: ANO 1 Scenano No.: 2 Op-Test No.:,,,1 ,

Examiners: Operators:

Objectives:

. Evaluate Reactor Trip immediate and follow-up actions.

. Evaluate usage of AOP loss of reactor coolant makeup.

. Evaluate actions required for control rod drive malfunctions and ESAS actuation following a Rx trip.

. Evaluate manualinitiation of ESAS and taking manual control of components actuated by ESAS.

Initial Conditions:

. ES channels 3 & 4 are failed and will not auto actuate.

. #1 EDG is out of service for repair of its govemor.

. #1 EDG output breakeris racked down.

. The 'B' HPI pump is the operating pump.

Tumover: The plant is at 80% power per dispatcher orders due to storm damaged power lines. #1 EDG OOS for govemor repair. Day 2 of 7 day time clock (LCO 3.7.2.C) Daily surveillance checks of #2 EDG are complete satisfactory.

Event Malf. No. Event Event No. Type

• Description INIT DG173 DO N/A #1 DG failure EDA 3080P Rack down A308 True DO 1 CV065100 C 100 gpm leak in 'B' HPl pump suction R60 DO N Place standby HPl pump in service.

2 CV01B DO C 'D' RCP Seal 1st stage will fail 3 TR562 I *A" Loop RCS Flow instrumentation failure.

4 RD270 C Continuous control rod insertion.

R S CV022 C 'D' RCP Seal 2nd stage failuit:

CV026 M 'D' RCP seal 3rd stage failure (LOCA)

RC006 .4 (RCS Tc leak )

R120 DO 6 ES261 DO C ES channel 3 fail to auto actuate ES262 DO M ES channel 4 fail to auto actuate 7 OVRD 1 *B' OTSG level fails high.

(N)ormal, (R)eactivity, (1)nstrument. (C)omponent (M)ajor NUREG-1021 41 of 42 Interim Rev. 8, Janualy 1997 l

i

Appendix D Scenano Outline Form ED-D-2 Simulator instruction for Scenano #2 Page 2 of 11 Event Malf No. Value/ Ramp Event Description No. Input Command Delay INIT iMF DG173 #1 EDG will not start.

MRF EDA 3080P TRUE DO #1 EDG output breaker racked down.

IMF ES261 ES channel 3 will not auto actuate.

IMF ES262 ES channel 4 will not auto actuate.

IMF CV065 100 R60 Leak in suction of *B* HPl pump.

IMF CV018 *D" RCP 1st stage RCP seal fails.

IMF TRS62 'A* loop RCS flow instrument failure. 1 IMF RX607 Continuous rod insertion.

IMF CV022 "D" RCP 2nd stage failure.

IMF CV026 *D" RCP 3rd stage failure.

IMF RC006 0.4 R120 D0 RCS leak due to seat failure.

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NUREG-1021 42 of 42 Intenm Rev. 8. January 1997 l

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Appendix D Scenano Outline Form ED-D-2

' Op-Test No.:L Sceriario No.:.2., Event No.: 1 Page 3 of 11 Event

Description:

100aom leak on suction of the "B" HPI oumo.

Time Position Applicants Actions or Behavior 2 CBOR Determine and report a nse in RCS leakage.

CBOT Monitor RB and AB sump levels, Dirty Waste drain tank level, and area rad monitors for possible leak indications.

I CBOR Determine and report leak rate change by monitoring Makeup Tank Level indication.  ;

CRS Obtain Excess RCS Leakage Abnormal Operating Procedure (1203.039) and direct  !

crew response. I NOTE It i.ek is rapesy idents d as t eino in makeup system this procedure may not be referenced.

CBOR/T Monitor operating HPl pump parameters.

1 ROLE PLAY l As Waste Control Operator (WCO), when asked to investigate operating HPI pump wait ~5 minutes and I then report that there is water vapor coming from the *B' HPI pump room doorway. l CRS Obtain Loss of RCS Makeup Abnormal Operating Procedure (1203.026) and direct crew response per section 2. Large Makeup and Purification System Leak.

CBOT Stop the *B* HPl pump.

1 CBOR Monitor Make Up Tank level and repo * 'evel dropping.

CBOR isolate Make Up Tank outlet by closing Make Up Tank Outlet valve (CV-1275).

CBOT isolate letdown by closing Letdown Coolers Outlet valve (CV-1221).

l NUREG-1021 42 of 42 Interim Rev. 8, January 1997

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! l Appendix D Scenano Outline Form ED-D-2 l

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)

Op-Test No.: 1 Scenario No.: 2 Event No.: 1 Page 4 of 11 Event

Description:

100aom leak on suction of the *B' HPl oumo. I Time Position Applicants Actions or Behavior I CBOR Verify ICW pumps nJnning.

i CBOT Verify RCP seats are being cooled by ICW. j CBOR Close in Hand the following valves;  !

• RCP Total Seal Injection Flow Control Valve (CV-1207) e PZR Level control valve (CV-1235).

CBOR Verify RCP Seal injection Block valve (CV-1206) closed.

CBOT Select "B" HPl on SPDS to evaluate pump parameters.

CBOR Batch add to Make Up Tank as required to raise tank level to >55 inches.

ROLE PLAY As WCO, after "B" HPI pump is tumed off wait ~4 minutes then report that the source of leakage is a weld on an elbow at the suction of the HPl pump between MU-188 and the pump. It is isolable.

When directed, isolate the leak as follows l MRF' CVMU18B 0 DO R0 Suction isolation valve  !

MRF CVMU20B 0 DO R0 Discharge isolation valve l MRF CVMU21B 0 DO R0 Recirc isolation Valve l Wait ~6 minutes then report the listed valves as closed. )

l if directed to vent the STBY HPI pump wait ~2 minutes then report the pump is vented. .

l As Auxiliary Operator (AO), when directed to rack down *B' HPl pump breakers as follows; MRF EDA 3070P True MRF EDA 4070P True l

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NUREG-1021 42 of 42 Interim Rev. 8. January 1997 l

q Appendix D Scenano Outline Form ED-D-2 Op-Test No.: 1_ Scenano No.:_2. Event No.: 1 Page 5 of 11 Event

Description:

100aom leak on suction of the *B* HPl oumo.

Time Position Applicants Actions or Behavior CBOR/T Verify STBY HPl pump suction pressure >10psig.

CBOT When directed start STBY HPl pump lube oil pump.

CBOT When directed start STBY HPl pump.

CBOT Stop the STBY HPI pump lube oil pump.

CBOR Place RCP Block push-button in over-ride (OVRD light on).

CBOR Open RCP Block valve (CV-1206).

CBOT Verify RCP seal bleed off temperatures <180*F.

CBOR Slowly open RCP Total Seal injection Flow control valve (CV-1207) to establish 12gpm to each RCP seal.

CBOR Remove RCP Seal Block valve over-ride push-button from over-ride (OVRD light off).

NUREG 1021 42 of 42 Interim Rev. 8. January 1997

Appendix D Scenario Outline Form EO-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 1 Page 6 of 11 Event

Description:

100aDm leak on suction of the *B" HPI oumo.

Time Position Applicants Actions or Behavior CBCR Slowly open PZR Level Control valve (CV-1235) until make up flow indication is on  !

scale.

CBOR Adjust PZR level setpoint to desired value and place PZR Level Control valve (CV-1235) in auto.

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EVENT TERMINATION CRITERIA

'C' HPI pump in service providing normal seat injection and make up with RCP Total Seal injection Flow control valve (CV-1207) and PZR Level Control valve (CV-1235) both in automatic.

NUREG-1021 42 of 42 Interim Rev. 8, January 1997

Appendix D Scenano Outline Form ED-D-2

' Op-Test No.:_1_ Scenano No.: 2 Event No.: 2 Page 7 of 11 Event

Description:

• D* RCP ist staoe failure.

Time Position Applicants Actions or Behavior 20 CBOR/T Identify and report RCP BLEEDOFF FLOW Hi annunciator (K08-87).

min identify and report cause of alarm to be *D* RCP ist stage seal.

CRS Obtain Reactor Coolant Pump and Motor Emengency Abnormal Operating procedure (1203.031) and direct crew response per Section 1, Seal Degradation.

CBOR Verify the following valves; e RCP Seal Injection Block valve (CV-1206) open e RCP Total Seal injection Flow (CV-1207) open and flow at 32-40 gpm.

CBOR Verify individual RCP Seal flows at 8-10 gpm.

CBOT Venfy the following; e Peak to peak seal pressure oscillations are <800 psi.

. P across any stage <2/3 system pressure.

. RCP seal temp <180*F.

. RCP seal bleed off temp <40*F above 1st stage temp.

NOTE seal bleedoff temperature will nse to <4o F above 1st stage temp EVENT TERMINATION CRITERIA This event will remain in place for the remainder of this scenario. No change in this malfunction will occur.

NUREG-1021 42 of 42 Interim Rev. 8. January 1997

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I i 1 l Appendix D Scenano Outline Form ED-D-2 1

l Op-Test No.:_1.,, Scenario No.: 2 Event No.: 3&4 Page 8 of 11 Event

Description:

'A' Loop RCS flow instrumentation failure.

l Time Position Applicants Actions or Behavior i CBOR/T Identify and report RCS FLOW LO annunciator (K09-D2).

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l l CBOR Determine and report *A* Loop RCS flow indication dropping.

l CBOR Determine and report that the control rods are inl.erting with'no demand.

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! CBOR Place Diamond Rod Control Panel in manual to stop rod motion.

j CBOR/T Match reactor power and turbine load.

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, l l ROLE PLAY l If contacted as engineering support to aid in identifying the cause of the problem inform control j l

personnel that investigation will commence.  !

! Wait ~3 minutes and if not notified, then call control room as EOC Dispatcher and inquire as to the i reason for power reduction. Direct Control Room to retum to 80% (~675MWe net).

CRS Direct CBORfr to raise load to retum to 80%.

l CBOR/T Raise reactor power and turbine load as required to retum unit to ~80%.

l EVENT TERMINATION CRITERIA Unit has commenced power escalation to 80%.

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NUREG-1021 42 of 42 Interim Rev. 8 January 1997 l

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A' Ahdix D Scenano Outline Form ED-D-2 1

Op-Test No.:_1._ Scenario No.: 2 Event No.: 5 and 6 Page 9 of 11 Event

Description:

RCP seal failure resultino in LOCA and ES Channel 3 and 4 auto-initiate failure..

Time Position Applicants Actions or Behavior 25 CBOT Identify and report *D' RCP Seat 2nd stage failure.

min 26 CBOT Identify and report *D* RCP Seal 3rd stage failure.

min CBOR Identify and report increase in RCS leakage.

CBOR Trip the reactor based on indications of LOCA, NOTE An automate reactor trip may occur before the CBOR is able to depress the reactor trip push-button.

CBOR/T Determine and report that ES channels 3 and 4 failed to automatically actuate.

CBOR CRS OtMain Reactor Trip Emergency Operating procedure (1202.001) and direct crew response.

CRS Direct reporting of Immediate Actions.

CBOR Report the reactor is tripped.

NUREG-1021 42 of 42 Interim Rev. 8. January 1997

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Apperldix D Scenario Outline Form ED-D-2 l I

Op-Test No.:1 Scenano No.: 2 Event No.: 5 and 6 Page 10 of 11 Event

Description:

RCP seal failure resultino in LOCA with ES Channel 3 and 4 auto initiate failure..

Time Position l Applicants Actions or Behavior l CBOT Report the turbine is tripped.

CBOR Report letdown flow is minimized.

CBOR Report current RCS Subcooling Margin and adequacy.

NOTE  !

RCs sCM we be inodoquete at this point. Crew win stop ad running RCP's.

, CBOR l Determine and report ES Channels 3 and 4 have met valid trip setpoints and have l failed to initiate, l

CBOR Depress the trip push-buttons on C04 to manually actuate ES Channels 3 and 4.

CRS If RCP's are not stopped SCM direct the CBOT to verify <2 minutes have elapsed and stop all running RCP's.  ;

I  :

CBOT Verify <2 minutes have elapsed since the loss of SCM and stop all running RCP's.

! l l l CRS Direct CBOT to venfy proper ES actuation per RT10.

l NOTE

! May direct CBOR to venfy proper EFW actuation using RTS or RTS as an assist to CBOT and RT10.

I CBOT Using RT10 verify complete and proper ESactuatioin.

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NUREG 1021 42 of 42 Interim Rev. 8. January 1997

Appendix D Scenano Outline Form ED-D-2 l

l Op-Test No.:1 Scenano No.: 2 Event No.:_1 Page 11 of 11 Event

Description:

"B* OTSG level indication fails hiah.

Time Position Applicants Actions or Behavior i CBOR/T Determine and report that *B* OTSG level has disparate indications.

l CBOR/T Venfy EFW operating properly.

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CBOR/T Using additional instruments determine and report that Ll"" has failed.

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l EVENT TERMINATION CRITERIA EFW actuation and control verified, and failed instrument identified.

SCENARIO TERMINATION CRITERIA RCS on LPI cooling with proper ESAS actuation verified per RT10 OR As directed by the lead examiner.

NUREG-1021 42 of 42 Interim Rev. 8. January 1997 L

Appendix D Scenano Outline Form ED-D-1 Facility: ANO-1 Scenario No.:_5_ Op-Test No.: N/A *-

Examiners: Operators:

Objectives:

Evaluate Reactor Trip immediate and follow-up actions.

Evaluate proper monitoring of turbine generator Evaluate usa 0e of EOP to mitigate degraded power.

Evaluate usage of EOP to correct Blackout.

Initial Conditions:

. The RPS is failed and will not cause an automatic trip.

. #2 EDG will fail to respond to an automatic or manual start signal. #2 EDG can be started locally.  ;

e HD4B is throttled to cause T40B level to rise above the HLD when >85% power i Tumover:

Plant is at 100% power. SU2 transformer is OOS for maintenance to repair an oilleak. The time clock will end tonight at 10pm. The transformer is expected to be retumed to operation at Spm. All Tech Spec requirements for the inoperability have been met.

Event Malf. No. Event Event No. Type

• Description 1 RP246 C RPS failure to inp RP247 RP248 RP249 2 FWO87 N P8B heater dngump beanng heat up and inp j 3 RX599 i 'B' MFP fails to respond to power reduction signal from ICS.

73.8 C 4 OVRD 1 'A' MFWP suction pressure drops dunng power reduction.

5 IOR-DI M Turbine trips without an RPS trip l PB9201_T R .

TRUE DO I 6 ED180 C SU1 Lockout l 7 DG176 C EDG #2 fails to auto start 8 IOR -Di C EDG #2 C10 start PB will not work CSI-DG2_S 9 DG173 M EDG #1 Trip (Blackout)

(N)ormal, (R)eactivity, (1)nstrument, (C)omponent (M)ajor

• This exam is a replacement exam for Exam Set #1.

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l NUREG-1021 41 of 42 Interim Rev. 8, January 1997 b

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Appendix D Scenano Outhne Form ED-D-2 SIMULATOR INSTRUCTIONS FOR SCENARIO #5 Page 2 of 9 Event Malf No. Value/ Ramp Event Desenption No. Input Command /

Delay IMF RP246 *A* RPS Channel fail to auto actuate IMF RP246 *B* RPS Channel fail to auto actuate IMF RP247 *C' RPS Channel fail to auto actuate IMF RP249 *D' RPS Channel fail to auto actuate IMF DG176 #2 DG fails to auto start IOR -Di CSI-DG2_S FALSE DO #2 DG start push-button on C10 will not work.

MRF EDH2300P TRUE Start Up Transformer breaker racked down.

MRF EDH1300P TRUE Start Up Transformer breaker racked down.

MRF EDA 1110P TRUE Start Up Transformer breaker racked down.

MRF EDA 2110P TRUE Start Up Transformer breaker racked down.

MRF HD4B 30 R60 HD-48 throttled to 30%

IMF FWO67 Heater Drain Pump (P8B) bearing heat up and trip.

IMF RX599 73.8 *B" MFWP fails to respond to power reduction signal.

IOR *A* MFWP Suction pressure drops during power reduction.

IOR -DI PB9201_T TRUE Turbine trip.

IMF ED180 Start Up #1 Transformerlock out.

IMF DG173 #1 DG trip.

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NUREG-1021 42 of 42 Interim Rev. 8, January 1997

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l Appendix D Scenano Outhne Form ED-D-2

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l Op-Test No.: STBY Scenario No.: 5 Event No.: 2,3, and 4 Page 3 of 9 l

! Event

Description:

"B" Heater Drain Pump (P88) bearing heat up and trip. l l Time Position Applicants Actions or Behavior )

CBORIT Identify and report P8A/PBS BRG TEMP Hi annunciator (K06-D8), l I

l l CBOT Reference temperature recorder TR2890 to identify pump in alarm.

l NOTE Pumo may ino tutore identrestion. ,

CBOR/T Identify and report e CONDENSATE PUMP AUTO START annuciator (K06-A7)

• PSA/P8B FLOW LO annuciator (K06 A8) ]

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CRS Reference Annuciator Corrective Action 1203.012E. I i

l CBOR Reduce unit power to -85%.

I CBOR/T Detennine and report that the "B" MFWP is not responding to ICS demand.

i f CBOR/T Take control of the "B" MFWP and reduce MFWP speed to match feedwater flow to demand.

j CBOR/T Determine and report that the 'A' MFWP suction pressure is dropping when it should be rising. Using attemate indications verify that the actual pressure is rising and there appears to b an instrument failure.

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EVENT TERMINATION CRITERIA Unit is stable ~BS% power with feedwater balanced at demand, t

Y NUREG-1021 42 of 42 Interim Rev. 8. January 1997 i

Appendix D Scenano Outline Form ED-D-2 Op-Test No.: STBY Scenano No.: 5 Event No.: 5 Page 4 of 9 Event

Description:

Turt)ine trip without a reactor trip.

Time Position Applicants Actions or Behavior CREW Determine and report Turbine Trip.

CBOR Determine and report the reactor failed to trip.

!N- -

i GWw.>,.. mw n n ': u ifkf Ib, hi fhkk

+ e 8 sr- >,nvL : , *': x ;e + +uu:w 3 72ik G CREW Perform Reactor Trip immediate actions.

CBOR Depress the reactor trip push-button. Venfy all rod inserted and reactor power dropping.

CBOT Depress the turbine trip push-button. Venfy turbine throttle and govemor valves closed.

CBOR Reduce letdown by closing Orifice Bypass valve (CV-1223).

CBOR Check adequate SCM.

CRS Reference Reactor Trip Emergency Operating procedure (1202.001).

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l EVENT TERMINATION CRITERIA Unit is stable in hot shutdown condition.

NUREG-1021 42 of 42 Intenm Rev. 8. January 1997

Appendix D Scenano Outline Form ED-D-2 Op-Test No.: STBY Scenano No.: 5 Event No.: 6,7,8 and 9 Page 5 of 9 Event

Description:

Start Up #1 lock out and failure of #2 EDG to start.

Time Position Applicants Actions or Behavior CBOR/T Identify and report SU 1 TROUBLE annunciator (K02-C1).

ROLE PLAY When directed, as Auxiliary Operator, to investigate SU #1 transformer wait ~2 minutes then report a high winding temperature of 125'C with all pumps and fans running.

CREW Identify and report SU 1 L.O. RELAY TRIP (K02-A1).

CBOR/T Determine and report #2 DG did not auto start.

CBOT Attempt to start #2 DG using the push-button o C10. Report that #2 DG does not start. l l

CRS Transition to Degraded Power Emergency Operating procedure (1202.007). i l

CBOT Close SW Crosstie valve for SW Loop 2 (CV-3640).

CRS Dispatch Auxiliary Operator to attempt to locally start #2 DG.

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ROLE PLAY When sent to start #2 DG do not start until after #1 DG trips and the unit is in Black Out.

CRS Utilize ES Electrical Operating procedure (1107.002) Altemate AC Generator Operation section.

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NUREG-1021 42 of 42 Interim Rev. 8. January 1997

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t l Appendix D Scenano Outline Form ED-D-2 l

l Op-Test No.: STBY Scenano No.: 5 Event No.: 6,7, and 8 Page 6 of 9 l Event

Description:

Start Up #1 lock out and failure of #2 EDG to start.

Time l Position l Applicants Actions or Behavior j

i. ROLE PLAY l

When directed to manually open the de-energized BWST outlet valve, as appropriate; l lCM CV1407_a l lCM CV1408 a if directed as Auxiliary Operator to operate ADV Control valves or isolation valves adjust using the following commands; ADV Control ADV isolation l *A*OTSG ICM CV2668_a ICM CV2672_a

• B*OTSG lCM CV2618_a ICM CV2619_a CBOR/T Verify SW to DG1 Coolers open (CV-3806).

! CBOR Actuate MSLI for both OTSG's using push-buttons on CC9 (8 push-buttons).

Verify proper actuation and control per RT6.

CBOT isolate letdown by closing Letdown Cooler Outlet valves (CV-1214 and CV1216).

l l CBOT Place RCP Seal Bleedoft (Altemate Path to Quench Tank) controls in Close l (SV-1270,1271,1272,1273).

l CBOT Isolate RCP Seal Bleedoff (Normal) by closing CV-1270,1271,1272, and 1273, i

l l EVENT TERMINATION CRITERIA This event will remain in effect until after the final event.

NUREG-1021 42 of 42 Interim Rev. 8. January 1997 i

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Appendix D Scenario Outline Form ED-D-2 i Op-Test No.: STBY Scenano No.: 5 Event No.: 7,8, and 9 Page 7 of 9 Event

Description:

Station Blackout and transition to Degraded Power.

Time Position Applicants Actions or Behavior CREW Determine and report that #1 DG has tripped.

CRS Transition to Black Out Emergency Operating procedure (1202.008).

CBOR Venfy proper EFW actuation and control per RTS.

CRS Notify Unit 2 that the AAC Generatoris needed.

CRS Notify operator previously dispatched to #2 DG that the unit is in a Blackout Condition.

CBOR Check SCM adequate.

CBOT Verify the following handswitches in PULL-TO-LOCK; l l

i. . EFW Pump (P78) i e Bus A1 Bus A2 Bus H1 Bus H2 A-111 A-211 H 13 H-23 A-11?. A-212 H-14 H-24 A-113 A 213 H-15 H-25 e Condensate Pumps (P2A, B, C)

ICW Pumps (P33A, B, C) l l

1 1 l l NUREG-1021 42 of 42 Intenm Rev. 8, January 1997 1

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Appendix D Scenario Outline Form ED-D-2 Op-Test No.: STBY - Scenario No.: 5 Event No.: 7,8, and 9 Page 8 of 9 Event

Description:

Station Blackout and transition to Degraded Power.

Time Position Applicants Actions or Behavior ROLE PLAY Start #2 DG as follows; DMF DG173 Notify control room as AO that #2 DG has started and is running with no abnormal indications.

The reason for the trip of #1 DG is a loss of tube oil trip.

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CRS Transition to Degraded Power Emergency Operating procedure (1202.007).

I ROLE PLAY j Start the AAC Generator as follows;

],

MRF EDA 901 IN DO Notify the control room that the AAC Generator is running and breaker 901 is closed.

CBO/T Verify SW to #2 DG Coolers (CV-3807) open.

CBOT Verify *C* SW Pump is running. ,

i i

CBOR Reverify MSLI and EFW per RTS.

CBOR Verify RCP Seal injection Block valve closed (CV-1206).

CBOT Close RCS Makeup Block valve (CV-1233 or CV1234).

CBOT Open BWST outlet to OP or STBY HPl pump (CV1408).

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NUREG-1021 42 of 42 Interim Rev. 8, January 1997 l

Appendix D Scenario Outline Form ED-D-2 l Op-Test No.: STBY Scenano No.: 5 Event No.: 7,8, and 9 Page 9 of 9 Event

Description:

Station Blackout and transition to Degraded Power. ,

l \

Time Position Applicants Actions or Behavior CBOT Start Aux Lube Oil pump for OP or STBY HPl pump. ,

l I CBOT Start the OP or STBY HPl pump. )

1 1

I CBOT Stop Aux Lube Oil pump for OP or STBY HPl pump.

CBOT Operate HPl Block valve associated with running HPl pump (CV-1220 or CV-1285) as required to maintain PZR level >55"..

CREW Verify time since loss of off site power occurred. I if $30 minutes restore RCP seal injection.

If >30 minutes do not establish seal injection at this time.

l CBOT Maximize RB Cooling per RT9.

l l

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l EVENT AND SCENARIO TERMINATION CRITERIA l Unit is stable in hot shutdown condition on natural circulation.

j NUREG-1021 42 of 42 Interim Rev. 8, January 1997 1

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Appendix D Scenano Outline Form ED-D-1 Facility: ANO-1 Scenano No.:_3 Op Test No.: 2_

I Examiners: Operators:

Objectives:

Evaluate Reactor Trip and immediate follow-up actions.

Evaluate usage of AOP for control rod drive malfunction, and pressurizer systems failures, e Evaluate usage of EOP to correct Degraded Power condition.

Initial Conditions; e EFIC will fail to automatically actuate EFW.

. Seismic alarm is spurious, l&C is investigating.

l Tumover.100% power equilibrium xenon. The .01 seismic earthquake alarm is in and no other alarms or indications, l&C is investigating. Thunderstorm wamings for state.

Event Maif. No. Event Event No. Type

• Description 1 N Dispatcher directs down power due to sever weather damaging i transformers at Mayflower substation 2 OVRD i P2A beanng temp failure.

3 ED180 M Start Up #1 lock out.

l 4 RD293 R Drop rod 7 - 3 5 TR458 i Controlling RCS pressure fails to 2280#

2280 R240 6 IOR -DO I PZR spray valve leaks by with closed indication.

l HS1006_R C False ICM CV1008_a

.1 7 ED183 M Loss of Offsite Power 8 FW621 C EFIC channel A,8.D initiate module fails 9 DG175 C #1 EDG will not auto start.

(N)ormal, (R)eactivity, (1)nstrument. (C)omponent (M)ajor l

l NUREG-1021 41 of 42 Interim Rev. 8, January 1997 i

l l

Appendix D Scenano Outline Form ED-D-2 Simulator instruction for Scenario #3 Page 2 of 10 Event Malf No. Value/ Ramp Event Desenption No. Input Command / Delay INIT LOR -DO K15C1 TRUE Seismic Trigger XSH-8007 0.01G annunciator.

IOR -DO K12F1 TRUE K15 NON-CRITICAL TROUBLE annunciator.

IMF FW621 EFIC Channels A. B. D initiate modules fail.

IMF DG175 #1 EDG auto start failure.

Condensate pump P2A bearing temperature instrumentation failure.

IMF ED180 Start Up transformer lock out.

IMF RD293 Group 7, rod 3 drops.

IMF TR458 2280 R240 Controlling RCS pressure fails to 2280psig.

LOR -DO HS1008 R FALSE PZR spray valve leaks by with closed indication.

ICM CV1008_a 0.1 IMF ED183 Loss of nff site power.

o NUREG-1021 42 of 42 Interim Rev. 8. January 1997

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( Appenoix D Scenano Outline Fonn ED-D-2 l

Op Test No.: 2 Scenano No.: 3 Event No..: 1 Page 3 of 10 Event

Description:

EOC Dispatcher directs power reduction due to severe weather damaging l transformers at Mayflower substation.

Time l Position l Applicants Actions or Behavior i ROLE PLAY l Call control room as EOC Dispatcher and direct unit to reduce power to 650 Mwe as soon as possible ]

due to transformer damage at the Mayflower substation.

]

If asked by control room personnel inform them that there 1.* serious concem over grid stability due to the severe weather and substation damage.

I CRS Direct CBOR to reduce unit load to 650 Mwe.

CBCR Commence reduction in unit load to 650 Mwe.

l CBOT Verify Turbine EHC responds to ICS.

I f

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EVENT TERMINATION CRITERIA Unit stable at -650 Mwe or as directed by the lead examiner.

NUREG-1021 42 of 42 Intenm Rev. 8 January 1997

Appendix D Scenano Outline Form ED-D-2 Op-Test No.: 2 Scenario No.: 3 Event No.: 2 Page 4 of 10 Event

Description:

Condensate pump P2A bearing temperature failure.

Time Position Applicants Actions or Behavior CBOR/T Identify and report COND PUMP BRG TEMP Hi annunciator (K06-D7).

CRS Reference Annunciator Corrective Action (1203.012E).

Direct CBOT to determine alarm source using motor winding temperature chart recorder TR2808 on panel C19 CBOT Observe source of alarm on TR2808 is P2A.

CRS Direct Auxiliary Operator to investigate P2A.

ROLE PLAY When directed by control room to investigate P2A wait ~3 minutes then report that P2A appears to be working property with all cooling water aligned. The pump does not appear to be any warmer than normal.

CREW Determine that the bearing temperature is erroneous.

EVENT TERMINATION CRITERIA Determination that bearing temperature is erroneous OR Standby condensate pump is in service and P2A is off.

NUREG 1021 42 of 42 Interim Rev. 8. January 1997

Appendix D Scenano Outline Form ED-D-2 Op-Test No.: 2 Scenario No.: 3 Event No.: 3 and 4 Page 5 of 10 Event

Description:

Lockout of Startup Transformer #1 and Control Rod 7-3 drop.

Time Position Applicants Actions or Behavior CBOR/T Identify and report the following annunciators;

. SU1 L.O. RELAY TRIP (K02-A1)

. CRD MOTOR POWER FAILURE (K06 F2)

. CONTROL ROD ASYMMETRIC (K08-C2) i CREW Determine and report the loss of SU #1 transformer.

CREW Identify control rod 7-3 dropped.

CBOR Verify ICS runback to 40% (-360Mwe),

CBOT Verify Turbine Eh'C responding to runback signal.

CRS Reference Control Rod Drive Malfunction Action (1203.003) Section 1, Asymmetric Rod.

CRS Reference Technical Specifications 3.5.2.2 CBOT Collect the following from the plant computer NASP menu 1202.003 Programs;

. Imbalance Tilt, and Rod index

. Uncorrected SPND Report

. Corrected SPND Report i

i 1

l

. EVENT TERMINATION CRITERIA Unit stable at -360 Mwe.

NUREG-1021 42 of 42 Interim Rev. 8. January 1997

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l Appendix D Scenano Outline Form EO-D-2 Op-Test No.: 2 Scenario No.: 3 Event No.: 5 and 6 Page 6 of 10

( Event

Description:

Controlling RCS pressure fails and PZR Spray Valve leaks through.

Time Position Applicants Actions or Behavior j CBOR Identify and report a dispanty between RCS pressure indications.

NOTE Crew may or may not identify the PzR spray vetve simuttaneous with pressure indcation failure.

CREW Reference panel indications, plant computer and SPDS to identify failed RCS pressure indication.

CBOR Determine and report that the failed indication is controlling RCS pressure.

CRS Direct the CBOR to select the attemate RCS pressure indication for coritrol.

I 1

CREW Determine and report that RCS pressure control is sporadic.

CRS Reference Pressurizer Systems Failure (1203.015), Pressurizer Spray Valve (CV-1008) Failure section.

CBOR Place PZR Spray valve in HAND and attempt to torque closed.

CBOR When directed close PZR Spray isolation valve (CV-1009). l

' CREW Celecmine and report that RCS pressure is recovering. l I

i EVENT TERMIN.ATION CRITERIA Pressurizer Spray isolation valve closed with RCS pressure stable at ~2155psig.

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i NUREG 1021 42 of 42 Interim Rev. 8, January 1997

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, Appendix D Scenario Outline Form ED-D-2 Op-Test No.: 2 Scenano No.: 3 Event No.: 7,8, and 9 Page 7 of 10 Event

Description:

Loss of offsite power with failure of #1 EDG to auto start and EFIC to auto initiate.

Time Position Applicants Actions or Behavior l l CREW identify loss of offsite power.

l CREW Carry out immediate actions for a reactor trip.

CBOR Depress the Reactor Trip push-button. l Verify all rods inserted and Reactor power dropping.

CBOT Depress the Turbine trip push-button. l Verify Turbine throttle and govemor valves closed.

l CBOR Reduce letdown flow by closing Orifice Bypass valve (CV 1233).

CBOR Verify Adequate SCM.

CRS Direct reporting of immediate actions.

CRS Transition to the Degraded Power Emergency Operating Procedure (1202.007).

CBOR/T Verify service water to both EDG's.

I  !

CBOR Actuate MSLI for both OTSG's using push-buttons on C09. l Venfy proper actuation using RT6.

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NUREG-1021 42 of 42 Interim Rev. 8, January 1997 l

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

Appendix D Scenario Outline Form ED-D-2 Op-Test No.: 2 Scenario No.: 3 Event No.: 7, 8, and 9 Page 8 of 10 l

Event

Description:

Loss of offsite power with failure of #1 EDG to auto start and EFIC to auto initiate.

l Time Position Applicants Actions or Behavior ._

l CBOT' isolate letdown by closing Letdown Coolers Outlet valve (CV-1222).

l l -

CBOT Place RCP Seal Bleedoff (Altemate path to Quench Tank) controls in CLOSE (SV-1270,1271,1272, and 1273).

CBOT isolate RCP Seal Bleedoff (Nomtal) by closing either; CV-1274 OR CV-1271,1272,1273, and 1274.

CBOT Verify the following handswitches in PULL-TO-LOCK; e A1, A2, H1, and H2 feeder breakers:

Bus A1 Bus A2 Bus H1 Bus H2 A-111 A-211 H-13 H-23 A-112 A-212 H-14 H-24 A-113 A-213 H-15 H-25 e Condensate Pumps (P2A, B, and C)

. ICW Pumps (P33A B, and C).

l CREW Place OP or STBY HPI pump in service.

CBOR Verify Seal injection Block valve (CV-1206) closed.  !

l I

i NUREG-1021 42 of 42 Interim Rev. 8. January 1997

_ ._ _ _ . . _ . _ . ~ . . _. _ . - . . _ . - . _ _ . _ ~ . . _ - . _ . _ . _ . . _ __ _ _ . . . _ _ .

Appendix D Scenano Outline Form ED-D-2 Op-Test No.: 2 Scenario No.: 3 Event No.: 7. 8, and 9 Page 9 of 10 Event

Description:

Loss of offsite power with failure of #1 EDG to auto start and EFIC to auto initiate.

Time Position Applicants Actions or Behavior CBOT Close RCS Makeup Block valve (CV-1233 or CV-1234).

CBOT Open BWST Outlet valve to OP HPI (CV-1407 or CV-1408).

CBOT Start Aux Lube Oil pump for OP or STBY HPI pump.

CBOT Start OP or STBY HPl pump.

CBOT Stop Aux Lube Oil pump for OP or STBY HPl pump.

CBOT As directed operate the HPl block valve associated with running HPI pump (CV-1220 or CV-1285) to maintain PZR level >55*. .

CREW Check 5,30 minutes have elapsed since loss of offsite power occurred.

CRS Direct Waste Control Operator to; e Close Seal injection Control valve inlet (MU-1207-1).

• Standby to operate Seal injection Control bypass valve (MU-1207-3)

CBOR Place in over nde (OVRD light on) and open Seal injection Block valve (CV-1206).

CREW Direct WCO to slowly throttle open MU-1207-3 until RCP Seal Total injection flow is 8-12 gpm.

NUREG 1021 42 of 42 Interim Rev. 8. January 1997

Appendix D Scenano Outline Form ED-D-2 Op-Test No.: 2 Scenario No.: 3 Event No.: 7,8, and 9 Page 10 of 10 Event

Description:

Loss of offsite power with failure of #1 EDG to auto start and EFIC to auto initiate.

Time Position Applicants Actions or Behavior CBOT Re-establish RCP Seal Bleedoff using A!!emate Path to Quench Tank.

CBOT Maximize RB cooling using RT9.

ROLE PLAY When notified as EOC Dispatcher to restore power inform control room that time to restore power is unknown until an assessment of switchyard damage is complete.

As Auxiliary Operator if directed to examine switchyard wait ~5 minutes then notify control room that one 500KV tower is down and at least two others show dan. age.

EVENT AND SCENARIO TERMINATION CRITERIA Unit is stable in a degraded power condition on natural circulation.

NUREG-1021 42 of 42 Interim Rev. 8, January 1997 i

l l

i Appendix D Scenano Outline Form ED-D-1 Facility: ANO-1 Scenano No.:_4 Op-Test No.:_g,.

Examiners: Operators: ,

i Objectives: )

. Evaluate Reactor Trip immediate and follow-up actions. l

. Evaluate usage of EOP for Steam Generator Tube Rupture.

. Evaluate usage for Loss of RCS Makeup and Loss of SG Feed.

initial Conditions:

100% power, MOL, Equilibrium Xenon.

Tumover:100% operations, equalibrium xenon, outside AO is cleaning screens, housekeeping is dusting ,

and wiping down the #1 DG room.

Event Malf. Event Event No. No. Type

• Description 1 RX605 C False lowenng of the turbine EHC.

30 2 N Retum to previous power directed by EOC Dispatcher.

3 FWO74 C Trip of 'A' Main Feed Pump 4 CV2820 1 MFP trip + 10 sec FW cross-tie valve sticks at 95% open.

a.95 5 RC001 C 'A' OTSG tube leak O.001 6 RC001 M 'A' OTSG tube rupture.

0.4 R 7 CV095 i Heatup of ES HPI pump motor winding resulting in pump trip.

C 8 OVRD l 'A' OTSG level fails high slowly.

(N)ormal, (R)eactivity, (i)nstrument, (C)omponent (M)ajor l

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l NUREG-1021 41 of 42 Intenm Rev. 8. January 1997 i

l

Appendix D Scenano Outline Form ED-D-2 Simulator instructions For Scenano #4 Page 2 of 10 Event Malf No. Value/ Ramp Event Desenption No. Input Command Delay l lMF RX605 30 False lowering of Turbine EHC.

l t

t IMF FWO74 *A* MFW Pump trip.

l l ICM CV2820,,,a 0.95 Feedwater Crosstie valve sticks at 95% open.

IMF RC001 0.001 R60 "A* OTSG tube leak.

MMF RC001 0.4 R300 *A* OTSG tube rupture.

i IMF CV095 ES HPl pump trip due to motor winding fault.

I IOR -AO *A* OTSG level fails high.

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NUREG-1021 42 of 42 Intenm Rev. 8, January 1997 I

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i-Appendix D Scenano Outline Form ED-D-2

Op-Test No.

2 Scenario No.: 4 Event No.: 1 Page 3 of 10 Event

Description:

False lowering of Turbine EHC Time Position Applicants Actions or Behavior CREW Determine and report that unit load is dropping.

CBOT Determine and report that Turbine EHC is lowering for unexplained reason.

CBOT Place Turbine EHC in Oper Auto or Manual.

CBOT Stabilize unit load.

CBOR Verify plant parameters within limits for current power level.

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EVENT TERMINATION CRITERIA Unit stable with Turbine EHC in Oper Auto or Manual.

NUREG-1021 42 of 42 Interim Rev. 8, January 1997

Appendix D Scenario Outline Form ED-D-2 Op-Test No.: 2 Scenario No.: 4 Event No.: 2 Page 4 of 10 Event

Description:

Unit load raised by direction of EOC Dispatcher.

Time l Position l Applicants Actions or Behavior ROLE PLAY After unit is stable wait ~S minutes then call control room as EOC Dispatcher and direct unit to retum to previous powerlevel. If control room is reluctant to raise powerinform CRS that the system is heavily loaded and the power is needed.

CRS Direct CBOT to raise unit load to 100%.

CBOT Raise load using Turbine EHC controls.

CBOR Verify ICS responds to increase in generator output.

EVENT TERMINATION CRITERIA Unit is stable at ~100 or as directed by lead examiner.

NUREG-1021 42 of 42 Interim Rev. 8, January 1997

Appendix D Scenano Outline Form ED-D-2 Op-Test No.: 2 Scenario No.: 4 Event No.: 3 and 4 Page 5 of 10 Event

Description:

"A" MFW Pump ,

Time Position Applicants Actions or Behavior CBOR/T Identify and report A MFP TURBINE TRIP (K07-A7).

CRS Reference Loss Of Steam Generator Feed Abnormal Operating procedure (1203.027).

i CBOR Verify OTSG levels are >15".

CBOT Reduce unit load to 40% (-360Mwe) using the Turtine EHC in Oper Auto or Manual.

CBOR/T Verify Feedwater Crosstie valve opens.

i CBOR Verify ICS reduces reactor power to 40% (-360Mwe).

CBOR Verify PZR heaters and spray operate to control RCS pressure.

I ROLE PLAY If instructed as Auxiliary Operator to investigate the tripped MFW Pump wait ~5 minutes then report that you can find no reason for the pump to be tripped.

t L-EVENT TERMINATION CRITERIA r

n Unit is stable at ~40% (-360 Mwe).

l NUREG 1021 42 of 42 Interim Rev. 8. January 1997 1

L

Appendix D Scenano Outline Form ED-D-2 Op-Test No.: 2 Scenano No.: 4 Event No.: 5 Page 6 of 10 Event

Description:

'A' OTSG tube leak.

Time Position Applicants Actions or Behavior CBOR/T Identify and report A OTSG N16 TROUBLE annunciator (K07 A5).

CBOR Begin leak rate determination.

~

CRS Reference Small Generator Tube Leaks Abnormal Operating procedure (1203.023).

ROLE PLAY If notified as Chemistry to determine leak rate; using condenser off gas wait -30 minutes using steam generator sample wait ~45 minutes then report approximate leak rate displayed on PS1 display.

CRS Reference Rapid Plant Shutdown Abnormal Operating procedure (1203.045). Direct CBOT to commence a plant shutdown at ~5% per minute.

CBOT T4 e shter,vw6gc ;.1cq,Th.24 ispHC1n Oper Auto or Manual.WSvh

.%%$l N k ., $ r  !

CRS Direct Auxiliary Operators to implement Control of Secondary Contamination Abnormal Operating procedure (1203.014).

CBOT Select ANALYZER position for "A" OTSG N3s detector.

CBOR Place SG EFW Pump Turbine (K3) Steam Supply valve (CV-2667) in MANUAL and close.

CRS Notify Health Physics to commence monitoring of secondary system for nsing radiation levels.

^

EVENT TERMINATION CRITERIA This malfunction will remain in effect for the remainder of this scenario.

u NUREG 1021 42 of 42 Intenm Rev. 8. hauary 1997

l Appenoix D Scenano Outline Form ED-D-2 Op-Test No.: 2 Scenano No.: 4 Event No.: 6 and 7 Page 7 of 10 Event

Description:

"A" OTSG tube rupture (~180 gpm) with a loss of the ES HPl pump.

Time Position Apphcants Actions or Behavior CBOR Determine and report OTSG tube leak rate has increased.

CRS Transition to OTSG Tube Rupture Emergency Operating procedure (1202.006).

CBOT Open BWST Outlet to OP HPl pump (CV-1407 or CV1408).

CBOR/T Reduce or isolate letdown flow NOTE Letdown es isolated at this pomt by closing Letdown Coolers Outlet vatve (CV 12219 CBOT

• nitiate 1 pe ata $ga_r_ftJ.2,as,requireg.-

,. NY ^

vwe a m. . ~ ^

j_ 2 01 y . . ..-.. ~.. .,.~s . . .

m .-.-y;c .. ,

h, .NMa i ., u CBOT When unit is $55% stop Heater Drain Pumps (P8A, B).

CBOT When unit is $50% transfer station auxiliaries to Start Up #1 transformer.

CBOT When unit is $180 Mwe open HP Turbine Drain valves on CO2.

CBOT When unit is $100 Mwe secure reheaters.

NUREG-1021 42 of 42 Intenm Rev. 8, January 1997 t

l

Appendix D Scenano Outline Form ED-D-2 Op-Test No.: 2 Scenano No.: 4 Event No.: 6 and 7 Page 8 of 10 Event

Description:

"A" OTSG tube rupture (-180 gpm) with a loss of the ES HPl pump.

Time Position Applicants Actions or Bahavior CBOR/T Identify and report HPl PUMP MTR WDG TEMP Hi annunciator (K10-E7).

CBOT Determine ES HPl pump is the motor temp that is high by referencing motor winding temperature chart recorder TR6501 on C13.

NOTE lt is poseable for the ES HPl pump to trip before the pump is identified uomo the atmo chart recorder.

CBOT Start the Aux Lube Oil pump for the ES HPl Pump.

NOTE The Es HPI Pump may tnp before the pump to stopped.

CBOT Stop the ES HPl Pump.

NOTE The ES HPl Pump may tnp before the pump is stopped.

CBOR/T Identify and report HPl PUMP TRIP annunciator (K10-A6).

CBOR/T Determine and report the ES HPl Pump has tripped.

ROLE PLAY If directed as Auxiliary Operator to check breaker for ES HPI Pump wait ~3 minutes then report that the breaker has a phase overcurrent relay tripped.

If directed as Waste Control Operator to inspect the ES HPI Pump wait ~3 minutes then report that the motor is extremely hot and has discolored paint neat the electrical connection head.

NUREG-1021 42 of 42 Interim Rev. 8, January 1997

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l Appendix D Scenano Outline Form ED-D-2 Op-Test No.: 2 Scenano No.: 4 Event No.: 6 and 7 Page 9 of 10 Event

Description:

• A* OTSG tube rupture (~180 gpm) with a loss of the ES HPl pump.

Time Position Applicants Actions or Behavior CBOT Initiate HPl using the OP HPl Pump per RT2:3ygg g p j w s w a n;s i W 3d $ dih*b h & ! % ?i d S W W ? % i R NEWW N 5 % 1 M b $g g y$ 5 & ?$ $

LW.,3%T2ArJ31T121203reddhCET4%2%2'*.MWA CBOR When both SG's are on low level limits;

1. Place both Feedwater Demand H/A Stations in HAND

2. Adjust demands to zero

3. Place Diamond Panelin MANUAL

4. Adjust rods to conteof reactor power at 10-12%.

CBOT When reactor power is <12%

1

1. Reduce turbine load to 20-30 Mwe l 2. Check Turbine Bypass valves controlling header pressure 880-920 psig I

3. Verify plant auxiliaries on SU1 CBOT Trip the turbine and perform the fcilowing; e Check throttle and governor valves shut. ,

e Verify Main Generator and Exciter field breakers open.

. Check Turbine Bypass valves operate to control header pressure 880-920 psig.

1 l l CBOR Select "A* OTSG to indicate on header pressure recorder.

! CBOR/T Check PZR Level 200-220". If <200* increase HPl as required to have PZR Level rising.

CBOR Place both Turbine Bypass valve H/A stations in HAND.

CBOR Adjust header pressure setpoint to 45.

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NUREG-1021 42 of 42 Interim Rev. 8, January 1997 l

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Appendix D Scenano Outline Form ED-D-2 Op-Test No.: 2 Scenario No.: 4 Event No.: 6 and 7 Page 10 of 10 Event

Description:

"A" OTSG tube rupture (-180 gpm) with a loss of the ES HPl pump.

Time Position Applicants Actions or Behavior CBOR Trip the reactor and immediately place both Turbine Bypass valve H/A stations in AUTO.

CBOR Verify all rods inserted and reactor power dropping.

CBOR Check Turbine Bypass valves controlling OTSG pressure 950-990 psig.

CBOR Operate PZR heater and spray in hand as required to maintain RCS pressure low within the limits of figure 3.

CBOR/T Stabilize PZR level >55*.

CBOT Select *A* OTSG Nie to GROSS position.

CBOR Place Turbine Bypass valves for the "B" OTSG in hand and adjust to initiate and maintain a cooldown rate of $100*F per hour.

CBOT Place Aux Feedwater Pump (P75) in service.

CBOR Determine and report that *A" OTSG level has failed high.

EVENT AND SCENARIO TERMINATION CRITERIA RCS Cooldown in progress and controlled at 1100*F per hour OR As directed by the lead examiner.

NUREG-1021 42 of 42 Interim Rev. 8. January 1997

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Appendix D Scenario Outline Form ED-D-1 Facility: ANO-1 Scenario No.: &

_ Op-Test No.: N/A

• Examiners: Operators Objectives:

. Evaluate reactor trip immediate actions.

e Evaluate use of ICS Malfunction AOP.

e Evaluate use of Reactor Trip EOP. j

. Evaluate use of ESAS EOP.

l Initial Conditions; e Reactor Protection system failed.

l e P-34A, LPI pump will not auto start on ESAS signal. l Tumover: Unit is operating at 100% steady state, equilibnum renon.

Event Malf. No. Event Event No. Type

• Description I

1 TR589 i Tc Dnfts low over 5 minutes.

I N I 2 RP246 C RPS fails to auto trip. l RP247 R l RP248 M RP249 3 TR626 i *B" CFT level failure.

4 RC005 C LOCA i M

5 HSt417_M C P34A fails to start on ESAS.

\

(

l (N)ormal, (R)eactivity, (f)nstmment, (C)omponent (M)ajor l

• This exam is a replacement for Exam Set #2.

NUREG-1021 41 of 42 Interim Rev. 8. January 1997

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l I

Appendix D Scenario Outline Form ED-D-2 I f Simulator instructions for Scenario #6 Page 2 of 6 )

Event Malf No. Value/ Ramp / Event Description l No. Input Command Delay l IMF RP246 *A* RPS failure to auto trip.

IMF RP247 *B" RPS failure to auto trip.

IMF RP246 *C" RPS failure to auto trip.

IMF RP249 "D" RPS failure to auto trip.

LOR -DO HS1417_WO1 FALSE "A" LPI pump failure to start on ESAS.

LOR -Di HS1417_M TRUE 'A' LPI pump failure to start on ESAS.

~

IMF TR589 520 R300 DO 'A' Loop RCS Tc drifts low.

IMF TR626 "B" Core Flood Tank level indication failure.

IMF RC005 0.2 R60 DO 0.2 ft" LOCA i

I NUREG-1021 42 of 42 Interim Rev. 8. January 1997

f Appendix D Scenano Outline Form ED-D-2 l

l Op-Test No.: STBY Scenano No.: 6 Event No.: 1 Page 3 of 6 Event

Description:

"A" Loop RCS Tc drifts low.

l l Time Position Applicants Actions or Behavior CBOR/T ldentify and report SASS MISMATCH annunciator (K07-B4).

CBOR Determine and report that *A* Loop RCS Tc is low.

CBOR/T Determine and report that (TT1015) is reading low.

1 l CBCR Take manual control of reactor and feedwater to stabilize plant.

CBOR Select attemate Tc instrument for control.

CBOR Retum ICS to auto.

CBOR Retum the unit to 100% power.

EVENT TERMINATION CRITERIA Unit stable at -100% or as directed by lead examiner.

NUREG-1021 42 of 42 Interim Rev. 8, January 1997

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- - - . . ~ . - ~ ~ . . . - - . - ~ . - .

l r Appendix D Scenano Outline Form ED-D-2 l

Op-Test No.: STBY Scenario No.: 6 Event No.: 3 Page 4 of 6 l~ Event

Description:

'B' CFT level failure. ,

Time Position Applicants Actions or Behavior .

CBOR/T Identify and report CFT B LEVEL Hl/LO annunciator (K10-D5).  ;

l CBOT Determine and ieport that one level indicator on the *B* CFT is failed low. j l

I CRS Reference Technical Specifications 3.3.3 and Table 3.5.

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EVENT TERMINATION Instrument failure identified and Tech Specs have been referenced.

l l NUREG-1021 42 of 42 Interim Rev. 8. January 1997 i

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i Appendix D Scenario Outline Form ED-D-2 Op-Test No.: STBY Scenario No.: 6 Event No.: 2,4 and 5 Page 5 of 6 Event

Description:

LOCA with failure of RPS to automatically trip.

Time Position Applicants Actions or Behavior l CREW Determine and report rapid drop in RCS pressure and PZR level.

I NkN

$$$$h?&hf?$h&$$$ bh@ibhh h.hkk l' CREW Perform Reactor Trip Emergency Operating procedure (1202.001) immediate actions.

CBOR Depress the reactor trip push-button. Verify all rods inserted and power dropping.

CBOT Dertess turbine trip push-button and venfy throttle and govemor valves close.

CBOR Reduce letdown by closing Letdown Orifice Bypass valve (CV-1223).

NOTE EsAs actuation ed have occurred at this point and letdown mH be isolated.

CBOR Check SCM adequate.

NOTE sCM wN be not be adequate at this poant.

CRS Transition to ESAS Emergency Operating procedure (1203.010).

CBOT St all runningm.RCp@; ,,jggggy$gyjgggJyggyp;{ gggyF4,gfg-@.

,m e r . . - - . . . . . , . < .. %y

,4  % .m.,., .> .. .

spe w+h

<wp ~t mr+ nt* M~;p:t f kstaztrwegD gm, ~g :>w: &hnneJ~lcrMht&,n p; b:u 14%u.*u A- +- e. a , ,. -: . 4 &44sgw yww w. a l

l NUREG-1021 42 of 42 Intenm Rev. 8. January 1997

l Appendix D Scenano Outline Form ED-D-2 Op-Test No.: STBY Scenano No.: 6 Event No.: 2,4 and 5 Page 6 of 6 Event Desenption: LOCA with failure of RPS to automatically trip.

Time Position Applicants Actions or Behavior CBOT Verify proper ES Actuation per RT10 CBOR/T Determine and report "A* LPI Pump (P34A) failed to start.

CBOT E **2 P usin t=n"' ' ' ' A%

• Ja,d%g harm

• 55g n%WW F+. e n a s=:Vk "~i.

w%m w :2 m w w :.t w :.1 w n = :: s 2 1 CBOT Maximize RB Cooling per RT9.

EVENT AND SCENARIO TERMINATION CRITERIA ES actuation verified and RCS pressure stable.

OR As directed by lead examiner NUREG-1021 42 of 42 Intenm Rev. 8. January 1997

i JOB PERFORMANCE MEASURE Page 1 of 6 "JIIT : 1 REV #: 1 DATE:

.OI NUMBER: ANO-1-JPM-RO-AOP21 SYSTEM: Emergency and Abnormal Operations L TASK: Align Auxiliary Spray To DH System During a Forced Flow Cooldown.

'JTA: 10055340101 KA VALUE RO: 4.4 SRO: 4.4 KA

REFERENCE:

006 A4.07 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR: OUTSIDE CR: X BOTH:

' SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE) :

PLANT SITE: Simulate SIMULATOR: LAB POSZTION EVALUATED: RO: SRO:

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT 3ITE: LAB:

TESTING METHOD: SIMULATE: PERFORM:

APPROXIMATE COMPLETION TIME IN MINUTES: 20 minutes REFERENCE (S): 1203.040 Rev. 3, 1104.004 Rev. 63 PCI EXAMINEE'S NAME: SSN: - -

EVALUATOR'S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY: UNSATISFACTORY:

' PERFORMANCE' CHECKLIST COMMENTS:

Start Time Stop Time Total Time SIGNED DATE:

SIGNATURE INDICATES THIS JPM MAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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JOB PERFORMANCE MEASURE Page 2 of 6

• ME EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

..le examiner shall review the " Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.

-JPM INITIAL TASK CONDITIONS: A Forced Flow Cooldown is being performed due to excess RCS leakage. RB Spray is not operating. CV-1416 supply breaker is closed and CV-1416 is closed.

TASK STANDARD: Pressurizer auxiliary spray has been aligned to the "A" LPI system.

TASK PERPORMANCE AIDS: AOP 1203.040 step 3.11.2, OP 1104.004 section 23.

JOB PERFORMANCE MEASURE Page 3 of 6

"*ITIATING CUE:

.no CRS directs you to align Pressurizer AUX Spray to "A" LPI system per step 3.11.2 of AOP 1203.040.

CRITICAL ELEMENTS (C): 2, 4, 5, 6 (C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT TRANSITION NOTE: The examinee should proceed to the 360' elevation of the Auxiliary Building (Upper North Piping ?enetration Room).

1. Verify HP Pressurizer Verified MU-64 c1csed AUX Spray Isolation by verifying valve MU-64 closed, stem down no threads showing.

POSITIVE CUE:

MU-64 is closed.

(C) 2. Open P-34A Supply to Opened DH-4A and DH-MU Prefilter and PZR SA using handwheel.

AUX Spray, DH-5A and DH-4A.

POSITIVE CUE .

DH-4A and DH-SA are open.

3. Verify P-34B Supply Verified DH-4B and to MU Prefilter and DH-5B closed by PZR AUX Spray, DH-4B verifying valve stem and DH-5B closed. down.

POSITIVE CUE:

DH-4B and DH-5B are closed.

TRANSITION NOTE: The examinee should proceed to the "A" Decay Heat vault.

(C) 4. Open Pressurizer AUX Opened DH-94 using Spray Isolation, DH- handwheel.

94.

POSITIVE CUE:

DH-94 1s open.

EXAMINERS NOTE:

Steps 7.and 8 may be accomplished at this point prior to leavino the 317' elevation.

TRANSITION NOTE:

The examinee should proceed to the Upper North Piping Penetration Room on the 360' elevation of the Auxiliary Building.

(C) 5. Unlock and open DH to Unlocked and opened PZR AUX Spray Valve, DH-15 using DH-lf. handwheel, POSITIVE CUE:

l DH-15 is unlocked and open.

(C) 6. Open Pressurizer AUX Opened DH-63 using Spray Valve, DH-63. handwheel.

POSITIVE CUE:

Auxiliary Spray is aligned to "A" LPI system.

NEGATIVE CUE:

, Auxiliary Spray is not

alioned to "A" LPI system.

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JOB PERFORMANCE MEASURE Page 4 of 6 1

1

). PERFORMANCE CHECKLIST STA!!DARD  !!/A SAT UNSAT i

7. Verify DH Room verified ABS-13 and Drains, ABS-13 and. ABS-14 handles in ABS-14, closed. closed position. l

)

POSITIVE CUE:

ABS-13 and ABS-14 are closed. i

8. Verify DH Room Verified DH Room '

watertight doors are watertight doors I closed. closed.

POSITIVE CUE: l DH Room watertight doors  !

are closed. '

EXAMINERS NOTE:

Stcp 10 may be performed at this point prior to leaving the Auxiliary Building.

TRANSITION NOTE:

Th2 axaminee should proceed to the ventilation room 404' elevation.

9. Close DH Room Purge Closed DH room Purge Dampers. Dampers by placing the switch located on POSITIVE CUE: C-143 to the DAMPERS IA-7635 and IA-6636 are in CLOSED position. (C-DAMPERS CLOSED position. 143 is located in the 404' el. ventilation NEGATIVE CUE: room east wall).

Decay Heat Rooms are not isolated.

TRANSITION NOTE:

Tho examinee should proceed to the Lower North Piping Room 335' elevation of the Auxiliary j Building.

10. Open RCP Seal ' 0%:ned MU-41 using Injection Filter handwheel.

Bypass, MU-41.

l POSITIVE CUE: i L MU-41 is open. l

'I NEGATIVE CUE:

l MU-41 is closed.

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END i e

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JOB PERFORMANCE MEASURE l Page 5 of 6 l l

PA: 306 KS.04 2.9/3.1 '

.sstion 1: What temperature limitations are placed on the use of Aux Spray?

Answar: Aux Spray temperature limitations are only imposed when the HPI pumps are l being aligned to Aux Spray and the DT is >430*F. Due to the low temperatures at which DH is placed in service (RCS <280*F) the potential of brittle fracture of the spray nozzle (and violation of T.S.) is very low.

RJf: 1104.002, Rev. 50, page 11 1203.013, Rev. 15, page 7&B  !

T.S. 3.1.2.5, i

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i PnocJWasix puw No. Pnnrw-sevoput Puw Tm.E:

• I PAGE: 11 of 230 1104.002 MAKEUP & PURIFICATION SYSTEM OPERATION REV: 50 CHANGE:

5.18.2 Ensure Pressurizer Spray Isolation (CV-1009) is fully closed prior to initiation of high pressure auxiliary spray. This will prevent partial aux. spray flow into the i

normal spray line and RCS cold leg, which would otherwise cause an unevaluated thermal stress.

5.18.3 Severe water hammer may occur when high pressure aux, spray is initiated. The operator shall ensure spray is cut in slowly to minimize the possibility of water hammer.

5.18.4 Due to the limited flow between the PZR and RCS while on high pressure aux. spray, boron addition will tend to concentrate in the RCS rather than uniforndy mix in PZR and l' RCS. Sampling of RCS and PZR water space will be necessary to determine total boron concentration.

5.18.5 once high pressure aux. spray has been initiated, flow l should not be secured completely due to thermal stress.

! PZR heaters may be used to counter the effect of the spray.

1 5.19 Modulating valves may indicate full closed, yet not be fully torqued closed, thereby allowing leakage past the valve.

, 5.20 At RCS pressures >150 psig, opening the following valves i

simultaneously could result in exceeding Letdown Relief VLV (PSV-1236) capacity and overpressurizing letdown system piping.

Letdown Orifice Block (CV-1222) l

'

• Letdown Orifice Bypass (CV-1223)

• Letdown Block Orifice Manual Bypass (MU-4)

.. . If the flow is stopped downstream of the makeup tank (T-4) with maximum letdown flow, the makeup tank will be overpressurized in approximately 5 minutes.

Maximum allowaole flow tnrough the seal injecticn filter 'F-2) is c; ;pm.

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• umoer of alloweo successive starts with motor initially at amolent emperature is 2 starts. Numoer of allowed successive starts with motor initially at rated temperature is 1 start.

.. '4 Oue to the close tolerances in the makeup /HPI pumps (P-36A/B/C),

peration for even a few seconds with their respective suction valve Cosed will result in damage to the pump, t.25 Operation of makeup pumpts: with suction aligned from makeup tank

'T-4) only, and all inlets to T-4 isolated, will lead to vacuum being

awn in T-4 wnlen will result in mar.eup pump damage.

2E Ohe Aux Lube Oil Pump should not be run for more than 5 seconds on a running MU Pump to

ninimize cil loss.

l PROC / WORK PLAN NO. I PROCEDURE / WORK PLAN P 8: MGE: 7 Cf 23 1 1203.013 NATURAL CIRCULATION COOLDOWN REV: 15 CHANGE:

i l

NOTE ,

1. During a natural circulation cooldown practically no flow exists in the l head region. Fluid temp will r==mi n near that RCS temp when RCPs were secured and will drop following ambient losses. This ambient cooldown rate will be ~5*F/hr.

2. RV Head steam bubble formation would be indicated by RV level indicators on ICCMDS display, rapid rise in PZR level while depressurazing, or rapid drop in PER level while pressurizing.

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3. If a steam bubble is indicated in the RV Head, cooldown rate shall be re'duced to $50*F/hr, unless SCH is less than adequate.

4. M RCS press is maintained within limits of Attachment A, and cooldown rate is maintained $50*F/hr, RV Head steam bubble formation should not prevent depressurization and cooldown to DMR operations.

3.11 f I_f, indication of RV Head steam bubble occurs, perform the following:

3.11.1 Unless directed otherwise by Ops Manager, terminate .

depres surization , then pressurize slightly to reduce the l size of the bubble and ensure continued natural circulation.

3.11.2 Proceed with cooldown and depressurization at $50*/hr, unless SCH is less than adequate.

3.11.3 Repeat bubble-reducing maneuver to minimize voiding.

3.1 Control RCS press during cooldown by one or more of the following:

CAUTION l

.. Jse rf hign pressure AUX spray wnen Pressurl:er Spray Isolation (CV-1009) rann:t =e :lesec can result in thermal shock of the spray line connection

.. tne :0_: J.eg pipe.

2. Use Of spray wnen temp difference between FZR and spray fluid is >430*F violates TS 3.1.:.5 ano mus: be evaluated crior to restart. i NOTE

1. Per 10CFR50.54 (x), reasonable action that departs from a Technical Spec;ft:ation may ce taken in an emergency when this action is immediately neeoed to protect the public health and safety and no action consistent with tecnnical specif1:ations that can provide acequate or equivalent protection is immeciately apparent. (y) Such action shall be approved by an SRO prior to taking the action. This action is reportable within one hour uncer 10CFR50.72 (b) (1) (1) (B) , " Deviation from Teen Specs authorized per 10CFR50.54(x)."

2. fiers are in order ef creference and deoend en availability.

3.;; ; ;y:;e EEV as necessary to centrcl RCS press.

PROCJWORM PLAN NO. l PR"CEDUREMORK PLAN Tm.E.

PAGE: 8 Cf 23 !

1203.013 NATURAL CIRCULATION COOLDOWN m: 15 CHANGE:

3.12.2 Turn off PZR heaters, then surge in and out of PZR between 60" and 200" to control RCS press.

3.12.3 Use Pressurizer AUX Spray as follows:

A. Calculate PZR/ spray fluid AT (PZR temp minus BWST templ:

1. PZR Temp (C04)

2. BWST T-3 Temp (C14)

3. AT =

B. When PZR/ spray fluid AT is <430*F or depressurization is needed to protect the public safety and no other actions consistent with Tech Specs are adequate, use Pressurizer AUX Spray (CV-1416) to control RCS press as follows:

1. If PZR/ spray fluid AT is >430*F, obtain SRO approval prior to using PZR AUX spray.

2. Verify Pressurizer Spray Isolation (CV-1009) closed,

a. If CV-1009 cannot be closed, do not use PZR AUX spray.

3. Collect the following data in rough log for each on-off cycle of AUX spray:

• PZR Temp (C04).

= BWST T-3 Temp (C141.

• RCS press.

e Time of CV-1416 opening and closing.

= Valve position (full open, opened for 4 sec, etc.).

4. Unlock and close power supply breaker (B-5531) for CV-1416.

5. Open High Pressure PZR AUX Spra) Isol (MU-f4).

6. Minimize water hammer; slowly introduce spray into PZR by slightly opening CV-1416,

7. Pegulate CV-1416 position so spray flow is cont nuous; avoid closing and reopen):'g.

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3.1.2 Pressurizatien. Heatun. spd Cooldown Limitations Soecification 3.1.2.1 Hydro Tests For thermal steady state system hydro tests, the system may be pressurized to the limits set forth in Specification 2.2 when there are fuel assemblies in the core, under the provisions of 3.1.2.3, and to ASME Code limits when no fuel assemblies are present provided the reactor coolant system limits are to the right of and below the limit line in Figure 3.1.2-1. The provisions of Specifications 3.0.3 are not applicable.

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3.1.2.2 Leak Tests Leak tests required by Specification 4.3 shall be conducted under l the provision of 3.1.2.3. The provisions of Specification 3.0.3 are j not applicable. I l

3.1.2.3 The reactor coolant pressure and the system heatup and l cooldown rates (with the exception of the pressurizer) shall be l limited in accordance with Figure 3.1.2-2 and Figure 3.1.2-3, and f are as follows:

Heatup:

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Allowable combinations of pressure and temperature shall be to the right of and below the limit line in Figure 3.1.2-2. The heatup rates shall not exceed those shown in Figure 3.1.2-2.

Cooldown:

Allowable combinations of pressure and temperature for a specific cooldown shall be to the right of and below the limit line in Figure 3.1.2-3. Cooldown rates shall not exceed those shown in Figure 3.1.2-3.

3.1.2.4 The secondary side of the steam generator shall not be i pressurized above 200 psig if the temperature of the steam generator shell is below 100F.

l 3.1.2.5 The pressurizer heatup and cooldown rates shall not exceed 100F/hr. The spray shall not be used if the temperature l

l difference between the pressurizer and the spray fluid is greater than 430F.

3.1.2.6 With the limits of Specifications 3.1.2.3 or 3.1.2.4 or 3.1.2.5 exceeded, restore the temperature and/or pressure to

within the limit within 30 minutes; perform an engineering evaluation to determine the effects of the out-of-limit condition on the fracture toughness properties of .e Reactor Coolant System; determine that the Reactor Coolant System remains acceptable for continued operations or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and reduce the RCS Tavg to less than 200F, while maintaining RCS temperature and pressure below the curve, within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

Amendment No. 22, 27, 37, 154, 161 18

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JOB PERFORMANCE MEASURE Page 6 of 6 VA: 006 Kl.04 2.7/2.8

.sation 3: Why can' t Aux Spray be used 11 the normal Pzr Spray isolation, CV-1009, can NOT be closed? i j

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An0 war: With CV-1009 open, part of the Aux Spray would flow back down into the normal spray line. This would caus= unevaluated thermal stresses on the normal spray piping.

i R]forence: 1104.002, Rev. 50 page 11.

1203.013, Rev. 15 page 7.

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CJWORK PLAN NO. '

Am4 WORK PUWd TME'

• Pl.GF: 11 Of 230 i 1104.002 MAKEUP & PURIFICATION GYSTEM OPERAT10N REV: 50 )

CHANGE:

5.19.2 Ensure Pressurl:er Spray Isolation (CV-1009) is fully closed prior to initiation of high pressure auxiliary spray. This will prevent partial aux. spray flow into the noonal spray line and RCS cold leg, which would otherwise cause an unevaluated thermal stress.

5.18.3 Severe water hammer may occur when high pressure aux. spray l 1s initiated. The operator shall ensure spray is cut in I slowly to minimi:e the possibility of water hammer. l 5.18.4 Due to the limited flow between the PZR and RCS while on high pressure aux. spray, boron addition will tend to f concentrate in the RCS rather than uniforndy mix in PZR and 1 RCS. Sampling of RCS and PZR water space will be necessary ,

to determine total boron concentration. l 5.18.5 Once high pressure aux. spray has been initiated, flow should not be secured completely due to thermal stress. '

PZR heaters may be used to counter the effect of the spray.  ;

5.19 Modulating valves may indicate full closed, yet not be fully torqued l closed, thereby allowing leakage past the valve. '

l 5.20 At RCS pressures >150 psig, opening the following valves simultaneously could result in exceeding Letdown Relief VLV (PSV-1236) capacity and overpressuri:ing letdown system piping.

• Letdown Orifice Block (CV-1222)

• Letdown Orlfice Bypass (CV-1223)

• Letdown Block Orifice Manual Bypass (MU-4)

.2. If the flow is stopped downstream of the makeup tank (T-4) with maximum letdown flow, the makeup tank will be overpressurl:ed in approximately 5 minutes.

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"sximum allowaole flow tnrouch the seal in]ecti:n filter F-2; 1s l

c.- gpm.

... ;unmer of allowec successive starts witn motor initially at amotent temperature is 2 starts. Nummer of allowed successive starts with motor initially at raten temperature is 1 start.

. 14 ue to the close tolerances in the makeup /HPI pumps (P-36A/B/C),

peration for even a few seconds with their respective suction valve

losed 111 result in damage to the pump.

i.*E Operation of makeup pumpts: with suction aligned from makeup tank l T-4) only, and all inlets to T-4 isolated, will lead to vacuum being crawn in T-4 wnlen will result in maxeup pump camage.

l . 26 The Aux Lube Oil Pump should not be run for more than 5 seconcs on a I

running MU Pump to min 1=c:e cil loss.

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ftOC/ WORK PLAN NO. ( PROCEDURE / WORK PLAN TTT12.; PAGE.: 7 of 23 REV: 95 1203.013 ft!ATURAL CIRCULATION COOLDOWN CHANGE:

NOTE

1. During a natural circulation cooldown practically no flow exists in the head region. Fluid tesp will remain near that RCS tesp when RCPs were secured and will drop following ambient losses. This aadstent cooldown rate will be ~5*F/hr.

2. RV Head steam bubble formation would be indicated by RV level indicators on ICCHDS display, rapid rise in PZR level while depressurizing, or rapid drop in PER level while pressurazing.

3. E a steam bubble is indicated in the RV Head, cooldown rate shall be reduced to $50*F/hr, unless SCM is less than adequate.

4. M RCS press is maintained within limits of At+=ah==at A, and cooldown rate is maintained $50*F/hr, RV Head steam bubble formation should not

, prevent depressurization and cooldown to DER operations.

3.11 M indication of RV Head steam bubble occurs, perform the following:

3.11.1 Unless directed otherwise by Ops Manager, terminate depressurization, then pressurize slightly to reduce the

' size of the bubble and ensure continued natural circulation.

3.11.2 Proceed with cooldown and depressurization at $50*/hr, unless SCM is less than adequate.

3.11.3 Repeat bubble-reducing maneuver to minimize voiding.

3.1 Control RCS press curing cooldown by one or more of the following:

CAUTION

.. J:e cf n ;n pressure AUX spray wnen Pressurizer Spray Isolata:n ;;V-1009)

annet ce :_:sec can result in thermai shock of tne spray .ine ::nnect :n

:ne ::_: _eg pipe.

2. Jse c: spray wnen temp cifference between P:R anc spray fluic is >430*F 1:01ates TE 3.1.2.5 anc must be evaluated crier to restart.

NOTE

' . . Per 10CTR50.54 (x), reasonable action that departs from a Technical Specif::ati:n may oe taken in an emergency when this action is immeciately neecec to protect the public health and safety and no action consistent witn tecnnical specifications that can provide acequate or equivalent protect :n is immeciately apparent. (y) Such action shall be approvec by an SRO pr : to taking the action. This action is reportable within ene hour un=er 10CFR50.72 (bl (1) (1) (B), " Deviation from Teen Specs author::ed I -cer .;;T?5C.54(x)."

2. 2:ees are in orcer of ::eference an= ceoenc en availability.

1.12.1 Cy:le EF'! as necessary : centrol FCS press.

i JOB PERFORMANCE MEASURE l Page 1 of 5 i UNIT: 1 REV #: 6 DATE:

TUOI NUMBER: ANO-1-JPM-RO-EWO2 'I SYSTEM: Emergency Feedwater TASK: Manually control P7A at the Turbine <

JTA: 10615110401 '

KA VALUE RO: 3.1 SRO: 3.4 KA

REFERENCE:

061 A2.05 APPROVED FOR ADMINISTRATION TO: 'RO: X SRO: X TASK LOCATION: INSIDE CR: OUTSIDE CR: BOTH: X l

SUGGESTED TESTING ENVIRONMENT AND METHOD'(PERFORM OR SIMULATE): )

PLANT SITE: Simulate SIMULATOR ' LAB

{

POSITION EVALUATED: RO: SRO:

}

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB TESTING METHOD: SIMULATE: PERFORM: }

APPROXIMATE COMPLETION TIME IN HINUTES: 5 Minutes REFERENCE (S): OP1106.006, Rev. 58, Section 13 or Exhibit C i

l EXAMINEE'S NAME: SSN: __ - -

EVALUATOR'S NAME:

THE. EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

l l

Start Time Stop Time Total Time i l' l 1

SIGNED DATE: '

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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JOB PERFORMANCE MEASURE t Page 2 of 5 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

The examiner shall review the " Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.

JPW INITIAL TASK CONDITIONS: P7A turbine was tripped and has been reset per Exhibit A, CV-2613/SV-2613 and CV-2663/SV-2663 are closed, no DC power en  !

turbine control cabinet.

TASK STANDARD: P7A runnino at -1400 psio discharoe pressure beino controlled usino T/T valve CV-6601A.

TASK PERFOpedhMG AIDS: Copy of Procedure OP1106.006 Exhibit C, calculator for JPM ouestion.  ;

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J011 PERFOR51ANCE MEASURE Page 3 of 5 INITIATING CUE:

The SS/CRS directs that you manually start P7A and control at approximately 1400 psig discharge pressure.

CRITICAL EI.I3ENTS (C) : 1, 3 PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSA T

(C) 1. Close K3 trip / Closed CV-6601A is by throttle valve (CV- rotating hand wheel in 6601A) closed. close direction.

POSITIVE CUE:

Handwheel does NOT move any further valve is

~

closed.

2. Request control Called control room room to open K3 and requested CV-2613 steam valve (CV- or CV-2663 to be 2613 or CV-2663). opened.

POSITIVE CUE:

Control Room reports valve is open.

(C) 3. Open K3 trip / Slowly opened CV-6601A throttle valve (CV- turbine until 6601A). approximately 1400 PSI discharge pressure was POSITIVE CUE: a ttair.ed .

Pump discharge pressure is approximately 1400 PSI.

NEGATIVE CUE:

Pump discharge pressure is approximately 500 psi.

4. Monitor turbine Checked turbine speed speed indication at the local control (if available) to cabinet and ensured ensure turbine speed less than 3776 does not exceed RPM or monitored pu:rp 3776 RPM or pump discharge pressure discharge pressure indication and at -1400 psig. maintained at-1400 psig.

POSITIVE CUE:

Turbine speed is less than 3776 RPM or pump discharge pressure 1400 psig.

DID

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JOB PERFORNIANCE SIEASURE Page 4 of 5 K/A: 061 A1.02 3.3/3.6 Question 1: Is there a problem with EFW actuating at low OTSG pressures?

Answer: Yes, due to the possiblity of flow oscillations at low OTSG pressures, P7A speed is controlled and EEW control valves are throttled if flow oscillations occur.

Reference:

1203.044, Rev. 1 page 1 and 2

^

PROCJWORK PLAN NO. PROCEDUREfWORK PLAN TITLE: PA:E: 1 of 2 1203.044 EFW ACTUATION WITH LOW OTSG PRESSURE REV: 1 j CHANGE:

C'J d3 TION Il entry into Emergency Operating Procecure series (1202.XXXI is required, tnis procecure coes not apply; EOP instructions take prececence.

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l 1.0 SYMPTOMS 1.1 Either of the following conditions, with OTSG pressures below Hot l Shutdown conditions (<900 psig): ,

i 1.1.1 EFW feed is required due to:

• Loss of Decay Heat removal system j

• Loss of OTSG feed j

• Loss of all RCPs 1.1.2 Any automatic EFW actuation l 1

2.0 IMMEDIATE ACTION l 2.1 If an automatic EFW actuation and EFW flow oscillations occur, perform j the following: >

2.1.1 Place affected EFW Control valves (CV-2647, CV- 2 64 8,-

CV-2645 and CV-2646) in HAND.

2.1.2 Close EFW Control valves as needed to stop oscillations in flow and throttle as needed to provide necessary flow to OTSGs.

j 3.0 FOLLOW-UP ACTIONS 3.1 If manual EFW is required, perform the following:

3.1.1 Verify all 4 EFW Isol valves (CV-2620, CV-2626, CV-2627 and CV-26'04 cpen.

3.1.2 Place all 4 EFW Control valves (CV-2647, CV-2648, CV-2645 and CV-2646) in HAND and close.  !

3.1 3 Start Emergency Feedwater Pump (P-7B). I 3.1.4 If RCS temperature >280"F, and if needed, start Emergency Feedwater Pump (P-7A) as follows:

A. Open or verify open P-7A Steam Supply Valves (CV-2617 and CV-2667).

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l B. Open P-7A Steam Admissien Valves (CV-2613 and l CV-2663).

C. Control F-7A speed as necessary for stable operation by ad3ustment of P-7A Speed Control EFW Pump HIC-6601).

PROCJWORK PLAN NO. PROCEDURE / WORK PLAN TITLE: PAGE: 2 cf 2 1203.044 EFW ACTUATION WITH LOW OTSG PRESSURE REV: 1 l CHANGE:

3.1.5 Throttie En control valves as neeceo to prevent flow oscillations and to provice the necessary flow to the OTSGs.

3.2' When E W is no longer needed, return system to normal per " Returning EFIC System and E N Components to Normal Automatic Condition" section of OP 1105.005.

4.0 REFERENCES

4.1 EAR 92-625' Steam Driven EW Pump Performance Evaluation with Low Steam Supply Pressure.

Discussion

.The EN system is susceptible to flow oscillations at low OTSG pressures, <150 psig, and high EFW flows, 400 to 500 gpm. Taking manual control of the E W flow control valves and lowering flow <-400 gpm will stabilize the flow oscillations. This procedure also provides guidance necessary to manually start E W at low OTSG

. pressure. During this time initiation signals are bypassed (Loss of RCP's, etc.).

The provided guidance starts the EFW system in a controlled manner.

P-7A operation with low steam supply pressure is verified periodically by testing at RCS. temperatures < 280 degrees F. (steam supply pressure <35 psig) . Typical data taken during testing in this condition yields P-7A discharge pressure ~110 pstg, flow -250 gpm and P-7A speed of -1100 RPM.

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I JOB PERFORMANCE MEASURE l K/A: 061 K5.01 3.6/3.9 I

Question 2: On an automatic actuation due to loss of all RCP's, how does the Em system respond to compensate for its ability to rapidly remove heat from the RCS7 (Ifow does it prevent overcooling?)

Answer: The fill rate of EW will be adjusted based on OTSG pressure. The fill rate is at a minimum of 2"/ minute with an OTSG pressure of 800 psig and increases linearly to a maximum of 8"/ minute when OTSG pressure is 1050 psig.

Reference:

STM l-66 Rev. 5 page 14 1106.006, Rev. 58 page 10 and 14 1

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-Em:IrgIncy Focdwntsr Initintien And Central STM 1-66 RIv. 5 driven EFW pump (P7A) to each steam generator. (CV-2645 to the A OTSG, CV-2647 to the B OTSG)

One of the control modules provides control of the Atmospheric Dump Valve associated with each channel. Train A controls CV-2668, ADV on the A OTSG, and Train B controls CV-2618, ADV on the B OTSG. Normally the ADV Block Valves are closed and are auto opened only on an MSLI actuation for the affected OTSG or a Condensor Low Vacuum. ADV pressure control is acuve at all times set to control at 1020 psig OTSG pressure.

De EFW flow control valves, during normal operation, are biased fully open. Upon an EFW actuation, the vector enable signal removes the open bias signal from the flow control valves and they are modulated to control OTSG level. OTSG level is automatically controlled at three level setpoints.

31" low range level with RCPs runmng (forced flow).

312" full range level when no RCPs are runmns (natural circulation), operator selected on C09.

378" full range level when no RCPs runmng and operator selects reflux boiling setpoint on C09.

If an EFW actuation occurs a.md the "all RCP's tripped" condition exists, since the level setpoint is 312" or 378" (as selected by the operator), steam generator level will be raised significantly from the post trip OTSG level. To limit the cooling effect raising level would have, the the full range level signal is compared to a rate limited setpoint that is based on OTSG pressure. His provides a fill rate as detenmned by the following graph.

. 1 8-Fill Rate

" / min 2

i i 800 1050 OTSG PRESSURE 2.2 Detailed Component Description 2.2.1 Control Room The Emergency Feedwater Initiation and Control System as Cabinets shown m Figure 66 05 consists of four channels (A. B. C, and D).

All cabinets have front and rear access doors. The front doors have a

~

transparent panel to allow surveillance of the status indicators.

Nameplates are used to identify cabinets. module types. and function.

14

PROCJWORK PLAN NO, PROCEDURE / WORK PLAN TITLE: PAGE: 10 of 155 1106.006 EMERGENCY FEEDWATER PUMP OPERATION REV: 58 ~

CHANGE.

6.7 P-7B TRIP / AUTO START FAILURE: alarms upon re.:eipt of the two following signals:

, A. P-7B auto start signal and

• B. Breaker (A-311) for P-7B open for ~50 seconds.

6.8 P-7A Turbine K3 Speed Control 3650 RPM 6.9 P-7A Turbine K3 Overspeed Trip 4255 RPM 6.10 EFW Pump Turb. Exhaust Rupture Disc 25 PSIG 7.0 Normal (Automatic) Operatien 7.1 Initial Conditions 7.1.1 Valve lineup in accordance with Attachment "A".

7.1.2 EFW CST (T-41B) level >27.8 ft. (267,000 gal.) if both units are aligned to T-41B; and >11.1 ft. (107,000 gal.) if Unit 1 only is aligned to T-41B.

NOTE P-7B has a 20-second. time delay on auto start.

4.3.m 7.2 To verify proper operation of P-7A and P-73 after an AUTO start, check the following:

7.2.1 Verify P-7A and P-75 discharge pressures 2 SG PRESS.

NOTE On loss of RC pumps, level increase will be at a controlled rate from 2 to 8 inches per minute depending on steam generator e ussure.

7.2.2 Verify emergency feed flow indicated to SG's and SG levels increasing toward or being controlled at one of the following levels:

A. E any RCP is on, 20" to 40" B. E all RCPs are off, 300" to 340" C. H Reflux Boiling selected, 370" to 410" NOTE EFW pump bearing oil level should be checked soon after auto start.

7.2.3 Verify proper ErW pump bearing oil levels.

7.2.4 If manual control is required, refer to " Manual Intervention to Control EI1t" section.

PROC / WORK PLAN NO. PROCEDURENbm Pt.AN TITLE: t' AGE: 14 Cf 155 1106.006 EMERGENCY FEEDWATER PUMP OPERATION REV: $8 CHANGE:

9.5 P-7A turbine speed may be reduced, if necessary, to maintain better flow control by adjusting E W P-7A Speed Centrol on C09.

9.6 Upon P-7A step, notify Nuclear Chemistry and perform the following:

• Provide start and stop time of release. PPAS computer point "EFWOl" can be checked to aid in determination of release start and stop time.

• Request initiation of Form 1604.015B.

(4.lu) 10.0 Hanual Initiation of Emergency Feed CAUTION -

EN Control valves are full open in the absence of a vector enable signal.

Starting an EM pump without an EM initiate signal will result in full EN flow.

NOTE Depressing both E M pushbuttons on Train A Matrix on C09 will start both E N Pumps (P-7A and P-7B). Depressing both EFW pushbuttons on Train B Matrix will start only P-7A.

10.1 To manually initiate E N , depress both EFW pushbuttons on either Train A Matrix or Train B Matrix on C09.

10.1.1 g EFW flow control valves are in HAND, verify control valves automatically switch to auto on initiate signal.

A. EFW P-7A to SG-B CNTRL (CV-2647)

B. EFW P-7B to SG-B CNTRL (CV-2648)

C. E N P-7A to SG-A CNTRL (CV-2645)

D. ETW P-7B to SG-A CNTRL (CV-2646) l NOTE If all RC pumps are off, the rate of level increase will be from 2 to B inches per minute, depending on steam generator pressure. j 10.1.2 Verify steam generator level control increases level to the following and maintains level:

A. g any RCP is on, 20" to 40" B. If all RCPs are off, 300" to 340" C. g Reflux Boiling selected, 370" to 410" 10.1.3 g subcooling margin is lost and RC pumps are tripped, select SG high level control reflux boiling setpoint (378")

by depressing the Train A and Train B REFLUX BOILING pushbuttons on C09.

. -. . . . - - - - - _ . . - - . . . . _ _ . . , - - .. . . - . . - - . . . . . . . . .. .~ - .

JOB PERFORMANCE MEASURE IT 1: X REV #2 9 DATE:

M I WUMBER:. ANO-1-JPM-RO-ED012 SYSTEM: Electrical System Operatiens .

. TACK: Startup Y-11 Inverter with 1 cad on the alternate source l

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JTA: 10625120101 KA VALUE RO: 3.1 SRO: _3.1 KA

REFERENCE:

062 A4.07 1 l

APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR: OUTSIDE CR: X BOTH:

1 SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

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PLANT SITE: Simulate SIMULATOR: LAB:

POSIT 80N EVALUATED: RO: ' SRO:

' ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB: '

TESTING METHOD ' ' SIMULATE: PERFORM APPROXIMATE COMPLETION TIPE IN MINUTES: 12 minutes REFERENCE (S) . OP 1107.003, Rev. 8 PC-3 EXAMINEE'S NAME: SSN: - -

1 EVALUATOR'S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN

'THIS.JPM AND IS DETERMINED TO BE:

SATISFACTORY:- UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

Start Time Stop Time Total Time SIGHED' DATE:

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEEl'AND IS CURRENT WITH THAT REVISION.

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JOB PERFORMANCE MEASURE Page 2 of 8 EXAMINER SHALL REVIEW THE FOLLOWIllG WITH THE EXAMIllEE:

The examiner shall review the " Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.

JPM~ INITIAL TASK CONDITIONS:_ Inverter Y11 is shut down. The Inverter manual switch is in the " Alternate Source to Load" position. RS-1 is being supplied from Y-11 citornate source.

TASK STANDARD: " Inverter Supplying Load" light on. " Alternate Source Supplying Load" light out. Manual switch in " Inverter to Load" position.

TASX PERFORMANCE AIDS: Copy of OP 1107.003, Section 8.3 1

1 JOB PERFORMANCE MEASURE  ;

Page 3 of 8

'IATING CUE:

The SS/CRS directs that you startup and place inverter Y-11 in service.  ;

I CRITICAL ELEMENTS (C): 9, 12, 14, 16  !

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PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT 1 Verify DC Input Verified DC Input j Breaker open, breaker on inverter l' open POSITIVE CUE: l Bkr. open.

2 Verify Inverter Verified inverter i Output Breaker output breaker is l open, open. j i

POSITIVE CUE:

Inverter output ,

breaker open.

]

3. Verify Alternate Verified Alternate l Source AC input source AC input )

l breaker closed. breaker closed.  ;

1 POSITIVE CUE: I Alternate Source AC input closed. I

4. Verify Y-11 Verified Y-11 Manual Manual selector selector switch (HS-switch (HS-1122) 1122) in the in the Alternate Alternate Source To Source To Load Load position.

position.

POSITIVE CUE:

Y-11 Manual selector

switch is in the l Alternate Source To i Load position.

5. Verify RS1 Verified RS1 Transfer Transfer switch switch (HS-1123) at  !

(HS-1123) in Y- the' top of Y-11 in 11 to RS-1 the Y-11 to RS-1 L position. position.

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l POSITIVE CUE:

! RS-1 Transler switch L is in Y-11 to RS-1 position.

TRANSITION NOTE: The examinee should proceed to the South Electrical Equipment Room (behind the orange door).

6. Verify Y-11 At B-51 verified B-l breaker B-5141A 5141A closed by closed. observing breaker handswitch in the POSITIVE CUE: closed position.

Breaker B-5141A is closed.

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i JOB PERFORMANCE MEASURE Page 4 of 8 e l PERFORMANCE CHECKLIST j STANDARDS j N/A { SAT l UNSAT l

_IRANSITION NOTE:

The examinee should proceed from the South Electrical Equipment Room (behind the orange door) to th2 D01 bus. I

7. Verify DC Supply AT D01 verified DC  ;

feeder breaker Supply feeder breaker i D01-22A closed. D01-22A handle in the l closed position.

POSITIVE CUE:

D01-22A CLOSED.  !

NEGATIVE CUE: -

D01-22A open.  :

8. Verify battery verified battery D07 j D07 disconnect disconnect D-13 D-13 closed. closed.

POSITIVE CUE:

Battery D07 disconnect is closed. -

(C) 9. Close the DC On the inverter, Input Bkr. placed the DC Input breaker handle in the POSITIVE CUE: closed position. I DC Input breaker closed.

5 NEGATIVE CUE' DC input breaker open 10 Wait 60 seconds Waited 60 seconds for for inverter to the inverter to stabilize. stabilize.

POSITIVE CUE:

Inverter.has stabilized.

11. Check inverter Checked inverter output is - 120 output voltage ~120 volts and Volts and frequency frequency is - -60 Hz.

60 Hz.

POSITIVE CUE:

Inverter output is

-120 volts /60 Hz.

NEGATIVE CUE:

! Inverter output is l- O volts /0 Hz. Breaker.

l (C) 12. Close Inverter On the front of the Output breaker. inverter closed the  ;

Inverter output  !

POSITIVE CUE: breaker.

~

Inverter output breaker closed.

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++

i JOB PERFORMANCE MEASURE Page 5 of 8 PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT

13. Verify the Verified the " UNIT IN inverter " UNIT SYNC" light ON.

IN SYNC" light ON.

POSITIVE CUE:

UNIT IN SYNC light on.

NEGATIVE CUE:

UNIT IN SYNC light is not on.

(C) 14. Piace the manual Placed the manual selector switch selector switch (HS-

-(HS-1122) in the 1122) in " NORMAL

" NORMAL SOURCE SOURCE TO LOAD" TO LOAD" position.

position.

POSITIVE CUE:

Switch in NORMAL SOURCE TO LOAD position.

15. Verify the Verified " UNIT IN inverter " UNIT SYNC" light on, and IN SYNC" light frequency between is on and 59.5 and 60.5 Hz.

frequency is between 59.5 and 60.5 hertz.

POSITIVE CUE:

Inverter UNIT IN SYNC light is on NEGATIVE CUE:

UNIT IN SYNC Light is not on.

(C) 16. Shift load to Depressed the the inverter. " INVERTER TO LOAD" push-button.

POSITIVE CUE:

" INVERTER SUPPLYING LOAD" light ON.

NEGATIVE CUE:

" ALTERNATE SOURCE SUPPLYING LOAD" light ON.

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JOB PERFORMANCE MEASURE Page 6 of 8 ,

~

PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT

17. Verify INVERTER Verified INVERTER SUPPLYING LOAD SUPPLYING LOAD light i light on and on and ALTERNATE ALTERNATE SOURCE SOURCE SUPPLYING LOAD SUPPLYING LOAD light out.

light out.

POSITIVE CUE

l INVERTER SUPPLYING LOAD light on and ALTERNATE SOURCE SUPPLYING LOAD light out. 1 l

18. Check local Reset alarms on local 1 alarm panel and alarm panel. I reset all related alarms.

POSITIVE CUE:  !

All alarms clear on l local alarm panel. ,

19. Verify RS1 Called control room l INVERTER TROUBLE to RS1 INVERTER l alarms are TROUBLE alarms are '

clear. clear.

POSITIVE CUE: .

Control Room reports all inverter trouble alarms clear.

END l

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JOB PERFORMANCE MEASURE

- Page 7 of 8 062 A3.03 2.3/2.3 Jusufication for use of <2.5 K/A:

Improper breaker operation may result in loss of power to vital 120VAC panels that could result in plant inp..

Question: If the SYNC light is not on what actions are required?

Answer: Electncal Maintenance assitance is required to correct the problem.

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Reference '. Inverter and 120VAC Vital AC Distribution (1107.003) Rev 8 PC 4 page19. .

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PROCJWORK PLAN NO. PROCEDURE / WORK PLAN TITLE: PAGE: 19 wi146 C'EV: 8 1107.003 INVERTER AND 120V VITAL AC DISTRIBUTION CHANGE:

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NOTES

1. If ALTERNATE SOURCE SUPPLYING LCAD light is on, the load remains on l alternate source regardless of position of manual selector switch.  !

2. If manual selector switch is in ALTERNATE SOURCE TO LOAD position, the load remains on alternate source regardless of position of static switch.

8.3.7 Switch Yll manual selector switch (HS-1122) to j

NORMAL SOURCE TO LOAD position as follows.

A. Verify Inverter Y11 UNIT IN SYNC light is on.

B. Place Inverter Yll manual selector switch (HS-1122) in NORMAL SOURCE TO LOAD position.

8.3.8 Shift load to Inverter Y11 as follows:

A. Verify Inverter Yll UNIT IN SYNC light is on and frequency is between 59.5 and 60.5 l hertr.

C'JMUTION i Transferring out of sync may cause loss of load. If IN SYNC light is not on, l Electrical Maintenance assistance is required. l i

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B. Depress Inverter Yll INVERTER TO LOAD  ;

pushbutton (PB-1100). j C. Verify Inverter Yll INVERTER SUPPLYING LOAD light comes on and ALTERNATE SOURCE SUPPLYING LOAD light goes out.

NOTE

.. Inverter Y11 is now in normal operating mode.

2. Inverter output overvoltage alarm may take as much as 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> to clear as inverter reaches normal operating temperature.

8.3.9 When alarm conditions clear, reset Y11 local

' alarm panel. Alarm reset not required to continue.

B.3.10 When local alarm panel is reset, verify RS1 INVERTER TROUBLE (K01-A51 alarm in control room is cleared. Alarm reset not required to continue.

8.3.11 l' applicaole, exit LCO entered for RS panel on alternate source. Otherwise N/A.

_J

JOB PERFORMANCE MEASURE Page 8 of 8 KAA 062 K5.03 2.4/2.6 2 hstlication for use of <2.5 K/A:

Improper breaker operation may result in loss of power to vital 120VAC panels that could result in plant

, ~ trip.

Guesti n: Why does the inverter have to be in sync before using the static switch to change from the alternate source?

Answer: The static switch is a make-before-break switch and no interlock exists to prevent switching out of sync.

Reference Invener and 120VAC Vital AC Distribution (1107.003) Rev 8 PC 4 page 6.

2 -

I l PROCJWORK PtAN NO. PROCEDURE / WORK PLAN TTTLE: PAGE: 6 Cf 146 1107.003 INVERTER AND 120V VITAL AC DISTRl!UTION RW: 8 CHANGE:

l  !

Switching to and from the alternate source using the static switch requires that the system be in sync. Using the manual selector switch also requires l the systems to be in syne because the switch is a make-before-break contact, '

however, there is no interlock to prevent switching out of sync.

Y28 has an additional breaker on the front of the cabinet, " Alternate Source AC Input to the Static Switch". This breaker can be used to allow naintenance l on the static switch while still supplying alternate AC power to C540. Y28 has a slightly different control and instrument arrangement and has no fault l protection breaker inside the cabinet. Y41 has no rectified AC input and the j Alternate Source AC Input breaker is connected in the circuit similar to the

Y28 " Alternate Source AC Input to the Static Switch" breaker.

L Power distribution to and from the inverters is as follows:

Alternate Inverter AC Input Source DC Input Output to:

Y11 B-5141A D01-22A RS1 Y13 B-5315 D01-52B RS3 Y15 B-5714 D01-53A RS1 or RS3 Y22 B-6543 D02-42A RS7 Y24 B-6145A D02-22A RS4 Y25 B-6315 D02-32 RS2 or RS4 Y41 B-5643A D-4184 RC1 Y28 B-6134B B-6134A D02-41B C540 Instrument power supplies in C27 provide a source of DC voltage for balance of plant (BOP) instrumentation. There are two 120V AC supplies to this panel.

Y'.1 treaker 38 supplies the norwal DC power supply. YO2 breaker 6 supplies tne stancby DC power supply. A power supply selector switch in C27 can

nnect either DC power supply to the load. Or, in AUTO, the two DC power supplies are auctioneered such that the one with the highest output voltage w:ll supply the load.

W tn tne power supply selector switch in AUTO, the DC power supply will not be isst :f one of the input sources (YC: or YO2) is lost.

A listing of the instru. tents supplied by C27 BOP power supply is contained in tne Eechtel design drawing, Schemats c Diagram Miscellaneous Instrumentation Power Supplies (E-330).

Instrument power supplies in C28 provide a source of DC voltage for other instrumentation. There is only one 120V AC supply to this panel, YO1 breaker

6. There are two DC power supplies in C28 with a power supply selector switch as in C27. However, with a single source of power (Y01), loss of this input ,

power will result in loss of the DC power supply. A listing of the i instruments supplied by the C2B power supply is contained in the Bechtel cesign drawing, Auxiliary Systems Miscellaneous Instruments (E-254). I i

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Page 1 of 5 I

l I l' -JOB PERFORMANCE MEASURE l

. UNIT: 1 REV # , 4 DATE: l

i. .TUOI NUMBER:-ANO-1-JPM-RO-RBC01 )

SYSTEM / DUTY AREA: REACTOR BUILDING COOLING TASK: MAXIMIZE REACTOR BUILDING COOLING

.JTA#: 10225010101 l KA VALUE RO.,,3 2 SRO: 3.2 KA

REFERENCE:

022 A4.03 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X

.. TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

! PLANT SITE: SIMULATOR: PERFORM LAB POSITION EVALUATED: RO: SRO:

l ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:

.ESTING METHOD: SIMULATE: PERFORM:

!' APPROXIMATE COMPLETION TIME IN MINUTES: 3 MINUTES

! . REFERENCE (S) : EOP 1202.012 REV. 3, PC-5, RT9 I

i

"MINEE' S NAME: SSN - -

EVALUATOR'S NAME:

l ~THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS I CONTAINED IN THIS JPM AND'IS DETERMINED TO BE:

l SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

1 l-i

! Start Time Stop Time Total Time l SIGNED DATE:

l SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A

. QUALIFIES INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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m . _, . . . _ _ _ _ _ _ _ _ _ _ - . - _ . . . . _ _ _ . _ . . . _ _ _ . - _ . . . . . . . . _ . _ . . . . _ _ . _ _ _ . . _ - - _ _ _ _ . _ _ _ .

. age 2 of 5  ;

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IUOI NUMBER: ANO-1-JPM-RO-RBC01  :

THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE: f The examiner shall review the " Briefing Checklist - System Walkthrough" portion of  ;

OP 1064.023 Attachment 6 with the examinee. l JPM INITIAL TASK CONDITIONS: Reactor is tripped with a steam leak inside the Reactor Building, f

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TASK STANDARD: Reactor Building cooling started with full service water flow I i

to RB cooling coils and all four chiller bypass dampers opened. .,

i TASK PERFORMANCE AIDS: Key for bypass dampers, EOP 1202.012, RT9 l

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Page 3 of 5 fUOI NUMBER: ANO-1-JPM-RO-RBC01 ZNITIATING CUE:

The control Room Supervisor directs you to initiate Reactor Building cooling.

CRITICAL ELEMENTS (C): 2, 3 PERFORMANCE CHECKLIST: STANDARDS N/A SAT UNSAT i - e - -: re o , , ,  :>; +

NOTE: ' STEPS' MAY<BE- ACCOMPLISHEDjIN ANY ORDER :. L. >

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ac w hl.,L,,,I. 11 OI- Y ), ""* 4 4't*

C PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT

1. Verify all four RB cooling Verified RB cooling fans fans running. running on C16 and C18.

POSITIVE CUE:

red light on, green light off for VSF-1A thru VSF-1D.

2. Open RB Cooling coils Opened CV-3812/CV-3814/ CV-Service Water Inlet and 3813/CV-3815.

C Outlet valves using handswitches on C16 and C18 for CV-3812/CV-3814/

CV-3813/CV-3815.

POSITIVE CUE:

red light on, green light off for CV-3812/CV-3814/ CV-3813/CV-3815.

, 3. Unlatch key-locked Chiller Unlatched all four Chiller Bypass Dampers. Bypass Dampers.

C l POSITIVE CUE:

red light on, green light off for SV-7410, SV-7411, SV-7412, SV-7413.

NEGATIVE CUE:

Maximum RB Cooling not established.

END

Page 4 of 5 KCA 022 A3.01 4.1/4.3 Quastion: What conditions would automatically maximize Reactor Building cooling?

Answer: Actuation of ESAS channels 5 & 6 at >4 psig (18.7 psia).

Raforence Engineered Safeguards Actuation System (1105.003) Rev 10 PC 1 page 3.

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PROCJWORK PLAN NO. ' PROCEDURE /WMK PLAN TITLE: PAGE: 3 Cf 16 1105.003 ENGINEERED SAFEGUARDS ACTUATION SYSTEM REv: 10 CHANGE: /DC - t i t.

3.5' Summary of ESAS trips anu functions:

Channel No. Action Trio Condition Trip Point l 1& 2 HP injection & Low RCS pressure <1590 psig l

i. diverse contain- High RB pressure >4 psig (18.7 psia) )

l ment isolation

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l 3& 4 LP injection, Low RCS pressure- <1590 psig 1

j diverse contain- High RB pressure >4 psig (18.7 psia) i ment isolation &  ;

EEW 5& 6 RB isolation & High RB pressure >4 psig (18.7 psia)  ;

RB cooling 1 l

i 7& 8 RB spray- High RB pressure >30 psig (44.7 psia)

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, 9& 10 RB Spray NACH High RB pressure >30 psig (44.7 psia) l- Addition' l 4.0 1trERENCES '

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4.1 REFERENCES

USED IN PROCEDURE PREPARATION  !

i 4.1.1 Unit 1 Technical Specifications 4.1.2 ESAS Technical Manual, Volume 3 (M-1-29) 4.1.3 Engineered Safeguards Actuation System (STM-1-65)

! 4.1.4 Safety Analysis Report, sections 6, 7.1.1, 7.1.3, 7.4.7 and 14.2.2.5 4.1.5 Integrated ES System Test (1305.006) l 4.1.6 CR-1-96-0359 ESAS Setpoint Change j 4.1 7 DCP 95-5010-D101 SW Valve Replacement

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4.2 I REFERENCES USED IN CONJUNCTION WITH THIS PROCEOURE 1 l 4.2.1 Plant Startup (1102.002)-

4.2.2 Plant Shutdown and Cooldown (1102.010) 4.2.3 Decay Heat Removal Operating Procedure (1104.004) 4.2.4 Emergency Feedwater Initiation and Control (1105.005) l 4.3 NRC COMMITMENTS 4.3.1 P 7617 (1-049-6) IE Bulletin 79-05A. Spurious Es actuation. Contained in "ESAS Operation After Spurious or Inadvertent Actuation" sect on.

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Page 5 of 5 KEA 022 A4.04 3.1/3.2 Gusstion: How are the Reactor Building Cooling Fan back draft dampers operated?

Answer: The back draf t damper is contro11edby the same handswitch as it's associated fan.

Raference System Training Manual 1-09 Rev 2 page 4.

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Rosctar Building Ventil tian STM 1-09 Rsv. 2 l A through ID, (SV-7410, 7411. 7412 & 7413) are controlled through the following hand switches:

Damper Control Ctl. Sw. Power Supply ES Actuatmg Switch Location Signal SV-7410 HS-7415 (C18) B5244 ES-5 HS-7435 (Local)

SV-7411 HS-7416 (C18) B5222 ES-5 HS 7436 (Local)

SV-7412 HS-7417 (C16) B6222 ES-6 HS-7437 (Local)

SV-7413 HS-7418 (C16) B6252 ES 6 HS-7438 (Local)

Flow rate through the Ventdation System is approxunately 120,000 cfm based on four fans in service. M-261 diagram shows the flow rate as per the SAR which is based on three fans in service for a total of 94,000 cfm. 57,000 cfm of which is supplied to the RCP l cavities for coolmg of the RCP's and to the lowest elevation of the buildmg for start circulauon in the RB. Another 9.000 cfm is supplied to the reactor cavity area. This air flows up between the reactor wssel and the concrete shield wall, then out between the hot leg piping and the concrete his air flow is used to prevent the concrete stueld from cwh g ad crackag. The balance of the total flow is distributed eveni; thwaghout the rest of the building.

Four fan flow is determined by itsg a quarter of the flow given for each location.

Each supply fan (VSFIA-D) has an associated discharge butterfly valve (CV-7470-7473) that opens when the fan starts.

These valves are back-draft damners that prevent reverse air flow through the fan when not runmng. He valves are controlled from the same hand switches as the supply fans and are powered from MCC  !

B5252 for CV-7470, B5332 for CV7471, B6212 for CV7472, and B l

6332 for CV-7473. Each valve has position indication on its i associated Control Room panel.  ;

Ducting in the reactor tuilding is protected by safety relief dampers that prevent implosion during accident conditions. ,

i Ventilation Unit Heaters (VUH46-53) are spaced intermittently i throughout the RB. They are used to mamtam RB temperature above 60'F durmg cold weather shutdowns. Each heater is a 130,000 Btu /hr unit which uses hot water from the plant heatmg system as a heatmg medium. Each unit is equipped with a fan to move air through the heating coils. The plant heatmg supply is normally flanged at the penetration and requires a flexible hose installed to provide water supply. These fans are powered from the followmg 120 volt panels:

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Page 1 of 6 JOB PERFORMANCE MEASURE UNIT: 1 REV # 1 DATE:

TUO! NUMBER: ANO-1-JPM-RO-AOP18 j SYSTEM /DLTTY AREA: EMERGENCY AND ABNORMAL OPERATIONS I

TASK: PERFORM ACTIONS FOR A LOSS OF DECAY HEAT REMOVAL j JTA#: 13035510401 KA VALUE RO: 33 SRO: 3.6 KA

REFERENCE:

025 AA2.04 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE: SIMULATOR- PERFORM LAB:

POSITION EVALUARID: RO: SRO:

ACIUAL TESTING ENVIRONMEl(T: SIMULATOR: PLANT SITE: LAB:

'ESTING MEUiOD: SIMULATE: PERFORM:

' APPROXIMATE COMPLETION TIME IN MINUTES: 7 MINUTES REFERENCE (S): 1203.028 REV.14.Section I i

EXAMINEE'S NAME. SSN - -

EVALUATOR'S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

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l-i Start Time Stop Time Total Time

SIGNED DATE:

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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Page 2 of 6 ,

f TUO! NUMBER: ANO-1-JPM-RO-AOP18 i

THE EXAMINER SHALL REVIEW HIE FOLLOWING WITH n!E EXAMINEE: I The examiner shall review the " Briefing Checklist - System Walkthrough" poruon of OP 1064.023 Attachment 6 with the examince; t

JPM INITIAL TASK CONDITIONS: Decay Heat Removal System is in service with RCPs off.  !

i Pressurizer level is dropping rapidly l

TASK STANDARD: The runnina decay heat DumD (P34B) was manually stooa~l. one Decay Heat

[;

Suction Valve was closed (CV-1050 or CV-1404 or CV 1410) and the "B" DH Pumo suction  !

valve (CV-1434)is shut i

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i TASK PERFORMANCE AIDS: Loss of Decay Heat Removal AOP after immediate actions are [

f completed. I f

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Simulator setus: recall an IC with "B" Decay Heat Removal Pump in service and RCPs off. Insert a malfunction which causes an RCS leak inside the auxiliary building.

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Page 3 of 6 TUOI NUMBER: A NO- 1 -JPM-RO- AOP18 INITIATING CUE:

The SS/CRS informs you that the WCO has loacted a large leak on the pump seal for ""B" Decay heat pump and directs you to perform the immediate actions for Loss of Decay Heat Removal due to a DH System Leak.

CRITICAL ELEMElfrS (C): L 2. 8 (C) PERFORMANCE CHECKLIST STANDARD N/A l SAT UNSAT

1. Stop the running Decay Heat Removal On panel C16 (P-34B) stopped the Pump (P-34 A). nanning Decay Heat Removal Pump (C) using its handswitch.

POSITIVE CUE: green light ON, red light OFF above DHR Pump handswitch.

2. Close at least one Decay Heat Suction On panel Cl4 (CV-1404) or C16 (CV-valve (CV-1050 or CV-1404 or CV-1410). 1410) or C18 (CV-1050), closed at least one of the three Decay Heat Suction POSITIVE CUE: green light ON red light valves. Observed green light ON, red (C) OFF for valve (s) that examinee closed. light OFF for the valve (s) manipulated.

NEGATIVE CUE: pressurizerlevelis lowering.

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l NOUITO EXAMINER '

After the above steps are completed Examince may reference Loss of Decay Heat Removal AOP (1203.028) for follow up actions. .

3. Notify Shift Superidv0Wnt/CRS to .

implement EAL classb atmn.

l POSITIVE CUE: EAL classification in progress.

4. Determine if maintenance actisities in the Reactor Building could be affected by RCS Level Rise, perform local evacuation of the affected areas.

POSITIVE CUE: No maintenance activities are in progress inside the Reactor building.

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5. Determine if RCS temperature will Momtor ICCMDS and/or SPDS for CET exceed 280'F. temperature.

POSITIVE CUE: RCS temperature is 150'F and slowly nsing.

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(C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT ,

6. Deternune that containment closure per 1203.28 Attachment G is not required.  !

!. e' Time to steam release >Ihour l l

e RCS p.T. ssure <l50 psig. I l e RCS press > DH sys max press limit

! per i102.010 Att A not applicable 3 1

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POSITIVE CUE contaiment closure is not i l required. '1

7. Determine that leak is not common to  !

both DH system. >

I l POSITIVE CUE: Local verification by operator in P34B vault reveals leak on P#SB seal. t l i l 8. Isolate the leak in the "B" DH system by Close CV 1434 using handswitch on l closing P34B suction valve (CV-1435). C-18.

(C) i POSITIVE CUE: CV-1434 indicates  :

closed.

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Page 5 of 6 l

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i K&A( g005 K4.07 3.2/3.5 j e

1 Question: At what RCS pressure ns the auto-close interlock for the Decay Heat Suction Valves reset?

l Answer: 290 psig.

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Reference Deacy Heat Removal Operating Procedure (1104.004) Rev 63 PC 1 page 14. I i

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PROCJWORK PLAN NO. PROCEDUREMtORK PLAN TITLE: PAGE: 14 Cf 77 1104.001 CORE FLOOD SYSTEM OPERATING PROCEDURE REV: 29 CHANGE:

9.0 Draining CFT T-2A to RB Sump (DWDH) During Reactor Shutdown 9.1 Determine amount of borated water to be drained and verify dirty liquid system is available to process required amount.

C' J MUTION Vented gas may be radioactive.

9.2 Reduce CFT T-2A pressure to -50 psig by opening Core Flood Tank T-2A Vent (CV-2417), then close CV-2417.

9.3 open Core Flood Tank T-2A Drains to DWDH (RBD-1A and RBD-2A).

9.4 Monitor RB sump and ensure floor drain handles drain flow and does not back up during draining evolution.

9.5 When desired level is reached, close RBD-1A and RBD-2A.

10.0 Draining CPT T-2B to RB Drain Header During Reactor Shutdown 10.1 Determine amount of borated water to be drained and verify clean liquid waste system is available to process required amount.

NOTE Draining CFT T-2B to ABEDT is a containment breach and requires tracking on either Category E Valve Log (Form 1015.035A) or Containment Closure Breach List (Form 1015.002D).

10.2 Unlock and open RBDH Isol to ABEDT (RBD-23 and RBD-24)

A. If required, make appropriate entry in Category E Valve Log (Form 1015.035A).

B. I' required, make appropriate entry on Containment Closure Breacn List (Form 1015.002D).

I 10.3 Open RBDH Isol to ABEDT (RBD-14). l l

J MUTION C'

Vented gas may oe radioactive.

1 10.4 Reduce CFT T-2B pressure to ~50 psig by opening Core Flood Tank T-2B Vent (CV-2420), then close CV-2420.

10.5 Open Core Flood Tank T-2B Drains to RBD (RBD-1B and RBD-2B) .

10.6 When desired level is reached, close RBD-1B and RBD-2B.

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.K&A 005 K3.013,9/4.0

. Question: If Decay Heat removal is lost containment closure must be established prior to what? i

)

1 Answer: Containment closure must be established prior to steam release.

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Reference . Loss of Decay Heat AOP (1203.028) Section 2 Rev 14 page 11.

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P.iOC.* WORK PLAN NO. ! PROCEDUREN/ORK PLAN TITLE: PAT E: 11 Cf 54 1203.028 LOSS OF DECAY HEAT REMOVAL REV: 14 l

i CHANGE:

I SECT!CN 2 -- DH REMOVAL SYSTEM LEAK (continuec)

NOTE

1. Containment closure must be established prior to steam release.

2. Decay Heat Removal and LTCP System Control (1015.002), Form 1015.002B provides estimate of time to 200*F, time to steam release, time to core uncovery, heatup rate, and required makeuo rate.

3.4 g any of the following conditions occur, initiate containment closure per Attachment G of this procedure, while continuing with this section.

• Time remaining to steam release is o_r_ becomes <1 hour and DH removal cannot be immediately restored.

• RCS press >150 psig and RCS loops not filled.

• RCS press > Decay Heat Sys. Max. Pressure limit of Plant Shutdown and Cooldown (1102.010), Attachment A.

3.5 M leak is common to both DH systems and is unisolable, GO To applicable " Loss of Both DH Systems" section of this procedure.

CAUTION

1. If RCS loops are not filled and DH pump is started with high flow, severe water hammer can damage DH system pipe.

2. If RCS press is >150 psig and DH pump is dead-headed, DH system design oress can be exceeded.

3.6 Isolate leak and restore DH Removal system as follows:

3.6.1 Verify CH pumps (P-34A and P-34B) off.

3.6.2 g leak is in "A" DH system and is un1E lable, close P-34A Suction From RCS (CV-1434).

3.6.3 M leakand is in "B" DH system is unisolable, close P-34B Suction From RCS (CV-1435).

3.6.4 M "A" DH system is to be placed in service, perform the following:

A. Verify DH suction press <75 psig.

B. Verify P-34A Suction From BWST (CV-1436) closed.

C. Open P-34A Suction From PCS (CV-1434).

Paga 1 of 6 JOB PERFORMANCE MEASURE UNIT: 1 REV # 1 DATE:

TUOI NUMBER: ANO-1-JPM-RO-CRD02 SYSTEM / DUTY AREA: CONTROL ROD DRIVE SYSTEM TASK: TRANSFER A GROUP OF RODS FROM THE NORMAL TO THE AUXILIARY POWER SUPPLY JTA#: 10015070101 KA VALUE RO: 3.4 SRO: 3.4 KA

REFERENCE:

001 K4.13 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE: SIMULATOR: PERFORM LAB:

POSITION EVALUATED: RO: SRO:

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:

ESTING METHOD: SIMULATE: PERFORM:

APPROXIMATE COMPLETION TIME IN MINUTES: 10 MINUTES REFERENCE (S): 1105.009 REV. 15, EXAMINEE'S NAME: SSN -

EVALUATOR'S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

Start Time Stop Time Total Time

GNED DATE:

JIGNATURE INDICATES THIS JFM HAS BEEN COMPARED TO ITS APPLICABLE FROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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.JOI NUMBER: ANO-1-JPM-RO-CRD02 THE EXAMINER SHALL. REVIEW THE FOLLOWING WITH THE EXAMINEE:

• i Th3 czaminer shall review the

• Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee. ,

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l JPM INITIAL TASK CONDITIONS: Rx demand and diamond stations are in manual. ,

! I TASK STANDARD: Group 1 Rods have been transferred to the Auxiliary Power Supply and ,

l rre enabled for being moved on that power supply.

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TASK PERFORMANCE AIDS: OP 1105.009, section 8.0 l i  !

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i Pega 3 of 6

.U01 NUMBER: ANO-1-JPM-P.O-CRDo2 l

INITIATING CUE:

- Ycu have been directed by the CRS to transfer Group 1 Rods to the Auxiliary Power Supply.

CRITICAL EI.EMENTS (C): 2, 3, 4, 5, 6, 8, 9, 10, 11 i C PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT

1. Verify transfer reset lamp is ON and TR On CRD Diamond Panel, .

CF is OFF. condition of both lights i were checked. Transfer  :

POSITIVE CUE: reset lamp was ON and TR CF was OFF.

Transfer reset lamp is ON and TR CF is OFF.

1

2. Place Group select switch to Group 1. On CRD Diamond l Panel, Group Select Switch l C POSITIVE CUE: was placed in Group 1 1 position.

]

Group select switch is in Group 1 position. '

3. Select Single Select Switch to ALL. On CRD Diamond Panel, J Single select switch was  !

C POSITIVE CUE: selected to ALL. j l

Single Select Switch is at ALL position.

4. Set Auto / Manual Switch to Manual, On CRD Diamond Panel, verified Manual Lamp is ON. Auto / Manual pushbutton

.C was selected to MANUAL.

POSITIVE CUE:

Manual lamp is now ON.

5. Set SEO.- SEQ OR. switch to SEO. OR On CRD Diamond Panel, position. SEO OR backlight lamp is verified SEO. SEO OR. switch was C ON. selected to SEQ. OR position.

POSITIVE CUE:

SEO OR backlight lamp is ON. I

6. Set Group / Auxiliary Switch to Auxiliary. On CRD Diamond Panel,  !

Aux PB backlight is verified on. Group / Aux. PB was C selected to Aux.

POSITIVE CUE:

l Aux PB backlight is verified on. i

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l TUOI NUMBER: ANO-1-JPM-RO-CRD02

7. Observed light indications to verify On CRD Diamond Panel, Control On lamp is lighted for Group 1. Group 1 Control on lamp

! lighted.

POSITIVE CUE:

Control On lamp is lighted for Group 1.

8. Set Speed Select Switch to " JOG", SY On CRD Diamond Panel, backlight verified ON. Speed Select Switch was C selected to JOG position.

POSITIVE CUE:

SY bacidight is ON.

9. Set Clamp / Clamp Release Switch to On CRD Diamond Panel, CLAMP, verified CLAMP CONFIRM light selected Clamp / Clamp came on. Release Switch to CLAMP.

C POSITIVE CUE: I CLAMP CONFIRM (amber) light is on. i

10. Press Manual Transfer Switch, verified On CRD Diamond Panel, Group 1 Control on White lights on the CRD manual transfer PB was C Position Indicating Panel. depressed.

POSITIVE CUE:

Group 1 Control on White lights on the Pl Panel are on.

11. Set Clamp / Clamp Release Switch to On CRD Diamond Panel, Clamp Release, verified CLAMP RELEASE depressed Clamp / Clamp fight came on. Release Switch, C POSITIVE CUE:

Clamp Release light is on.

NEGATIVE CUE:

Group 1 Rods will not move.

END l

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Paga 5 cf 6 KEA 001 K4.02 3.8/3.8 Question: What conditions must be met for group 7 CRD's sequence enable to occur?

Answer: All of the following conditions must occur; e All safety groups at out limit e Group 5 at out limit

• Group 6 >75 withdrawn R3ference CRD Operating Procedure (1105.009) Rev 15 page 9.

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PROCJWORK D".AN NO. PROCEDUREMORK PLAN TITLE: PAGE: 9 of 61 1105.009 CRD SYSTEM OPERATING PROCEDURE REV: 15 CHANGE:

I l S. Group 6 Sequence Enable e All safety groups at out-limit e Group 5 API average greater than 75%

e Group 7 API average less than 25%.

C. Group 7 Sequence Enable l

l e All safety groups at out-limit e Group 5 at out-limit e Group 6 API average greater than 75%.

3.9 CRD Position Indication

' 1 3.9.1 Absolute Position Indication (API) determines rod position I l

with a series of reed switches mounted alongside the upper -

l motor tube. A magnet attached to the torque taker closes j the reed switches sequentially during vertical travel. '

Groups 1-6 have 52 reed switches, 45 of which are wired in parallel with a resistor string so that resistance is proportional to vertical position.

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Groups 7 and 8 are provided with 79 reed switches, 72 of which are divided into 2 separate channels, each having its own resistor string. Each channel gives a continuous i output of vertical position. Normally, the channels are I averaged for API. Bypass switches located on the I

individual buffer amplifier cards in the PI amplifier panel (C77, computer room) can be used to switch off either

! channel, A or B. Removal of the card allows access to l bypass switch, during which indication will be lost. With

' one channel bypassed, the other channel outputs with a small loss of accuracy.

All rods have 7 reed switches providing in-limit, 0%, 25%,.

50s, 75%, '00% travel and out-limit.

l 3.9.2 Relative Position Indication (RPI) monitors 3 phases of the 6 phase input to the CRD motor. These 3 phases drive a l stepping motor, which operates a theostat. This signal provides position indication propertional to motor

} revolutions. RPI output can be adjusted by operating the l position reset switch on'the PI panel in con] unction with the cnosen group or rod on the Diamond Panel.

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Pcge 6 of 6 i

K&A 001 A2.20 2.6/3.6 l

Ousation: What action is required if 3 CRD's are reading 190*F7 Answer: Trip the reactor and follow the Emergency Operating Procedure.

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Raforence Control Rod Drive Malfunction Action (1203.003) Rev 19 Section 2 page 11.

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PROCJWORV. PLAN NO. PROCEDUREN ~4 PLAN TITLE: I PACE: 11 Cf 18 j 1

1203.003. CONTROL ROD DRIVE MALFUNCTION ACTION RW: 19 l CHANGE:

SECTION 2 -- CRD STATOR TEMPERATURE HIGH 1.0 SYMPTCMS 1.1 Stator temp. HI alarm on plant computer alarm screen.

1.2 CRD COOLING RETURN TEMP HI (K08-B1) annunciated.

2.0 IMMEDIATE ACTION l NONE l

3.0 FOLLOW-UP ACTIONS l l

l 3.1 Verify standby CRD Cooling Pump (P-79A or P-798) running.

l 3.2 From plant computer, commence taking CRD Motor Temperature Reports (computer function: NASP, N4, F4, 2, Enter, Enter) at ~5 minute )

intervals or more often as necessary. Continue until temperatures j stabilize. ,

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NOTE Since Group 8 rods will not drop when deenergized, manual Rx trip is only i required if more than one rod in Groups 1-7 is >l80*F. l l l l 3.3 g more than one CRD stator in Groups 1-7 exceeds 180*F, trip reactor and follow Emergency Operating Procedure series (1202.XXX).

3.4 Check local CRD cooling water supply filter and pre-filter AP's in ammonia pump pit.

3.5 Vent CRD cooling water pumps, filters and high points on lines. .

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3.6 Verify non-nuclear ICW temperature and flow are normal (009).

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.~ M only one CRD stator temperature in Groups 1-7 exceeds 180*F due to I an eve

.. which is confined to that stator alene , then proceed as ,

follows: l 3.7.1 Reduce neutron power to <40% of 902 MWe (<360 MWei.

3.7.2 Take manual control of reactor demand H/A station and Diamond panel.

3.7.3 Transfer affected rod to' AUX supply per CRD System j operating Procecure (1105.009), " Transfer to Auxiliary i Power" section.

l I 3. 7. 4 ' In computer room, in Au:.111ary Power Supply A cabinet (C72), remove the following fuses from the programmer control assemoly to de-energize auxiliary power supply and drop affected rod.

A. 120 Y AST

3. *20 Y Bus I 4

JOB PERFORMANCE MEASURE i

Page 1 of 6 UNIT 1.: X REV #: 0 DATE:

- TUCI NUMBER: ANO-1-JPM-RO-AOP25 SYSTEM: Emergency and Abnormal Operatons TASK: Respond to loss of loadeenter B2.

.JTA 106263904A4 KA VALUE RO: 3.4 SRO: 3.9 KA

REFERENCE:

062 A2.01 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X

. TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PIANT SITE: SIMULATOR: PERFORM LAB:

. POSITION EVALUATED: RO: SRO:

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:

TESTING METHOD: SIMULATE: PERFORM:

APPROXIMATE COMPLETION TIME IN MINUTES: 15 minutes REFERENCE (S): AOP 1203.046, Rev. 1 PC3 e

EXAMINEE'S NAME: SSN: - -

. EVALUATOR'S NAME:

THE EXAMINEE'S PERTORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

Start Time Stop Time Total Time SIGNED DATE:

SIGNATURE' INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED

- INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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__.____7 1

JOB PERFORMANCE MEASURE Page 2 of 6 ,

THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

The examiner shall review the " Briefing Checklist - System Walkthrough" portion of 1

OP1064.023 Attachment 6 with the examinee.

l JPM INITIAL TASK CottDITIONS: A breaker fault has resulted in the loss of loadcenter B2.

Unit is at 100% power. l 1

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l TASK STANDARD: AOP 1203.046, steps 3.2.1 through 3.2.9 completed. l l

TASK PERIWtMANCE AIDS: Copy of AOP 1203.046, Rev 1, section 3.2 l

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JOB PERFORMANCE MEASURE Page 3 of 6 INITIATING CUE:

The SS directs you respond to loss of loadeenter B2 in the control room.

CRITICAL ELEMENTS (C): 1, 3, 8 (C) PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT

1. Place ICW pumps P-33B On panel C09, and P-33C in pull-to- handswitches for P-33B lock. and P-33C placed in (C) pull-to-lock.

POSITIVE CUE:

Handswitches in pull-to-lock.

NEGATIVE CUE:

Handswitches in normal-after-stop or normal-after-start.

2. Verify suction and On panel Cu9, verified discharge crossconnect valves CV-2238, CV-valves open. 2239, CV-2240, CV-2241 indicate RED.

POSITIVE CUE:

CV-2238, CV-2239, CV-2240, CV-2241 indicate RED.

NEGATIVE CUE:

CV-2238, CV-2239, CV-2240, CV-2241 indicate GREEN.

3. Isolate Letdown. At C16, Letdown isolated by closing POSITIVE CUE: Letdown Coolers outlet (C) Letdown flow FI-???? CV-1221.

Indicates bottom of scale.

Examiner Note:

Tall examinee that step 3.2. 4 has been completed.

4. Verify ICW booster At C09, verified P-pump P-114A or P-114B 114A or P-114B running. indicated RED.

POSITIVE CUE:

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P-114n or P-ll4B indicate RED.

NEGATIVE CUE:

P-ll4A or P-ll4B indicate GREEN.

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l JOB PERFORMANCE MEASURE -

i Page 4 of 6 (C) PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT

5. Verify CRD Cooling on panel C09, verified '

Water Pump P-79A P-79A indicated RED.

l running.

i POSITIVE CUE:

P-79A indicates RED. '

6. Verify a MEW Pump On panel CO2, verified Turbine oil pump indicating lights were

! running for each RED for at least one l operating Main oil pump on MEW Pumps Feedwater pump. A and B.

POSITIVE CUE:

P26A, P27A, or P28A  !

l indicates RED.  ;

l P26B, P27B, or P28B ,

indicates RED.

j 7. Verify Condensate Contacted inside AO to l Transfer Pump P-9A verify P-9A running.

running.

POSITIVE CUE: i P-9A running. '

8. Isolate Letdown Oc panel C04, closed Cooler. RC t.o Letdown Coolers, CV-1213, indicates (C) POSITIVE CUE: GREEN.

CV-1213 indicates GREEN.

l l NEGATIVE CUE:

CV-1213 indicates RED.

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JOB PERFORMANCE MEASURE

.' age 5 of 6 L

K&A 008 K1.02 3.3/3.4 Question: What cKect does a loss of RCP Seal Injection to the RCP seals under this condidon have?

Answer: Alempt to restore seal injection or seal cooling within 2 minutes. Continued operation without seal injection or seal cooling will cause seal damage due to overheating.-

Reference Reactor Coolant Pump and Motor Emergency AOP (1203.031) Section 3 page 9.

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PROC / WORK PLAN NO. PROCEDUREjWORM PLAN TITLE: PAGE: 9 cf 25 j 1203.031 REACTOR COOLANT PUMP AND MOTOR EMERGENCY REV: 13 i CHANIE:

SECTION 3 SIMULTANEOUS LOSS OF SEAL INJECTICN AND SEAL COOLING FLOW l

1.0 ZYMPTCMS

• RCP SEAL INJ FLOW LO (K08-A7)

• RCP SEAL COOLING FLOW LO (K08-E7)

• RCP BLEED OFF TEMP HI (K08-C7) 2.0 IMMEDIATE ACTION None.

3.0 FOLLOW-UP ACTIONS CAUTION )

Continued RCP operation without seal in3ecticn or seal cooling will cause i seal damage due to overheating.

3.1 Attempt to restore seal in]ection o,r seal cooling within 2 minutes, while continuing with this procedure.

3.2 M at least 1 RCP in each loop is unaffected, begin reducing reactor power at maximum rate, using Rapid Plant Shutdown (1203.045), to within limits of unaffected RCP combination.

! 3.3 g either seal injection o_r_ seal cooling cannot be restored within 2 minutes, perform the following:

NOTE

1. High power / pumps reactor trip setpoints are:

e One pu:r.p per locp - 155%

{

• O pumps in one loop - 30% i

.2. Tripping 1 RCP with reactor power >928 may result in reactor trip on high power /imoalance/ flow.

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3.3.1 M tripping the affected RCP(s) will result in reactor trip l on high power / pumps, perform the following:

A. Trip reactor.

B. Trip affected RCP(s).

C. While continuing with follow-up actions, refer to Emergency Operating Procedure (1202.XXX).

4 4

, ._ . . _ _ . _ . _ . . . . . . . - _ _ _ _ . m_. . _ . . _ . . . . . _ . . . _ . _ _ . _ . .. , . .-. __ __._ _ = _ . - . _ . _. _ ,_.

.JB PERFORMANCE MEASURE Page 6 of 6 j l

K&A 008 A3.02 3.2/3.2 -

Question: . Given ICW Pumps P33 A and P33C are running, if ICW Pump P33 A trips. What automatic actions occur?  :

Answer. ICW Pump P33E will auto start (10 see time delay), suction valve (CV 2240) and discharge l

. valve (CV-2238) will open.

Reference Annunciator Corrective Action 1203.012K Rev 31 page 13.  ;

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PROCJWORK PLAN NO. PROCEDUREJWORK PLAN TITLE: PAGE: 13 of 25 1203.031 REACTOR COOLANT PUMP AND MOTOR EMERGENCY REV: 13 CHANGE:

SECTICN 3 SIMULTANEOUS LOSS OF SEAL INJECTION AND SEAL COOLING FLOW (continued)

NOTE

1. If no RCPs are running, a second RCP snould be started ~30 seconds after Uie first RCP to prevent pump damage due to inadequate flow through the hydrostatic bearing and pump cavitation.

2. Example of upper cavity seal pressure between 20% and 65% of RCS pressure 431 psig to 1400 psig with RCS pressure 215% psig.

3. Example of lower cavity seal pressure between 40% and 80% of RCS pressure:

862 psig to 1724 psig with RCS pressure 2155 psig.

3.7.4 If the following conditions are met, restart RCP(s) as follows:

e Upper cavity seal pressure 20% and 65% of RCS pressure e

Lower cavity seal pressure 40% and 80% of RCS pressure Except in case of emergency, at least one RCP already running or two RCPs available for restart A. Place Seal Injection Flow Interlock Bypass switch for respective RCP(s) in BYPASS.

B. Start oil pumps for respective RCP(s).

C. Start RCP.

1. Iff only one RCP is running, start the second RCP

~30 seconds after the first RCP.

a. g second RCP cannot be started, except in case of emergency, trip running RCP.

D. Stop oil pumps for running RCP(s).

E. Return Seal Injection Flow Interlock Bypass switch (es) to NORMAL.

3.7.5 Monitor RCP and seal performance. Verify seal parameters return to normal.

3.7.6 y any of the following exceed nornal limits, stop RCP.

e Cavity pressure e Seal leakage

• Pump vibration i

l Page 1 of 6 JOB PERFORMANCE MEASURE l

UNIT: 1 REV # 2 DATE:

TUOI NUMBER: ANO-1-IPM-RO-ED009 SYSTEM / DUTY AREA: ELECTRICAL DISTRIBUTION  ;

TASK: jHIFT PLANT AUXILIARIES TO A STARTUP TRANSFORMER DURING A TUBE RUPTURE JTA#: 10625110101'  !

KA VALUE RO: 31 SRO: 3.1 KA

REFERENCE:

062 000 A4 07 ,

APPROVED FOR ADMINISTRATIONTO: RO: X SRO: X j

' TASK LOCATION: INSIDE CR- X OLTFSIDE CR: BOTH:

• SUGGESTED TESTING ENVIRONMENT AND MEniOD (PERFORM OR SIMULATE):

PLANT SITE: SIMULATOR: PERFORM LAB:

POSITIONEVALUATED: RO: SRO:

' ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB: '

TESTING MEDiOD: SIMULATE: PERFORM:

APPROXIMATE COMPLETION TIME IN MINUTES: 15 MINUTES REFERENCE (S): 1107.001 REV. 53. PC 2 1202.006 REV. 6 EXAMINEE'S NAhE: SSN - -

EVALUATOR'S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

I Stan Time Stop Time Total Time SIGNED DATE:

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE r",0CEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

i

Page 2 of 6 TUOI NUMBER: ANO-1-JPM-RO-ED009 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

The examiner shall review the " Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee. ,

JPM INITIAL TASK CONDITIONS: Plant is <50% power dunne a shutdown due to a tube tuoture m the "A" OTSG. Unit 2 is in a refueline outage and is utilizing SU2 for non-vital electrical loads to complete outage work on SU3 transformer. .

TASK STANDARD: Both EDGs supoMne their respective ES buses and separated from off-site power AND feeder breakers for SU2 to A1. A2. H1 and H2 are removed from P-T-L.

This is an Alternate Success Path JPM,  ;

TASK PERFORMANCE AIDS: 1107 001 and 1202 006 4

NOTE: recall an IC with powr <30%. After examinee begins this JPM open breaker B01:3, thefeeder breaker to Sul.

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Page 3 of 6 TUOI NUMBER: ANO-1-JPM-RO-ED009 INT 11ATING CUE:

The SS/CRS directs you to transfer plant auxilianes per step 9 B. of the Tube Rupture EOP 1202.006.

CRITICAL ELEhENTS (C): 5. 6 (C) PERFORMANCE CIECKLIST STANDARD N/A SAT UNSA l T

1. Vertfy stanup transformer #1 is Examinee noticed that B0125 is open and  ;

available for accepting plant loads. SUI transformeris determined to be i inoperable. )

NOTE: breaker B0123 will open causing l the negative cue to be used. j l

POSITIVE CUE:

breaker B0125 is closed and voltage is indicated for SUI transformer.

NEGATIVE CUE:

breaker B0125 is open and no voltage is indicated for SUI transformer.

NOTE: If dispatcher is called to close B0125, repon that B0125 cannot be closed at this time.

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2. Verify that SU2 transformer is Determined that Unit I could NOT ahgn available for transfer of all Unit I to transfer all loads since Unit 2 is using buses. SU2 for non-vitalloads.

NOTE: Use the negative cue.

POSITIVE CUE:

SU2 voltage is >157 KV. autotransformer is energized from 500 KV and aligned to SU2, no Unit 2 buses are aligned to SU2 and SU2 V Reg 3% reduction is disabled.

NEGATIVE CUE:

unit 2 non-vital buses are aligned to SU2.

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TUO! NUMBER: ANO-t JPM-RO-ED009 i

(C) PERFORMANCE CHECKLIST STANDARD N/A SAT- UNSA T

3. Verify non-vitalloads may be Decision to transfer non-sital loads to transferred to SU2 transformer. SU2 is made.

POSITIVE CUE:

Attachment E of 1107.001 is used to determine transfer of non-vital loads is allowable.

NEGATIVE CUE:

Attachment E is not used and determination cannot be made, i

4. Notify Unit 2 ofintent to transfer Unit 2 control room personnel told of  !

non-vitalloads to SU2. need for Unit I to transfer to SU2.

5. Place EDGs in service MR separate Estimated load calculated for each ES 4160Vvitalbuses A3 and A4 from bus and both EDGs supplying their  !

off-site power. respective bus, separated from off-site power.

(C) POSITIVE CUE:

Both EDGs operating and supplying their respective ES buses.

NEGATIVE CUE '

EDGs not supplying their respective ES buses. j i

6. Remove the SU2 feeder breakers for Feeder breakers for Al, A2, H1 and H2 )'

A1. A2, H1 and H2 from PULL-TO- are removed from PULL-TO-LOCK LOCK and allow to auto transfer position and are in the NORMAL-when the Reactoris tripped. AFTER-STOP position.

(C) POSITIVE CUE.

feeder breakers for Al, A2, Hi and H2 in NORMAL-AFTER-STOP position.

NEGATIVE CUE:

Al, A2, H1 and H2 feeder breakers in PULL-TO-LOCK.

I END

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l Page S of 6

.. i KAA 062 A1.013.4/3.8 ii Question: What are the reactive load limits for an Emergency Diesel Generator in parallel operation? .i Answer 400KVAR out and 100KVAR in.

- Reference . ' Emergency Diesel Generator Opention (!!04.036) Rev 37 PC 2 page 6. .

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toCJWORK PLAN NO. PROCEDURE / WORK PLAN mtE: l 0 AGE: 6 cf 160 1104.036 . EMERGENCY DIESEL GENERATOR OPERATION REV: 37 CHANGE:

5.2 Any visible tubing vibrations during DG surveillances, or, water, air, or oil leaks are to be promptly reported. Elevated leaks may allow oil system to draw in air when shut down, draining pipes.

4.3.li 5.3 Diesel run time unloaded or at low load (<756) should be minimized in order to prevent carbon fouling (improper combustion) and excessive turbocharger gear train wear.

5.4 During periods of known of f-site electrical grid disturbances, neither diesel should be paralleled with the grid. This will prevent a loss of the diesel generator from protective relay actuation such as overload or reverse power.

5.5 When both diesel generators are in operation, do not tie them to the grid simultaneously. One DG shall be dedicated only to its ES bus.

Otherwise a single grid electrical fault may cause a loss of both emergency diesel generators.

5.6 Governor booster pump tubing should be inspected for leaks during diesel run to prevent loss of governor-control oil pressure.

5.7 The Shift Superintendent shall be notified of any oil spill that has the potential of reaching Lake Dardanelle.

5.8 Do not attempt diesel generator restarts until engine has stopped (O RPM).

5.9 Either the AC or DC soak back pump (P-106A3 or P-106Al for DG1, P-106B3 or P-106B1 for DG2) must ce operational before operating the diesel and must continue to operate a minimum of 30 minutes after the diesel is shutdown to cool the turbocharger bearings.

5.10 In parallel operation, maximum allowed reactive load is 400 KVAR out '

and 100 KVAR in. l l

5.11 Maximum current: 450 amps. Do not exceed except in emergency. '

5.12 Maximum ambient temp for diesel operation is 122*F. Verify ventilation f_. operate to maintain ambient temp < maximum allowed. '

5.13 Maximum engine outlet water temperature is 205'F.

5.14 Minimum oil pressure is 35 psig when diesel is operating at 900 RPM.

5.15 Except for automatic starts and tests when opposite train components are inoperable, do not operate the diesel until all cylinders are cleared of water.

5.16 Do not operate the diesel unless service water is available for l cooling.

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KAA 062 A2.013.4/3.9 i

Question: During a tube rupture event, if SU#1 transformer is not available to load, how is transfer i

accomplished to SU#2 transformer?

. Answer: ~. Notify Unit 2 ofintent to transfer loads to SU2 transformer. i e Remove SU2 feeder breakers for buses A1, A2, Hl. and 112 from PULL-TO-LOCK position.  ;

e When reactor is tripped loads are allowed to auto-transfer to SU2 and load shed will -

occur. ,

Reference Tube Rupture EOP (1202.006) Rev 6 page 4 & 7,  ;

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i l 1202.006 TU3E RUPTURE ,

REV 6 PAGE 4 of 37 INSTRUCTIONS CONTINGENCY ACTIONS

9. Perform the following during power reduction

! (Refer to Power Operations (1102.004) and l Plant Shutdown and Cooldown (1102.010) if

( needed):

A. At 555%, stop Heater Drain pumps (P8A and B).

I I B. At 550%, transfer plant auxiliaries to B. IF_ SU1 is unavailable, j SU 1. THEN perform the following:

l l NOTE SU2 is considered available if pJil the following conditions are met. ,

e SU2 voltage 2:157KV l

• AUTO X-FMR energized from 500KV

!

• AUTO X-FMR aligned to SU2 l

• & Unit 2 buses eligned to SU2

• SU2 V REG 3% reduction disabled >

1) LF SU2 is available, THEN perform the following: i

. l a) Notify Unit 2 of intent to transfer tu SU2.

b) Remwe SU2 feeder breakers for buses A1, A2, H1, and H2 from PULL-TO-LOCK to allow auto transfer when Reactor is tripped.

[ Bus Bus Bus Bus 1 A1 A2 H1 H2 .,

A-111 A 211 H-13 H-23 l I

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19. CONTINUED ON NEXT PAGE) ,

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1202.006 TUBE RUPTURE ,

REV 6 PAGE 7 of 37 INSTRUCTIONS CONTINGENCY ACTIONS l

!- 10. WHEN Reactor Power has been reduced I below 12%,

. THEN perform the following

l A. Place Turbine'Controlin OPER AUTO or TURBINE MANUAL.

B. Reduce Turbine load to 20 to 30 MW. r C. Check TURB BYP valves controlling C. Operate TURB BYP valves in HAND to Header press 880 to 920 psig, meintain Header press 880 to 920 psig.

t

, D. Verify plant auxilians aligned to SU1. D, Perform the following:

NOTE l SU2 is considered available if gli the following conditions are met:

I

• SU2 voltage 2157KV e AUTO X-FMR energized from 500KV -

• AUTO X-FMR aligned to SU2 e N_q Unit 2 buses aligned to SU2

• SU2 V REG 3% reduction disabled

1) IE SU2 is available, THEN perform the following:

a) Notify Unit 2 of impending transfer to SU2.

b) Verify SU2 feeder breakers for buses A1, A2, H1, and H2 out of PULL-TO-LOCK.

Bus Bus Bus Bus A1 A2 H1 H2 A-111 A-211 H-13 H-23 NOTE l The following step will result in load shed of L buses A1. A2. H1. and H2.

l

! c) Trip the reactor l

AND l

GO TO step 25.

.(10.= CONTINUED ON NEXT PAGE)

.. . - , _ _ _ . . ~ . - . . ~ - - . . _ - . . - . . ~ . ~ . , - . -. . ,. - . ~ . _ .

i Page 1 of 6 L

r JOB PERFOPNANCE MEASURE t

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t UNZT 1 REV # DATE:

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i TUOI NUMBER: ANO-1-JPM-RO-RPS01 SYSTEM / DUTY AREA: REACTOR PROTECTION SYSTEM t TASK PLACE A CHANNEL OF RPS IN MANUAL BYPASS JTAN: 10125020101 ,

KA VALUE RO: 3.6 SRO: 3.6 KA

REFERENCE:

012 000 A4.03

?

APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:

• SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE: SIMULATOR: PERFORM LAB:

l POS8 TION EVALUATED: RO: SRO:

ACTUAL TESTING ENVIRONMENT: ' SIMULATOR: PLANT SITE:

LAB:

-TESTING METHOD: SIMULATE: PERFORM:

/ PROXIMATE COMPLETION TIME IN MINUTES: 5 MINUTES REFERENCE (S): 1105.001 REV. 16 PC 1 l

EXAMINEE'S NAME: SSN - -

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' EVALUATOR'S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY: UNSATISFACTORY:

-PERFORMANCE CHECKLIST COMMENTS:

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Start Time Stop Time Total Time

,'*IGNED DATE: -

.'JNATURE INDICATES.THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A l JALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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Page 2 of 6 TUO! NUMBER: ANO-1-JPM-RO-RPS01 dE EXAMINER.SHALL' REVIEW THE FOLLOWING WITH THE EXAMINEE:

f Tha Examiner shal review the " Briefing checklist -' system Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.

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JPM INITIAL TAKS CONDITIONS: The plant is operating at 100% power with all ICS stations in i automatic. A potential problem exists in the "A" RPS cabinet that could lead to a channel trip.

1

- TASK STANDARD: The "A" RPS cabinet is in Manual Bypass i I

i TASK PERFORMANCE AIDS: Simulator and 1105.001 and the Manual Bypass key.

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Page 3 of 6 l

l TUOI NUMBER: ANO-1-JPM-RO-RP501

.lITIATING CUE: )

The CRS directs you to place the "A" RPS channel in Manual Bypass. j

'CR8TICAL ELEMENTS (c): 5 I

l C PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT

1. Verify no other RPS channel is l Looked in the RPS cabinet l in manual bypass. in the back of the control '

room and verified no manual Note:-Due to the uniqueness of the (or channel) bypass lamps design in the simulator, all .

are lit or verified that  !

channel indications are located in K08D3, RPS Channel Bypass, one RPS cabinet. annunciator is clear.

POSITIVE CUE: no manual (or channel) bypass lamps are lit or K08D3 RPS Channel Bypass is clear.

2. Verify no EFIC Channel is in On the EFIC cabinets, Maintenance bypass that does not verified that no correspond to the RPS channel to " Maintenance" lamps are lit be placed in manual bypass. for any channel or verified that K12F7, EFIC CH Maint POSITIVE CUE: no " Maintenance" Bypa s s , annunciator clear.

lamps lit for EFIC cabinets or K12F7 EFIC CH Maint Bypass clear.

3. Place the SASS Rx Power input on C03, compared NI to ICS selector switch on C03 in indicators and deteomined the "Y" position. if the ICS needs to be placed in manual operation. l Note: If a difference exists Then selected the "Y"  ;

between compared values of >1%, the , input to ICS for Rx power. '

Diamond and Reactor Demand stations of ICS should be placed in Manual.

Note: if simulator and/or plant computer unavailable tell examinee that all four power range instruments indicate the same value.

POSITIVE CUE: "Y" position selected.

4. Obtain the RPS Manual Bypass From the key locker in the ke" from the SS. SS office or from the examiner, obtained the RPS POSITIVE CUE: give key to examinee. Manual Bypass key.

- - - . . .. . . . ~ _ _ . . . . - . .- . - ~ , _ _ . . . - - . . . . . . . . - . . - - . . - .

f Page 4 of 6 TUOI NUMBER: ANO-1-JPM-BO-BPS 01 i

C PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT

5. In the RPS cabinet, placed the In the RPS cabinet, l key switch for the appropriate inserted the key in the key i channel on tne selected Rx Trip switch in the "A" Reactor module to the bypassd position. Trip Module and placed the C switch in the bypass Notes'In the simulator at this time position.

l (5-7-96), the "A" RPS cabinet is I laid out as at the plant but is not l powered up. Therefore, the j

examiner will have to cue the examinee as lights change status, etc.

6. Verify the manual bypass lamps Verified the Manual Bypass on the Rx Trip module and the lamp on the Rx Trip Module indicating panel go on bright. went BRIGHT and the Manual Bypass lamp on the Note: The Rx Trip module lamp will indicating panel for "A" not illuminate, so the examinee RPS went BRIGHT. )

would have to point out the light.  !

POSITIVE CUE: manual bypass lamps on bright.

7. Verify Auxiliary Relay lamps Verified Auxiliary Relay for Manual' Bypass to EFIC and lamps for Manual. Bypass Manual Bypass to annunciator are to EPIC and Manual on bright. Bypass to annunciator are on bright.

NOTES located in-the left side of the RPS cabinent.

{

POSITIVE CUE: lamps on bright.

l-l- 8. Verify the associated EFIC On the EFIC cabinet, the  !

channel Maintenance light is " Maintenance" lamp for the l flashing. "A" EPIC channel is I verified to be flashing. l POSITIVE CUE: light is flashing. i

9. Verify the annunciator for RPS On K06, verified the i CHANNEL BYPASSED (K08-D3) is in annunciator is in alarm for alarm. RPS CHANNEL BYPASSED.

POSIT!VE CUE: K08D3 in alarm.

I END l

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U4 012 K4.06 3.2/3.5 l Quastion: If the "B" EFIC channel is in bypass and the "A" RPS channel bypass switch is placed in the bypass position what occurs? i Answer The "A" RPS channel will go to bypass and the "B" EFIC channel will be autcmatically removed f rom bypass even though it's key switch is in the '

bypass position.

R3ference NI & RPS Operating Procedure (1105.001) Rev 16 PC 1 page 11, 1

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PROC #/ORK PLAN NO. PROCEDURE / WORK PLAN TITLE: PA7E: 11 Cf 31 REV: 16 l 1105.001 NI & RPS OPERATING PROCEDURE CHANGE:

10.0 Placing a RPS Channel in Manual Bypass l l

NOTE l Only one RPS Channel may be placco in Manual Bypass at a time, j

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10.1 Determine which RPS Channel is to be placed in Manual Bypass and I verify no other RPS Channel in Manual Bypass.

i CUVUTION  !

Placing a RPS Channel in Manual Bypass will remove any noncorresponding EFIC Channel f rom Maintenance Bypass causing possible EFIC actuation.

l 10.2 Verify no EFIC Channel in Maintenance Bypass that does not correspond to the RPS Channel to be placed in Manual Bypass. J l

10.3 Place SASS Neutron Flux selector switch on C03 in the "X" or "Y" position as follows:

l 10.3.1 Compare Plant Computer point N1I56HI to N1I78HI.

A. If Plant Computer is not available, compare the highest of NI-5 and NI-6 to the highest of NI-7 and NI-8 on C03.

10.3.2 If the difference between the compared values is >1%, place' the Diamond and Rx Demand H/A stations in manual.

10.3.3 If placing RPS Channel "A" or "B" in Manual Bypass, place l l Neutron Flux selector switch to the "Y" position.

i 10.3.4 Ef Placing RPS Channel "C" or "D" in Manual Bypass, place l l Neutron Flux selector switch to the "X" position.

10.3.5 if ICS H/A stations were placed in manual for this step, stations may oe returned to auto per ICS Cperating Procecure UDP 1105.004), " Transferring ICS Control Stations to Auto" section.

10.4 Obtain the RPS Manual Bypass key from the Shift Superintencent.

10.5 Place key switch en the selected Rx Trip module to the bypass position and verify the following:

l 10.5.1 Manual Bypass lamps on the Rx Trip r.odule and indicating l panel go on bright.

I Page 6 of 6 -

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.EA 012 K2.01 3.3/3.7 .

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i Question: What'is the power supply for the "A" RPS channel cabinet?

i Answer: Panel RS-1 breaker 1.

(Breaker number not required for credit) 1 R2ference Inverter and 120V Vital AC Ditribution (1107.003) Rev 8 PC 4 Exhibit A page 135.

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PROCJWORK PLAN NO PfmCEDURE/ WORK PLAN Tm.E: I PAGE: '136of146 l l' 1107.003 . INVERTER AND 120V VITAL AC DISTRIHUTION m. 8 j CHANGE.-

l EXHIBIT A CP 1107.003 Exhibit A

-l PANEL RS1 REVISED 9/18/96 l ' Power Source: Inverter Y11 or_ Y15 l Location: Control room NOTE: All breakers-except spares should be closed.

l 3 "A" RPS Cabinet C41 2 ESAS Analog-1 Panel C88 i

.3 Spare 4 ESAS Digital-1 Panel C86 .

Reactor Building Pressure 5 CRD #1 C49 6 Transmitter PT-2400 to "A" RPS CV-7910 position indication C19 LPI/ Decay Heat Pump Brg. CLR E-50A Rad. Monitor Panel C24 i

7 Inlet CV-3840 and C18 Indication 8 Rad. Monitor Panel C25 Bay 1 1

9 NNI X C47 Normal Supply 10 Auxiliary Equipment Panel C486-1  :

H2 Analyzer C178  ;

11 SV-1840 - Hot Leg Sample Isol. 12 EFIC Channel A Panel C37-1  :

Instrument Cabinet C544 13 Panel C09 14 (ICS Room)

EFIC Trip Intertace Instrumentation l 15 Panels'C511 and C513 16 Cabinet C539 i Penetration Room Ventilation i 17 Panels C03 & C04 Indicator Power 18 Flow Switch C28 l 1

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Page 1 of 6 I

I JOB PERFORMANCE MEASURE ,

i UNIT: 1 REV # 0 DATE: .

TUOI NUMBER: ANO-1EJEM-RO-EOP20

• SYSTEM / DUTY AREA: EMERGENCY AND ABNORMAL OPERATIONS TASK: MANUALLY INITIATE FULL HIGH PRESSURE INJECTION (HPI)

JTAW: 10045850601 ,

KA VALUE RO: 4.4 SRO: 4.4 KA

REFERENCE:

006 030 A4.02 i

!- APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE: SIMULATOR: PERFORM LAB i

I POSITION EVALUATED: RO: SRO: ,

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:

TESTING METHOD: SIMULATE: PERFORM:

APPROXIMATE COMPLETION TIME IN MINUTES: 8 MINUTES  ;

. REFERENCE (S): 1202.012 REV. 3 PC 5 (RT 3) i EXAMINEE'S NAME: SSN - -

f EVALUATOR'S-NAME:

I >

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS '

CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

i Start Time Stop Time Total Time i

SIGNED DATE:

a SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A

UALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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Page 2 of 6 TUOI NUMBER: ANO-1-JPM-RO-EOP20

-THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

The examiner shall review the " Briefing Checklist - System Walkthrough" portion of  !

OP 1064.023 Attachment 6 with the examinee.

JPM INITIAL TASK CONDITIONS: Plant is at power, PZR level is at 195 inches and i

dropping due to a tube rupture. ,

TASK' STANDARD: Full HPI has been initiated as indicated by the following: two HPI pumps running, all eight HPI' block valves opened, one HPI recire valve closed (either CV-1300'or CV-1301), both BWST outlet valves open (CV-1407/CV-1408).

TASK PERFORMANCE AIDS: 1202.012 RT3 Simulator setup: Simulator at power with a tube rupture (-200 gpm, .5 tubes) present, PZR level is <200 inches. This JPN is written for P-36B as the Operating HPI pump powered from A4.

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( TUCI NUMBER: ANO-1-JPM-PO-EOP20 l

INITIATING CUE:

l The SS/CRS directs you to initiate full HPI per RT3.

CRITICAL ELEMENTS (C): 2, 5, 6, 8, 9 (C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT

1. Place RCP Seal INJ Block Placed CV-1206 in override

( CV-12 06) in OVRD. position as indicated by 1 amber OVRD light on C04 ON. I POSITIVE CUE: CV-1206 is in ,

override. l i

2. Open both BWST Outlets Opened CV-1407 (on C18) and l (CV-1407 and CV-1408). CV-1408 (C16).

(C)

POSITIVE CUE: red lights CN, green lights OFF for CV-1407/CV-1408.

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3. Verify OP or STBY HPI pump Verified that the operating i running. HPI pump (P-36B) is still l running on panel C16. l POSITIVE CUE: the Operating l HPI pump, P-36B, is running.

4. Verify HPI RECIRC valves Verified CV-1300 and CV-1301 open (CV-1300 and CV-1301). open on panels C16 and C18.

I POSITIVE CUE: red lights ON, i green lights OFF for CV-1300 l' and CV-1301.

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5. Start AUX Lube Oil pump Started P-64A on panel C18.

for ES HPI pump. j (C) i POSITIVE CUE: red light CN, green light OFF for P-64A. I l

6. Start ES HPI pump. Started P-36A cn panel C18.

(C) POSITIVE CUE: red light ON, green light OFF for P-36A. l

! 7. Stop AUX Lube Oil pump. Stopped P-64A en panel C18.

I POSITIVE CUE: green light ON, red light OFF for P-64A.

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Page 4 of 6

'TUOI NUMBER: ANO-1-JPM-RO-EOP20 i l

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8. Fully open all HPI Block' Fully opened the following valves. valves as indicated by red lights ON and green lights POSITIVE CUE: red lights ON, OFF:

(C) green lights OFF for the CV-1219, CV-1220, CV-1278, following valves: CV-1279 on panel C18 AND CV-CV-1219, CV-1220, CV-1278, 1227, CV-1228, CV-1284, CV-CV-1279 on panel C18 AND CV-' 1285 on panel C16.

1227,.CV-1228, CV-1284, CV-1285 on panel C16.

9. Close HPI RECIRC (CV-1300 CL; sed either CV-1300 or CV-or CV-1301). 1301 as indicated by' red light OFF/ green light ON POSITIVE CUE: green light ON, for valve operated by the red light OFF (for the valve Examinee.

(C) operated by the Examinee, either CV-1300 or CV-1301) NOTE: satisfactory even if and PZR level has started to Examinee closes both valves, rise.

NEGATIVE CUE PZR level is l dropping rapidly. I END i

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Page 3 of 6 K&A 004 K6.313.1/3.5 Question: Why is CV-1206 placed in the OVERRIDE (OVRD) position when initiating HPI?

Answer: To prevent CV-1206 from automatically closing on low flow.

(Due to HPI lowering seal injection flow -- this pert of answer NOT required).

Reference Makeup & Purification System operation (1104.002) Rev 50 PC 3 Section 6.0 page 13.

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PROC.! WORK PLAN NO. PROCEDURE / WORK PLAN TITLE: PA!E: 13 Cf 230 1104.002 MAKEUP & PURIFICATION SYSTEM OPERATION REV: 50 CHANGE:

.s.9 Total FCP seal flow icw alarmt 20 gpm o RCP'S Total Seal' Flow LO (ccmputer point P379 from FS-1239) 6.10 Total RCP seal low flow interlock: 22 gpm o RCP Seal Flow SW (FS-1240)

Automatically closes RCP Seal Injection Block (CV-1206) unless in OVRD.

6.11 Makeup Tank (T-4) high. level alarm: 86 in.

• RC Makeup Tank Level HI (LS-1247) 6.12 Makeup tank low level alarm: 55 in.

• RC Makeup Tank Level LO (LS-1249) 6.13 Makeup tank low level interlock: 18 in.

• . Makeup Tank Level SW (LS-1248)

Automatically opens Makeup Tank Gas Space Vent (CV-1257) and positions Letdown 3-Way Valve (CV-1248) to LETDOWN.

6.14 Makeup tank high pressure alarm: 90 psig

• RC Makeup Tank PRESS HI (PS-1255) 6.15 Makeup tank low pressure alarm: 10 psig o' RC Makeup Tank PRESS LO (PS-1256)

-6.16 Primary makeup pmnps low oil pressure alarm: 7 psig

• PRI Makeup Pump P-36A Oil ?RESS LO (PS-1291). Auto starts AUX Lube Oil Pump for P-36A (P-64A,.

PRI Makeup Pump P-36B Oil PRESS LO (PS-1292 or PS-1293).

Auto starts AUX Lube Oil Pump for P-36B (P-64B).

• PRI Makeup Pump P-36C 011 PRESS LO (PS-1294). Auto starts AUX Lube Oil Pump for P-36C (P-64C).

6.17 Makeup Filter (F-3A/F-38) high AP alarm: 25 psid

• PRI Make-up Filters AP HI (PDS-1247) 6.19 Makeup Pre-Filter 'F-25) high AP alarm: 25 psid MU SYS PREFLTR F25 SP MI 'PDIS-1400)

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Page 6 of 6 .;

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- K&A- 006 K6.03 3.6/3.9 i,

' Quesdon: -What is.the maximum flow through an HPI pump for emergency operation? '

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4 Answer; 525 gpm.

I  !

I Reference Makeup & Purification System operation (1104.002). Rev 50 PC 3 )

Section 5.0 Limits and Precautions page 9.

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PROCJWORK PLAN NO. I PROCEDURE / WORK PLA,; TITLE: PA2E: a af 230 1104.002 MAKEUP & PURIFICATION SYSTEM OPERAT80N REV: 50 CHANGE:

! t 4  ;

4.2.20 Makeup anc Purific2 tion System Integrity Test and Leak Rate Determination (1305.003) 4.2.21 Control of Infrequently Performec Tests or Evolutions (1000.143) 4.3 NRC CCMMITMENTS i

, 4.3.1 P 1699, NRC Bulletin 88-11 Pressurizer Surge Line Thermal i Stratification. Contained in Supplemrat 7 Initial  !

Conditions.

4.3.2 P 309 and P 310, IST Program Procedure Changes Required for ,

l GL 89-04. Contained in Supplements 3, 4, 5, 7, & 8.

l 4.3.3 P 8221 Use of Temporary Test Gauges for Testing. Conte.ined i i in Supplements 3, 4, & 5.

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4.3.4 P 9947, Low Temperature Overpressurization. Contained in Supplement 8.

4.3.5 P 7, Leak Testing HPI Valves limit of 200 psi rise in one minute. Contained in Supplements 1 and 2.

i 4.3.6 P 2882, Monitor HPI Pump for oil leakage during normal starts and steps. Contained in " System Startup, System

! Shutdown, and Makeup Pump Operatiu.'." sections.

I' 4.3.7 A 11934, only one Train of HPI System will be tested at a t

time. Contained in " Limits and Precautions" section.

4.3.8 P 15000, Initiate a Condition Report if HPI check valve backleakage test indicates a 200 psi rise in one minute. I i i 4.3.9 P 15647 Closure Testing of BW-2 and BW-3, contained in  !

Supplements 3 and 5.

3 5.0 LIMIT 11 AND PRECAU'JIONS 5.1 Do not s';a r t or continue to run a Makeup Pump (P-36A, B or C) with the a

RCS in a solid wacer condition except as directed by emergency procedures.

5.2 Maintain Makeup Tank (T-4) pressure above 10 psig.

5.3 Restricting flow through an operating Makeup Pump (P-36A, P-36B or P-36C) to <55 gpm can cause pump damage. Acccunting for instrument accuracy, HPI flow should not be throttled to <100 gpm total HPI pump flow with recire valve closed.

5.4 Maximum flow through a makeup pump is 500 gpm for normal operation.

5.5 Maximum flow througn a makeup pump is 525 gpm for emergency operation.

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ADMINISTRATIVE SECTION TEST #1 RO ADMINISTRATIVE OUESTION Page 1 of 8 Operating Test 1 RO Subject A1 (Open Reference)

QUESTION Al-1:

Reference:

K&A 2.1.3 3.0/3.4 What off-going shiA individuals are required to review and sign the Shia Relief Sheet 200*F and Above (1015.015A)?

ANSWER: ShiA Superintendent ShiA Engineer Control Room Supenisor Control Room Supenisor Admin (if manned)

CBO Turbine CBO Reactor

REFERENCE:

' Unit One Operations Forms (1015.-15) Rev 24 PC2 Form 1014.015A page 7.

COMMENTS:

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I Page 7 cf 50 Page 4 of 4 l CIRCLE INITIALS Cencitional Surve111ances-

1. Has reactor power level changed by more than 10% within YES NO [

the last 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />?

g YES, NI cal is required daily during non-steady state power operation. Unless already performed, enter "NI Cal due no later than (time and date)" in Evolutions Scheduled section of this form.

Otherwise N/A.

Reference:

1304.032, T.S. Table 4.1-1, item 3 1

2. Has R.B. Personnel Hatch or Emergency Escape hatch been opened this day or I is LLRT on R.B. Personnel or Emergency Escape Hatch pending? YES NO l M YES, LLRT is required. Unless already performed, enter "LLRT due no later than (time and date)" in Evolutions Scheduled section of this form. Otherwise N/A.

Reference:

1304.020, T.S. 4.4.1.2.5 and 6.8.4

3. Has there been a makeup to the SF Pool, BAAT, BWST, NaOH tank or either Core Flood Tank? . . . . . . . . . . . . . . . . . .YES NO M YES, a chemistry sample is required. Unless already performed, verify Nuclear Chemistry has been notified and enter in evolutions scheduled section of this form. Otherwise N/A.

Reference:

T.S. Table 4.1-3

4. Are there any other conditions requiring special surveillances,

. such as additional diesel generator testing due to inoperable equipment, grab samples due to failed radiation monitors, etc.?

. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . YES NO If YES, list the required surveillance, due date and time below.

l. Otherwise leave blank.

S U RVE! *.*.AN C E DUE BY OFF-GOING EIFT SIGNATURES S/S l

SE CRS

'N/A if not manned, ;RS Acmin

30 Turbine 230 Feacter FORM TIT,E FORM NO REV.

SHIFT RELIEF SHEtiT - 200*F AND ABOVE (UNIT 1) 1015.015A 24

ADMINISTRATIVE SECTION TEST #1 RO ADMINISTRATIVE OUESTION Page 2 of 8 EXAMINEES COPY QUESTION Al-1:(Closed Reference)

What off-going shiA individuals are required to review and sign the ShiA Relief Sheet 200*F and Above (1015.015A)?

- . . . - ._ . .- ~ ~ . - - . - - .- .-

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! ADMINISTRATIVE SECTION TEST #1 RO l ADMINISTRATIVE OUESTION Page 3 of 8 Operating Test 1 RO Subject Al (Open Reference) t

! QUESTION A12:

Reference:

K&A 2.1.14 2.10/3.0

! Plant / Safety System State Joard entries should be brief and as a minimum contain what information?

I ANSWER: Component name/ number l Component status (isolated, bypassed, etc)

Associated LCO time clock if applicable ,

ti Date and time of occurrence i laitials of person making entry -

REFERENCE:

' Conduct of Operations (1015.001) Rev 50 PC 2 page 40.

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PROCJWORK PLAN NO. PROCEDUREJWORK PLAN TTTLE: PAGE: 40 of 55 1015.001 CONDUCT OF OPERATIONS REM: 50

)

CHANGE:

1 12.5 Status boards for Waste Control Operators and Auxiliary Operators may serve the function of a Shift Relief Sheet for these positions.

12.6 Status boards should have entries made whenever special operating consideration must be given a specific system or component related to l the watch station.

l 12.7 Entries on Plant / Safety System Status Board should be brief, but  !

contain all of the following:

• Component name/ number l NOTE Exceeding LCO time clocks requires the initiation of a Condition Report which will address any actions necessary at end of time clock. l l

• Component status (isolated, bypassed, etc.) and associated LCO time clock if applicable

• Date and Time of occurrence

• Initials of person making the entry 12.8 When a failed, bypassed, or misaligned component shown on a status l board or listed in the Component Out of Position Log is restored to '

its normal condition, the status board entry shall be removed or the Component Out of Position Log entry shall be updated.

13.0 ANNUNCIATOR MONITORING AND RESPONSE 13.1 When conditions result in actuation of the annunciator system, the  ;

alarm shot be promptly investigated and corrective action taken to clear the 4Aarm.

1 e When available, related instrument readouts and status lamps located on the control panels may be used to facilitate a quick l l check of the alarming conditioc.

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• Some alarms require local investigation and subsequent corrective action l 13.2 Conditions or alarms which repeatedly occur or which cannot be cleared

shall be brought to the attention of the Shift Superintendent.

13.3 If an alarming condition is considered t o be significant from the standpoint of plant safety or continued unit operation, it shall be logged in the respective unit's Station Log along with a description of the corrective action taken.

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l ADMINISTRATIVE SECTION TEST 01 RO ADMINISTRATIVE OUESTION Page 4 of 8 l

j EXAMINEES COPY l

Operating Test ! RO (Open Reference) i^

'. QUESTION Al-2:  ;

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Piant/ Safety System Status Board entries should be brief and as a minimum contain what information?

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ADMINISTRATIVE SECTION TEST 01 RO

{

ADMINISTRATIVE OUESTION j Page 5 of 8 )

Operaung Test i RO Subject A3 (Closed Reference) l QUESTION A31;

Reference:

K&A 2.3.1 2.6/3.0  :

What is the Federal Limit for Occupational Whole Body (TEDE) exposure?

ANSWER: 5.0 Rems per calendar year

REFERENCE:

Exposure Limits and Control (10!2.021) Rev 4 page 5.

COMMENTS:

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PROCJWORK PLAN NO. PROCEDURE / WORK PLAN TITLE: PAGE: 5cf18 ,

1012.021 EXPOSURE LIMITS AND CONTROLS REV: 4 CHANGE:

5.0 RESPCNSIBILITY AND AUTHORITY 5.1 MANAGER, PADIATION PROTECTION and CHEMISTRY has overall responsibility  ;

for the implementation of the requirements of this proceoure.

5.2 RADIATION PROTECTION DEPARTMENT SUPERVISORS are responsible for the i day to day implemectation of this procedure.

5.3 RADIATION PROTECTION DEPARTMENT PERSONNEL are expected to be knowledgeable in the requirements of this procedure and incorporate these requirements into the performance of their assigned duties.

6.0 INSTRUCTIONS 1

6.1 FEDERAL LIMITS 6.1.1 Radiation Worker A. Occupational

! 1. Whole body (TEDE) - 5.0 rems / calendar year

2. Single organ (TODE) - 50.0 rems / calendar year l 3. Lens of the eye (LDE) - 15.0 ;tms/ calendar year l

l 4. Skin of whole body (SDE) - 50.0 rems / calendar year

5. Extremities (SDE) - 50.0 rems / calendar year B. Planned Special Exposures (PSEs) i 1. Dose assessed due to a PSE is in addition to the l annual occupational dese. j

2. Annual

a. Whole body (TEDE) - 5.0 rems

b. Single organ (TODE) - 50.0 rems

c. Lens of the eye (LDE) - 15.0 rems

d. Skin of whole body (SDE) - 50.0 rems j

e. Extremities (SDE) - 50.0 rems l

3. Lifetime l a. Whole body (TEDE) - 25.0 rems

! b. Single organ (TODE) .- 250.0 rems

c. Lens of the eye (LDE) - 75.0 rems

d. Skin of wnole body (SDE) - 250.0 rems l- e. Extremities (SDE) - 250.0 rems o

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ADMINISTRATIVE SECTION TESTcl RO ADMINISTRATIVE OUESTION

1. E' EXAMINEES COPY Operaung Test 1 RO (Closed Reference)

QUESTION A3-1 What is the Federal Limit for Occupational Whole Body (TEDE) exposure?

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ADMINISTRATIVE SECTION TEST #1 RO ADMINISTRATIVE OUESTION '

Page 7 of 8 Operating Test 1 RO Subject A3 (Open Reference) >

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- QUESTION A3 2:

Reference:

K&A 2.3.11 2.7/3.2 l l

What Unit i ventilation systems are momtored by SPING monitors?

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l ANSWER: Unit One Containment Purge SPINGl i Unit One Radwaste Area SPINO 2 1 Unit One Spent Fuel SPING3 '

Unit Penetration Room Exhaust . SPING4

REFERENCE:

System Training Manual 1-62 Rev 2 page 23 COMMENTS:

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l Rcdicti:n Manitaring STM-1-62 REV. 2 The meteorological data is obtamed from the MET Tower l located on the cast side of the access road north of the intake canal.

Data collected consist of 10 meter wind speed and direction,57 meter l_ wind speed and direcuan,10 meter air i ..gr = Lire, difference in 10 meter and 57 meter temperatures,10 meter dew point t-.pcs re and standard deviation of wind direction. The data can be obtamed on the Plant Ca===aae, RDACS, or chart recorders in the back of Unit 1 Control Room .

l A Control Room ar==iacintar, "RDACS RADIATION HI" is located on K10-A1. The purpose of this alarm is to warn the operator i

of a nood to monnor RDACS more closely. The alarm is activated v/. ; w;r a E gy Action Iml (EAL) Report is .c 4,

<v=====umrian is lost to any SPING for 10 minutes, caninninicanna l is lost between 'A' and 'B' file servers for 10 mmutes, or

' comn==nc=tian lost between' SPDS and the file servers for 10 minutes. '

SPING's ma-mar the followng release paths:

1. 1 SPING - Unit I raar=====r Purse Exhaust (VEF-15)

! #2 SPING - Unit 1 Radwaste Area Fvhmum (VEF-8A/B) l #3 SPING - Unit 1 Spent Fuel Area Exhaust (VEF-14A/B) ,

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1. 4 SPING - Unit 1 Penetration Room Exhaust (VEF-38A/B)  !

! #5 SPING - Unit 2 Canr===nent Purge Fvhane (2VEF-15) l #6 SPING - Unit 2 Radwaste Area Fvhann (2VEF-8A/B) l #7 SPING - Unit 2 Spast Fuel Area Fvhane (2VEF-14A/B)

1. 8 SPING - Unit 2 Penetration Room Exhaust (2VEF-38A/B) l #9 SPING - PASS Buildmg Fvhane (2VEF-73)

1. 10 SPING - Aux hary Buildag Extension Fvhanet (2VEF-51 A/B) l # 11 SPING - Low Imel Radwaste Buildmg Exhaust (2VEF-81)

Each SPING monitor is a selfenarminad rmcroprocessor based rarhatian detection system for monitoring particulate, iodine and noble gases in the ventdation system momtored. (Figure 62.26) The l programs that control the system are stored in READ-ONLY Memory

! (ROM) and, therefore, are fixed and only numerical operatmg parameters can be varied. The system performs the tasks of data  ;

acquisition, history file management, operational status check and l alarm determmation. This mformation'is sent to each of the file  !

servers used for dose assessment and personal computers used for  !

dose assessment in both Control Rooms. The operability of SPING is i h.. c4 by the (%=iery Department using OP 1604.051

- I (Eberline R mehntion Monitoring System).  !

The Unit i SPING units are located on skids on the 404' elevation of the Auxthary Building by the Boric Acid Add tank.  !

Each SPING unit has an associated area radiation Geiger-Mueller detector that provides a measure of the gamma field in the area of the SPING. This activity level can be monitored on SPING Channel 6. Another gamma Geiger-Mueller detector is installed to determme the background activity and was designed to compensate the particulate and noble gas for background activity. At the present

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ADMINISTRATIVE SECTION TEST #1 RO ADMINISTRATIVE OUESTION Page 8 of 8 i EXAMINEES COPY -

Operating Test 1 (Open Reference) ' l QUESTION A3 2:

What Unit I ventilation systems are monitored by SPING monitors?

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ADMINISTRATIVE SECTION TESTC1 RO ADMINISTRATIVE JPM Page 1 of 3 -

Operating Test 1 RO Al (JPM-1)

Reference:

K&A 2.1.2 3.0/4.0 i

Initiating cue:  ;

Utilizing the Plant Monitoring Computer (PMS), calculate current RCS leakrate over a 10 minute time period.

i

Reference:

RCS Leak Detection (1103.013) Rev 17 PC 2 Supplement I pages 45-52.

Standard:

Use any PMS console and perfom RCSLKRTI.

If PMS is unavailable perform 1103.013 Supplement I and calculate RCS leakage il gpm.  !

COMMENTS:

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PROCJWORK PLAN NO. PROCEDURE /WOPW PLAN TTTLE: PA7E: 45 cf 69 1103.013 RCS LEAK DETECTION REV: 17 CHANGE:

SUPPLEMENT 1 Page 3 of 11 2.0 TEST METHOD 2.1 RCS Leak Rate Determination NOTE l Plant Computer program "LKRTl", option 1, is the preferred source of Total RCS Losses.

2.1.1 If available, after at least an hour of stable RCS conditions, but preferably 6 or 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />, obtain Total RCS Leakrate from Plant Computer program "LKRT1", option 1, and N/A steps 2.1.2 through 2.1.9. Otherwise N/A i

2.1.2 Enter initial data required in Table 2.1.1,

" Total Leakage Data Table." Check (/) data l source used:

Pressurirer Level (/) T-ave (/)

i Preferred: L1001B Preferred: XTAVE I

Backup: L1002B Backup: SPDS TAVRCl SPDS LPZRIG Controlling T-ave SPDS LPZRlR Indicator (TI-1032)

PZR Level (LIS-1002)

Makeup Tank Level (/) Reactor Power (/)

Preferred: L1248 Preferred: XPP Bacxup: SPDS L1248 Backup: .SPDS NIlLP Level Recorcer for .SPDS NI2LP MU Tank (LR-1248) Power Range Indicators (NI-5, NI-6, NI-7, NI-8) t i  !

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P

( . - < . , . , . . ._..

m , v,

..__,._ _ ...._ __ _ _ _ _ .-_.- _ .-_......_ _ ..~._. _ _. _._ ,._ _ _ - - -

l' PROCJWORK PLAN tm.- l PROCEDURE / WORK PLAN Tm.E: #a ofgg 1 l PAGE:

1103.013 RCS LEAK DETECTION REV: 17' CHANGE:

[

i SUPPLEMENT 1 '

l Page 4 of 11 2.1.3 When following applicaole conditions have been '

met, enter FINAL cata in Table 2.1.1, l A. Leak rate determination has run for >l hour.

B. Pressuri:er level, T-ave, and Rx power  ;

values are approximatelv equal to initial values.

1 Table 2.1.1 Total Losses Data Table -f i

Start Stop f l' Date/ Time: Date/ Time: AT = liin.

1' CONVERSION EQUIVALENT VARIABLE. INITIAL FINAL CHANGE FACTOR LOSS (GAL) ,

Pressurizer Level ( "H,0 ) ( )-( ) =

(+12.40)

TAV f*F) ( l-( ) =

(-102.44)'

l MU Tanx ,

Level ' " H ,0 ) . ( l-( l= (+30.06) j Reactor 1 Power (%) (. )-( ) =

(- 9.15 ) <

l- Reactor Power Souared (P ) 2 ( )-( ) =

(+0.083) 5 l

t l TOTAL LOSSES i

2.1.4 Compute INITIAL and FINAL "Peactor Power i Squared" values'and enter in Table 2.1.1.

. '. 5 Calculate CHANGE in eacn variable anc enter in

~able 2.1... I 1

l 2.. 6 Multiply CHANGE values by CONVERSION FACTOR anc enter under EQUIVALENT LOSS in Table 2.1.1.

2.'.7 Add EQUIVALENT LOSS values algebraically to determine TOTAL LOSSES and enter in Table 2.1.l.

2.1.9 Determine test AT in minutes and enter in Table

2. 1. 1.

2.~.9 Find total RCS : 3 ei as follows:

TOTAL LOSSES ca.lons) = total RCS ( gpm)

AT I minutes) losses l

1 PROCJWORK PLAN NO. PROCEDUREJWORM PLAN TTTLE:

l PAGE: 47 Cf 69 1103.013 RCS LEAK DETECTION REV: 17 CHANGE:

SUPPLEMENT 1 Page 5 of 11 2.1.10 Enter total RCS losses value in section 3.0 and on Form 1103.013A.

2.1.11 I_f desired, verify Plant Computer Tabular Log "RCS Leakrate Data" deactivated.

l(4.3.el 2.1.12 Obtain quench tank fill rate as follows:

NOTE Pumping quench tank or adding condensate for cooling during the fill rate determination period invalidates the fill rate determination.

A. Verify quench tank has not been pumped and condensate has not been added to quench tank during the quench tank fill rate determination period.

l B. Record quench tank final volume, stop time, T-lll running timer and the last valid T-111 fill rate from RCP Drinking Bird Log in table 2.1.2.

Table 2.1.2 Quench Tank Data Table Start Stop Date/ Time: Date/ Time: AT = min.

l T-111 running timer last valid j i nitial min. final min. T-111 fill rate gpm

{ Quenen Tank Volume Final Initial

- i ) =

gal C. Calculate the correction to account for water in T-111 as follows:

l NOTE The following calculation will result in a negative number if the initial timer is greater than the final.

1. Subtract the initial T-111 timer from the final T-111 timer and multiply this number by the T-111 fill rate:

final initial fillrate Correction = !( )-( ) X ( ) = gal

PROCJWORK Pt.AN NO. PROCEDURElWORK PLAN TITLE: PA E: 48 cf 69 1103.013 RCS LEAK DETECTION RB/: 17 l CHANGE: l l

l SUPPLEMENT *

! Page 6 of 11 l D. Calculate quench tank fill rate as follows:

1. Add Quench tank gallons and T-111 correction gallons algebraically and

divide this number by the AT from table 2.1.2.

Quench T-111 Quench tank tank Correction AT Fill Rate =

(( ) gal + ( ) gal) - ( ) min = gpm E. Record Quench Tank fill rate in Section 3.0 and on Form 1103.013A.

2.1.13 If total RCS losses exceed 10 gpm, determine non-returnable leak rate as follows, otherwise N/A here and in Section 3.0.

Total RCS Quench Tank Non-returnable Losses Fill Rate Leak Rate = ( ) -

( ) = gpm A. Record non-returnable leak rate in Section 3.0.

2.1.14 Obtain known leakage from the following f source (s) and enter in Table 2.1.3 as i applicable:

CJLUTION Use quench tank fill rate or RCP seal leak rate but not both.

I A. Quenen tank fill rate. Use only ii RCP seal leakage is not used.

B. RCP seal leak rate from RCP Drinking Bird Log (CPS-A9), T-111 or drinking birds.

Use only if quench tank fill rate is not used.

l l

l

PROCAVORK PLAN NO. PROCEDURFJWORK PLAN Tm.E: PAGE: 49 Cf 69 1103.013 RCS LEAK DETECTION W: 17 CHANGE:

SUPPLEMENT 1 Page 7 of 11 C. Identified leakage sources from "RCS Leak Test", Supplement 5 to Plant Preheatup and Precritical checklist (1102.001), performed during most recent plant startup. Do not use leakages <0.01 gpm.

D. Leakage sources >0.01 apm which have been identified since the last plant startup and evaluated per Supplement 3 to this procedure.

Table 2.1.3 Known Leakage Data Table LOCATION MEASURED RATE Quench tank till rate (N/A if not used)

(qpm)

RCP seal leax rate (N/A li quenen tank 1111 rate used). T-111 or drinkinc birds (circle one) (gpm)

Other source (s) (explain)

(gpm)

(gpm)

TOTAL KNOWN LEAK RATE: (gpm) 2.1.15 Add MEASURED RATE values to determine TOTAL KNOWN LEAK RATE and enter in Table 2.1.3.

2.1.16 Find unidentified leak rate as follows:

Total RCS losses (section 3.0) ( gpm)

Minus TOTAL KNOWN LEAK RATE ' Table 2.1. 3 ) - - ' gpmi Unicentifiec leax rate i gpm) 2.~.17 Enter unidentifiec leak rate in section 3.0.

f

a PROCJWORK PLAN NO. I PROCEDURE / WORK PLAN TTTLE: PA7E: 50 cf 69 1103.013 RCS LILAK DETECTN)N REV: 17 l CHANGE: gg,;

1 SUPPLEMENT 1  !

Page 8 of 11 ,

l 2.2 RB Sump Fill Rate Determination  ;

NCdMCS

1. To prevent masking a rise in RB Sump fill rate, RB Sump Initial and Final ]

-levelz should be the-current values taken from SPDS Ll405 at the start and i stop times. i I

...2. Draining the RB Sump during fill rate determination period invalidates the l

fill rate determination. f 3.' Actual RB Sump volume change based on' level is: l e 22.3 gal /% below 8% l 7 e 26' gal /% from 8% to 48%  ;

](

• 30.6 gal /% from 48% to 76%

l Due to this variance, 31 gal /% is used for fill rate calculations to -)

ensure conservatism. '

l 2.2.1 Record RB sump final level and stop time in Table 2.2.1, "RB Sump Level Data Table" and 1 calculate "AT" and " Level Change." '

Table 2.2.1 RB Sump Level Data Table l Start- Stop

'Date/ Time: Date/ Time: AT= Min.

VARIABLE FINAL INITIAL CHANGE CONVERSION LEVEL i  %  % FACTOR CHANGE (GAL)'  ;

'N RB

( I "

kl Sumo Level I ~ I 31 2.2.2 Find RB sump fill rate as follows

LEVEL CHANGE i callons = RB sump. fill rate ( gpm)

AT ( minutes) 2.2.3 Enter RB sump fill rate in section 3.0.

! -2.3 RB Air Monitor Reading Evaluation .

1 2.3.1 From the previous day's Unit 1 WCO Logsheet (OPS-A3), record the highest valid reading

[ observed for the following in section 3.0 and on  ;

Form 1103.013A: l A. RB ATMOS Particulate Monitor (RI-7460)

B. RB ATMOS Gaseous Monitor (RI-7461) 1 2.4 11 this s a daily leak rate determination, perform steps ,

l 2.5 thru 2.12. '

ij this as not a daily leak rate determination, N/A steps 4

2.4.thru 2.12.

~

l l

l i

PROCJWORK PLAN NO. PROCEDURE / WORK PLAN TTTLE: grAGE: 51 ef 69 1103.013 RCS LEAK DETECTION REV: 17 CHANGE:

SUPPLEMENT 1 Page 9 of 11 NOTE Unidentified RCS leak rate and RB sump till rate 5-day averages are from the previous 5 days and do not include the data from this leak rate.

.2.5 Calculate unidentified RCS leak rate 5-day average from Form 1103.013A:

gpm 2.5.1 Record unidentified RCS leak rate 5-day average on Form 1103.013A. 1 2.6 Record unidentified RCS leak rate on Form 1103.013A.

2.7 g any of the following conditions are met, record in  !

station log and begin RCS Leakage Investigation per Attachment A of this procedure, otherwise N/A:

1 2.7.1 RCS unidentified leak rate increases above the '

5-day average by >0.2 gpm and RB sump fill rate  !

coincidentally increases by >0.2 gpm.

l 1

2.7.2 RCS unidentified leak rate increases above the l 5-day average by >0.5 gpm.

{

2.7.3 RCS unidentified leak rate exceeds 1 gpm.

2.8 Calculate RB Sump fill rate 5-day average from Form 1103.013A:

gpm 2.8.1 Record RB Sump fill rate 5-day average on Form 1103.013A.

2.3 Record RB Sump Fill Rate on Form 1103.013A. l ta a n 2.10 g RB sump fill rate increased above the 5-day average by

>0.1 gym, perform the following. Otherwise, N/A.

2.10.1 Notify Nuclear Chemistry to obtain RB sump  !

sample in an effort to determine the source of the increased fill rate. j 2.10.2 g sample results indicate source of increased fill rate is from service water, initiate steps to perform RB entry to inspect accessible areas.

l

. - - . . . . . -~ _ . . . . - . - - . - - . . - ..._ . - - _ ... . ..

l PROCJWORK PLAN NO. PROCEDURE / WORK PLAN TmJE: PAGE: 52 of 69 1103.013 RCS LEAK DETECTION REV: 17 CHANGE:

l l

SUPPLEMENT 1 1

Page 10 of 11 2.11 Review.all calculations entered in this supplement and on Form 1103.013A and verify correct.

]

Reviewed and verified by (SRO) Date 2.12 Record and review required trend data.

. Recorded.and reviewed by (SE/SRO) Date 2.12.1 If available, attach copies of graphs.

Otherwise N/A.

i

~ I

-3.0 ACCEPTANCE CRITERIA  !

l l

3.1 Record values observed during leak rate determination and '

compare with " Limiting Range For Operability". l i

' TEST, MEASURED LIMITING RANGE IS DATA WITHIN. )

LIMITING RANGE 7 QUANTITY INSTRUMENT VALUES FOR OPERABILITY (YES, NO, OR N/A) ,

Total RCS Losses N/A GPM <30 GPM YES NO Unidentified Lsak Rate M/A GPM <1 GPM YES NO Ncnreturnable LSek Rate N/A GPM <10 GPM YES N/A NO RB Sump Fill' Rate N/A GPM N/A N/A RI-7460 Daily Hich RI-7460 CPM N/A N/A RI-7461 Daily Mich RI-7461 CPM N/A N/A Quenen Tanr, j

Fill Pate N/A GPM N/A N/A  !

3 . ~,.

f "NO" is circled in above table or.chere is any leakage evaluated as unsafe, or non-isolable leakage from a reactor coolant system strength boundary, immediately notify the Shift Superintendent and write a Condition Report.

Performed by Operator Date/ Time -

Operator Date/ Time SRO Date/ Time Date/ Time l Step 2.12.1 performed by i

. - _ . . . _ - _ . - . . . - . . . . - . . .. -. -.. . .. -~ . . . _ ~ . . . _ _ . . . . . . _ -

1 I

ADMINISTRATIVE SECTION TEST 01 RO l ADMINISTRATIVE JPM  ;

Page 2 of 3 i Operating Test 1 RO A2 (JPM 2)

HOLD CARD Authorization Form (1000.27A) completed with missing craft signature authorizing release, missing Authorization Removal signature, and no removal sequence specified.  !

l

Reference:

KAA 2.2.13 3.6/3.8 l I

i Initiating cue, l

CRS directs you to remove hold cards using the attached Hold Card Authorization Form (1000.027A). l

Reference:

Hold and Caution Card Control (1000.027) Rev 24 PC 2 pages 22-23 ,

I l

Standar1 Review of form 1000.027A reveals incomplete emit signatures, no removal authorizatio% signature and no removal sequence specified.

1 I

i COMMENTS:

l

).

l

, , __J

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

raoc./wcom P:n No. PROC 3 DURA / WORK PIM T!r1.s: PAgg: 22 of 56 100C.J27 HOLD AND CAU'I.ON CARD CONTROL REY: 24 ,

CHAN!s;

'2.4

. The CRS en the affected Units shall verify the following:

(3.3,s) e Required Released By signatures obtained.

• Appropriate removal position and sequence.

• Appropriate determination of restoration verification requirement.

• If a bus was hold carded for breaker PMs, then Electrical Bus Hold Card Authorization Addendum complete.

12.5 When satisfied the tagout is ready to be cleared, then the CRS will sign the Hold Card Authorization Form.

13 HOLD CARD REMOVAL / RESTORATION 13.1 An OPERATOR shall perform the following:

13.1.1. Verify all required signatures obtained on 1000.027A.

13.1.2. Verify there are no personal identification tags or padlocks on the component. Contact maintenance as necessary.

g 13.1.3. Remove the Hold Cards and align conponents in the proper sequence as designated on the Hold Card Record Sheet.

13.1.4. Verify any motor-operated valve that was manually seated is restored per Valve Operations (1015.035).

13.1.5. Initial the Removed By blanks on the Hold Card Record Sheet.

This may be initialed Per-Telecon per Section 18.

13.1.6. Update C 'egory E Log Book for any Category E valves returned j to Locks Jtatus per Valve Operations (1015.035).  !

(3331 13.2 If required, then a VERIFIER shall perform an INDEPENDENT VERIFICATION /

VERIFICATION of required components as follows: I 13.2.1. Verify proper restoration by comparing required position on l tne Hold Card Record Sheet with-actual position of component.

13.2.2. :nitial the Verified By blanks on the Hold Card Record Sheet.

This may be initialed Per-Telecon per Section 18.

13.2.3. Verify Category E valves returned to Locked Status and update Category E Log Book per valve Operations (1015.035).

13.3 AN OPERATOR will:

13.3.1. Review the Hold Card Authorization Form and Hold Card Record Sheet for completeness.

13.3.2. Verify the Hold Card Index is updated.

i

. . ,_ - ~ . -. .-=- - .. - - - - . _ - - - . - . - .- -

Proc./WQkK PIAN No. PnoCEDUp.E/ WORK PLAN TIr1.E. Paas: 23 of 56 l 1000.027 HOLD AND CAUTION CARD CONTROL REY: 24 l QuMGE:

l 14 T*JPJIO'.'IR OF ACCEPTANCE FFCM CNE CRAFTSMAN TO ANOTHER l

14.1 f it is necessary for one Craftsman to relinquish lead responsibility i to another Craftsman, then both Craftsmen shall report to the Control 1 Room (either together or separately) and sign the appropriate blank on l the Hold Card Author 1:ation Form. '

l 14.2 An Operator shall fill in the required information for the new Lead Craftsman on the Hold Card Authorization Form. Prepared by and Verified By olanks may be N/A'd for a WORK ACTIVITY being transferred from one Lead Craftsman to another.

14.3 A LICENSED OPERATOR shall initial the Adequacy Verified By blank af ter l ensuring the tagout is adequate for maintenance to be performed.

14.4- The craftsman accepting the lead shall sign and date the appropriate Lead Craftsman blank.

14.5 The craftsman relinquishing the lead responsibility shall sign and date the Released By blank. This should not occur until another Lead Craftsman has accepted the tagout.

15 PARTIAL / TEMPORARY RELEASE AUTHORIZATION 15.1 An OPERATOR will perform the following- '

l 15.1.1. Record required information on a Partial / Temporary Release '

Authorization Sheet (Form 1000.027C). l I

15.1.2. After referring to the necessary procedures, valve lineups, status boards and P& ids, specify components to be  ;

repositioned on the Temporary Release Record Sheet (1000.027D). The position of Tag Removed may be used for i components that do not require repositioning.

15.1.3. Annotate the Rehang section for each tag being permanently l l

cleared (M/A, Permanent Clear, etc.). Any non-applicable columns may be N/A'd or left blank.

15.1.4. Designate the sequence to use in removal / restoration and the required position for each component on the Hold Card Record Sheet. The general guideline for restoration sequence is:

1. Close vents and drains.

2. Open suction valves.

3. Open discharge valves.

4. Close breakers.

15.1.5. Verify adequate personnel and plant safety exists for the continuation of work still covered by the tagout.

l

__j

COPY ENTER %Y CPERATI!!C'l INCORPORATED COPY Arkansas Nuclear One

Title:

HOLD CARD AUTHORIZATION FORM Form No. 1000.027A Revised 11/10/97 _

Date: 05/10/98 UNIT 1: X UNIT 2: BOTH: HOLD CARD SERIAL NUMBER: 98-1-0992 Affected System: C8 Reason / Scope of Tagout: REPAIR P2A PUMP / MOTOR.

Spacial Conditions Required / Remarks: PUMP / MOTOR CATASTROPHICALLY FAILED, CRAFT TAEE NER DED PRECAUTIONS.

E306-1 PROCEDURE ISSUED ACCEPTED Ano RELEASED OR WORK COMPONENT PREPARED VERIFIED ADEQ TO SPEC COND REVIEWED BY LEAD ACTIVITY BEING BY BY VER EXT / BY LEAD CRAFiSMAN DATE CRAFTSMAN DATE '

HUMBER WORKED INIT (PRINT) SIGN TURE) 0s (stGaiATURE)

(0 .

00978414 P-2A DAVID BICE h rp, d ,, g pfgg[4 7/, ,j'y [%(q gg, 00978416 P-2A DAVID BICE [hs E LQ ggQ 'p4/j[

7 gg 00978419 P-2A DAVID BICE [M ' 4

_my 7 7 fg g7 ((g, j MM$

[

.A WTOtV _

7 Mk 39Ct?\ /M TAGOUT AUT" ,, ]y9 'g(g" l TAGOUT REMOVAL l

y'  ;-. -Q%, -

Verify all Released by Signatures obtained.

di, hj g fj 7 -

Designate removal sequence and position.

If required, verify 1000.027N complete.

Is Restoration Verif:. cation Reguired? [ ]Yes [ ]No If NO, then N/A Ver:.fication blanks.

Operator: ,

APPROVED ,

INS LL: W j ~7 / 7[ P AL: M Operations Super or [ ate - O [ ti[ns Supervisor '

Date

PAGE 40 '56-liOI.D CARD AUTif0RIZATIOll- FORM PAGE 1 OF 2 F.!!TERGY OPERATIONS INCORPORATED Arkansas fluclear One Page 1 of 2

Title:

ilOLD CARD AUTHOR'ZATIOri FOPM l Form No. 1000.027A Revised 11/10/97 Date: _ _ _ . _ UNIT 1: II Ull1T 2: ii BOTH: 1I HOLD CARD SERIAL NUMBER: ,_

Atfected System: Reason / Scope of Tagout:

I Special Conditions Required / Remarks: -

PROCEDURE COMPONENT PREPARED VERIFIED ADEQ ISSUED ACCEPTED AND RELEASED BY OR WORK BEING BY BY VER TO SPEC COND LEAD ACTIVITY WORKED INIT EXTN PEVIEWED BY DATE DATE LEAD CRAFTSHAN NUMBER (PRINT) (SIGNATURE)

CRArTSMAN (SIGNATURE) i TAGOUT AUTHORIZATION TAGOUT REMOVAL i'

• Verify all Released By signatures obtained.

• Designate removal position and sequence.

• If required, then verify 1000.027N complete. ,

• Is Restoration Verification required? Yes No If No, then N/A Verification blanks.

i Operator Date APPROVED . REMOVAL TO INSTALL Operations Supervisor Date APPROVAL Operations Supervisor Date  !

form title: form no. rev.

Hold Card Authorization Form 1000.027 A 24 ,

i I

.. - -. . - . . . . - - - - . . . . ~ . _ _. _ . _ . _ - - . . _ . . . __, _ . . _

ADMINISTRATIVE SECTION TEST 01 RO ADMINISTRATIVE JPM Page 3 of 3 Operatmg Test i RO Al (JPM-3)

The simulator set ist Unit is tripped.

"A" OTSG N16 annuciator (K07-A5) is in alarm.

IIPI is in senice per RT2 at ~75 gpm to maintain Pressurizer level at -100".

MU Flow indicator reads >160 gym.

"A" OTSG pressure is 850 psig and dmpping.

MSSV OPEN annunciator K07- is in alarm. )

5 .u kh E N

• • ggagga i"- '

- -, g. .aca f gg., v. & 4 Ag* :e k - M!$I'P88!$F4${$$ M 8M$$Id$$$eS93w l i

Reference:

K&A 2.1.2 3.0/4.0 1

Initiating cue:

Detennine what information the CRS would require to make the proper E AL declaration.

Reference:

Emergency Action Level Classification (1903.010) Rev 34 PC 1 pages 11 and 28.

I 1

Standard:

1. Determine that 01 SG tube leakage is in excess of 10 gpm.

2. Determine that the "A" OTSG has an MSSV open.

3. Review EAL 3.0 of 1903.010 and determine OTSG leakage and steam release to atmosphere requires a change in EAL classification.

COMMENTS:

_, - . . - . - -..- - -.- - - . - _ . . ---._ _ . - -- --- ~. .- .--

PATE: 11 Ef 124 PEC.! WORK PLAN NO. PROCEDURE / WORK PLAN T(TLE:

REV: 34 1903.0i 'i EMERGENCY ACTION LEVEL CLASSIFICATION CHANGE:

ATTACHMENT 1 UNIT 1 INDEX OF EALS 4.0 PRIMARY SYSTEM EVENTS 1.1 RCS Activity Indicates >0.li Failed Fuel...........................NUE l.0 RCS Activity Indica te s > l i Failed Fue1. . . . . . . . . . . . . . . . . . . . . . . . . . . . ALERT

.3 Core Damage Indicated with an nacequate Core Cooling Condition....SAE 1.4 Containment Radiation Peading wnich Indicates LOCA and >14 Cladding Failure.................. ............................ ............SAE 1.5 Containment Radiation Reading whien Indicates LOCA and >50s ruel overheat...........................................................GE 1.6 Core Melt..........................................................GE 1.7 Loss of or challenge to all 3 Fission Product Barrier..............GE

'S PCS LEAKAGE

, 2.1 RCS Leakage > T.S. Limits requiring a plant S/D or C/D.............NUE l 2.2 RCS Leakage > Normal Makeup Capacity (50 gpm)...................... ALERT 2.3 RCS Lenkage > Normal Makeup Capacity (50 gpm) with >l.0i Failed Fuel Conditions....................................................SAE t 2.4 RCS Leakage > HPI Capacity.........................................SAE

.;.0 SECONDARY SYSTEM EVENTS 3.1 Uncontrolled CTSG Depressurization Resulting in MSLI Actuation. . . . .NUE l 3.2 OtSG Tube Leak > .347 gpm .........................................NUE 3.3 OTSG Tube Leak 310gpm Concurrent with an On-going Steam Release.... ALERT 3.4 OTSG Tube Ruptura with Primary to Secondary Leakage > Normal j

l Makeup Capacit.y (50 gpm) with ongoing steam release................SAE 3.; CTSG Tube Leak >l gpm with >1% Failed Fuel and on-going Steam l

i Release............................................................SAE

• .O ELEL*"RICAL POWER FAILURES 4.1 Degracud Power.....................................................NUE

....................... ALERT 4.; Station Eiackout..... ..... ...............

...SAZ 4.3 Elacxcut for more than 15 minutes....... ..... ........ .....

4.4 Loss of All vital DC Power.......... .............................. ALERT 4.1 Loss of All Vital DC Power f:r mere than 15 minutes...... ........SAE

5. FADICLOGICAL EFFLUENTS 5.1 Radiological Effluents >.05 mrem /hr TEDE or .15 mrem /hr Child Thyroid CDE at Site BouHaary or Liquid Radiological Effluents exceed Tech Spec Lim 1ts........................... ..................... .NUE .

5.2 Raciological Effluen:s >. 5 mrem / hr TEDE or 1. 5 mRer /hr Child Thyroid CDE at Site Boundary or Liquio Radi>1ogical Effluents exceed 10 times Tech Spec lim 1:s................... ...................... ALERT 5.3 Raciological Ef fluents >50 mrem /hr TEDE or 150 mrem /hr Chila Thyroid CDE at tne Site-Boundary...................................SAE

5. 4 Radiological Ef fluents >250 mrem /hr TEDE or 500 mrem /hr Child  !

Thyroid CDE at :he Sit [Bouncary................. .................GE i 5.5 High Padiation/ Airborne Levels.......................... .......... ALERT l 5.E Spent Fuel Accicent... ............................................SAE 4

]

1 4

i

.n __ ,

J PRY.., WORK PLAN NO. PROCEDURE / WORK PLAN TITLE: PAGE: 28 cf 124 REV: 34 1903.010 EMERGENCY ACTION LEVEL CLASSIFICATION CHANGE:

l ATTACHMENT 3 UNIT 1 SECONDARY SYSTEM EVENTS 3.3

. NDITION:

STSG Tube Leakage > 10 gpm concurrent with engoing steam release i

i EMERGENCY CLASSIFICATION:

Alert MODES Above CSD i

'RITERIA:

e

1. FCS Leaktate increase of >10 gpm, with coincident Main Steam Line N-16 alarm (s) or condenser off gas process nonitor count rate increase, or Steam l Line High Range Rad Monitors Increase (RI-2681 or 2682) or Nuclear Chemistry

- sample indicating Primary-Secondary tube leak.

-. AND

i. 2 ANY of the following occur:

A. L0ss of Offsite power l

3. Steam release to ne environment indicated by:

I

.. MaAn Steam Safety Valveis) ..~:

2. 'J s e the ADV : s : to ::ntrol affected CTSG pressure

3. P7A running with steam frem affected CTSG

4. Steam line break cutsice contalnnent

• LATE: EALS:

. TAB OTSG Tube Rupture >50 gpm with ongoing steam release 3 OTSG Tube Leak with failed fuel 3 j RCS ~.ea stage 2

?.adiol:gical Effluents 5 lHignRadiation/Aircorne Levels 5

Ilectrical Pcwer Failures 4 j;;ss :f er Cnallenge := 3 F:.ssien Procuct Barriers 1

~ _________-.J

i

' JOB PERFORMANCE .TIEASURE i Page 1 of 6 "iT: 1 REV #: 1 DATE:

, I NUMBER: ANO-1-JPM-RO-AOP21 i SYSTEM: Emergency and Abnormal Operations  !

J TASK: ' Align Auxiliary_ Spray To DH System During a Forced Flow Cooldown. t

.' JTA : 10055340101 )

KA VALUE RO: 4.4 SRO: 4.4 KA

REFERENCE:

006 A4.07 .

l APPROVED FOR' ADMINISTRATION TO: RO: X SRO: X j

-TASK LOCATION:- INSIDE CR: _ OUTSIDE CR: X BOTH:

' SUGGESTED TESTING' ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE: Simulate SIMULATOR: LAB:

' POSITION EVALUATED: RO: SRO:

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:

TESTING METHOD: SIMULATE: PERFORM APPROXIMATE COMPLETION TIME IN MINUTES: 20 minutes REFERENCE (S): 1203.040 Rev. 3, 1104.004 Rev. 63 PCl i-l l EXAMINEE'S NAME: SSN: - -

l l

EVALUATOR'S NAME:

f f~ THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN

l. TH8S'JPM AND IS DETERMINED TO BE:

i SATISFACTORY: UNSATI5 FACTORY:

PERFORMANCE CHECKLIST COMMENTS:

f.

' Start Time Stop Time Total Time SIGNED DATE:

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED

INDIVIDUAL (NOT-THE EXAMINEE) AND IS CtiR! ?* WITH THAT REVISION.

JOB PERFOR31ANCE 51EASURE Page 2 of 6

"""" EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMI!EE:

ine examiner shall review the " Briefing Checklist - System Walkthrough" portion of CP 1064.023 Attachment 6 with the examinee.

JPM INITIAL TASK CONDITIONS: A Forced Flow Cooldown is being performed due to excess RCS leakage. RB Spray is not operating. CV-1416 supply breaker is closed and CV-1416 is closed.

I TASK STANDARD: Pressurizer auxiliary spray has been alioned to the "A" LPI system.

' TASK PERPORWANCE AIDS: AOP 1203.040 step 3.11.2, OP 1104.004 section 23.

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JOB PERFORMANCE MEASURE Page 3 of 6 INITIATIUG CUE:

..e CRS directs you to align Pressurizer AUX Spray to "A" LPI system per step 3.11.2 of AOP 1203.040.

CRITICAL ELEMENTS (C): 2, 4, 5, 6

-(C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT TRANSITION NOTE: The examinee shculd proceed to the 360' elevation of the Auxiliary Building (Upper North Piping Penetration Room).

1. Verify HP Pressurizer Verified MU-64 closed '

AUX Spray Isolation by verifying valve MU-64 closed. stem down no threads showing.

POSITIVE CUE:

MU-64 is closed.

(C) 2. Open P-34A Supply to Opened DH-4A and DH-MU Prefilter and PZR SA using handwheel.

AUX Spray, DH-5A and DH-4A.

POSITIVE CUE:

DH-4A and DH-5A are open.

3. Verity P-34B Supply Verified DH-4B and to MU Prefilter and DH-5B closed by PZR AUX Spray, DH-4B verifying valve stem and DM-5B closed. down.

POSITIVE CUE:

[ DH-4B and DH-53 are closed.

l TRANSITION NOTE: The examinee should proceed to the "A" Decay Heat vault.

(C) 4. Open Pressurizer AUX Opened DH-94 using Spray Isolation, DH- handwheel.

94.

POSITIVE CUE:

DH-94 is open.

EXAMINERS NOTE:

Steps 7 and 8 niay be accomplished at this point prior to leaving the 317' elevation.

L TRANSITION NOTE:

[ The examinee should proceed to the Upper North Fiping Penetration Room on the 360' i elevation of the Auxiliary Building.  ;

(C) 5. Unlock and open DH to Unlocked and opened PZR AUX Spray Valve, DH-15 using l DH-15. handwheel.

POSITIVE CUE:

l DH-15 is unlocked and open.

(C) 6. Open Pressurizer AUX Opened DH-63 using Spray Valve, DH-63. handwheel.

. POSITIVE CUE:

,. Auxiliary Spray is aligned I to "A" LPI system.

NEGATIVE CUE:

1 Auxiliary Spray is not i alioned to "A" LPI system.

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JOB PERFORMANCE MEASURE Page 4 of 6 C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT .

7. Verify DH Room Verified ABS-13 and  !

Drains, ABS-13 and ABS-14 handles .in ABS-14, closed. closed position, j

POSITIVE CUE:

ABS-13 and ABS-14 are closed.

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8. Verify DH Room Verified DH Room watertight doors are watertight doors closed. closed. )

POSITIVE CUE:

DH Room watertight doors are closed. , )

EXAMINERS NOTE:

Stcp 10 may be performed at this point prior to leaving the Auxiliary Building. j TRANSITION NOTE:  :

Th7 examinee should proceed to the ventilation room 404' elevation.

9. Close DH Room Purge Closed DH room Purge i Dampers. Dampers by placing l the switch located on POSITIVE CUE: C-143 to the DAMPERS  !

IA-7635 and IA-6636 are in CLOSED position. (C- I DAMPERS CLOSED position. 143 is located in the l 404' el. ventilation  ;

NEGATIVE CUE: room east wall).  !

Decay Heat Rooms are not isolated.

TRANSITION NOTE: I Tha examinee should proceed to the Lower North Piping Room 335' elevation of the Auxiliary Building.

10. Open RCP ;$eal Opened MU-41 using Injection Filter handwheel.

Bypass, MU-41.

POSITIVE CUE:

MU-41 is open.

NEGATIVE CUE:

MU-41 is closed.

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i JOB PERFORMANCE MEASURE Page 5 of 6 v'4 : 006 K5 04 2.9/3.1 I

.estion 1: What temperature limitations are placed on the use of Aux Spray?

1 Answar: Aux Spray temperature limitations are only imposed '* ban the HPI pumps are i being iligned to Aux Spray and the DT is >430*F. Due .o the low temperatures I at which LH is placed in service (RCS <280*F) the potential of brittle l fracture of the spray nozzle (and violation of T.S.) is very low. I Raf: 1104.002, Rev. 50, page 11 1203.013, Rev. 15, page 7&B T.S. 3.1.2.5, I

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P RoCJWORK PLAN NO. PROCEDURE 4WDfDC PLAN Tm.E:

• I CAGE: 11 of 230 1104.002 MAKEUP & PURIFICATION SYSTEM OPERATION Rm 50 CHANGE:

5.18.2 Ensure Pressurizer Spray Isolation (CV-1009) is fully I closed prior to initiation of high pressure auxiliary spray. This will prevent partial aux. spray flow into the normal spray line and RCS cold leg, which would otherwise i

, cause an unevaluated thermal stress.  !

. I 5.18.3 Severe water hammer may occur when high pressure aux. spray l is initiated. The operator shall ensure spray is cut in slowly to minimize the possibility of water hammer.

5.18.4 Due to the limited flow between the PZR and RCS while on i high pressure aux. spray, boron addition will tend to ,

concentrate in the RCS rather than uniformly mix in PZR and l RCS. Sampling of RCS and PZR water space will be necessary s to determine total boron concentration.

5.18.5 Once high pressure aux. spray has been initiated, flow l

. should not be secured completely due to thermal stress.

PZR heaters may be used to counter the effect of the spray. ,

.5.19 Modulating valves may indicate full closed, yet not be fully torqued l closed, thereby allowing leakage past the valve.

5.20 At RCS pressures >150 psig, opening the following valves

, simultaneously could result in exceeding Letdown Relief VLV (PSV-1236) capacity and overpressuri:ing letdown system piping.

] = Letdown Orifice Block (CV-1222)

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• Letdown orifice Bypass (CV-1223) i e Letdown Block orifice Manual Bypass (MU-4) i 4  : :. If the flow is stopped downstream of the makeup tank (T-4) with 1 maximum letdown flow, the makeup tank will be overpressurized in ,

approximately 5 minutes.

.; Maximum allowaole flew tnrougn the seal in]ecti:n filter F-2: is l 7

4. ; ;pm. .

.2 Numoer of allowec successive starts with mo~or initially at amolent I temperature is 2 starti. Numoer of allowec successive starts with {

meter initially at rated temperature is 1 start. '

.14 Oue to the close tolerances in the makeup /HPI pumps (P-36A/B/C),

eperation for even a few seconds with their respective suction valve

losec will result in damage to the pump.

5.25 Operation of makeup pump (s) with suction aligned from maPeup tank T-4; only, and all inlets to T-4 isolated, will lead to vacuum being crawn in T-4 wnich will result in makeup pump damage.

5.2E The Aux Lube Oil Pump sneuld not be run for more than 5 seconus on a running MU Pump to minimize c:.1 loss

MtOCJWORK PLAN NO. PROCEDURE / WORK PLAN TITLE: PA7E: 7 cf 23 1203.013 NATURAL CIRCULATION COOLDOWN REV: 15 CHANGE:

NOTE l

' 1. During a natural circulation cooldown practically no flow exists in the Fluid temp will remain near that RCS temp when RCPs were l

. head region. I l

secured and will drop following ambient losses. This ambient cooldown rate will be ~5'r/hr.

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i l 2. RV Head steam bubble formation would be indicated by RV level indicators I j on ICCMDS display, rapid rise in PZR level while depressurizing, or rapid j drop in FIR level while pressurizing. j I l l 3. E a steam bubble is indicated in the RV Head, cooldown rate shall be i reduced to $50*F/hr, unless SCH is less than adequate.

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4. M RCS press is maintained within limits of Attachment A, and cooldown zate is maintained $50*F/hr, RV Head steam bubble formation should not ,

prevent depressurization and cooldown to DHR operations. l l l l 3.11 g indication of RV Head steam bubble occurs, perform the following: l 3.11.1 Unless directed otherwise by Ops Manager, terminate depressurization, then pressurize slightly to reduce the size of the bubble and ensure continued natural

! circulation, l

i l 3.11.2 Proceed *.itn cooldown and depressurization at $50*/hr, I

unless SC21 is less than adequate.

3.11.3 Repeat bubble-reducing maneuver to minimize voiding.

3.1 Control RCS press during cooldown by one or more of the following:

l CAUTION

.. Jse :f h gh pressure AUX spray wnen Fressurl:er Spray Isolation lCV-1009) ranne: ce c1:sec =an resul: := thermal snock of the spray . ne connection

:ne ::i: .eg pipe.

2. Use f spray wnen temp cifference between PZR and spray fluid is >430*F viciates TS 3.1.2.5 anc must ce evaluated crior to restart.

NOTE l1. Per 10CTR50.54 (x), reasonable action that departs from a Technical Specification may be taken in an emergency when this action is immediately neeued to protect the public health and safety and no action consistent with technical specifications that can provide acequate or equivalent protection is immediate apparent. (y) Such action shall be approvec by an SRO p lo: to taxing t e action. This action is reportable within one hour under 10CTR50.72 (b> 1) ::: (B), "Deviatien f:cm Teen Specs authorized i per ; %FR50.54(x)."

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i :. S:ers are in c cer cf :eference anc depend en ave 11 ability.

3.;~.. Ty:le Ep'! as necessary te cent::1 PCS press.

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• ROCJWORK PLAN NO. PROCEDURE / WORK PLAN TITLE: PAGE: 8 cf 23 1203.013 NATURAL CIRCULATION COOLDOWN RLv: 15 CHANGE:

3.1".2 Turn off PZR heaters, then surge in and out of PZR between 60" and 200" to control RCS press.

3.12.3 Use Pressurl:er AUX Spray as follows:

A. Calculate PZR/ spray fluid AT (PZR temp minus BWST temp):

1. PZR Temp (C04)

2. BWST T-3 Temp (C14)

3. AT =

B. When PZR/ spray fluid AT is <430*F or depressurl:ation is needed to protect the public safety and no other actions consistent with Tech Specs are adequate, use Pressurizee AUX Spray -(CV-1416) to control RCS press as follows

1. If PZR/ spray fluid AT is >430*F, obtain SRO approval prior to using PZR AUX spray.

2. Verify Pressurizer Spray Isolation (CV-1009) closed.

a. If CV-1009 cannot be closed, do not use PZR j

AUX spray.

3. Collect the following data in rough log for each on-off cycle of AUX spray:

o PZR Temp (C04).

• BWST T-3 Temp (C14).

• RCS press.

• Time of CV-1416 cpening and closing.

e Valve position (full open, opened fer 4 sec, etc.).

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4. Unlock and close power supply breaker (B-5531) for CV-1416.

, 5. Open High Pressure PZR AUX Spray Isol (MU-64).

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6. Minimi

e water hammer; slowly introduce spray l into PZR by slightly opening CV-1416.

7 Regulate CV-1416 position so spray flow is 1 continuous; avoid closing and reopening.

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3.1.0 Pressurizatien. Hea tup s_1nd Cooldown Limitat iong Soecification 3.1.2.1 Hydro Tests For thermal steady state system hydro tests, the system may be pressurized to ti:e limits set forth in Specification 2.2 when there are fuel assemblies in the core, under the provisions of 3.1.2.3, and to ASME Code limits when no fuel assemblies are present provided the reactor coolant system limits are to the right of and below the limit line in Figure 3.1.2-1. The provisions of Specifications 3.0.3 are not applicable.

3.1.2.2 Leak Tests Leak tests required by Specification 4.3 shall be conducted under the provision of 3.1.2.3. The provisions of Specification 3.0.3 are not applicable.

3.1.2.3 The reactor coolant pressure and the system heatup and cooldown rates (with the exception of the pressurizer) shall be limited in accordance with Figure 3.1.2-2 and Figure 3.1.2-3, and are as follows:

Heatup:

Allowable combinations of pressure and temperature shall be to the right of and below the limit line in Figure 3.1.2-2. The heatup rates shall not exceed those shown in Figure 3.1.2-2.

Cooldown:

Allowable combinations of pressure and temperature for a specific cooldown shall be to the right of and below the limit line in Figure 3.1.2-3. Cooldown rates shall not exceed those shown in Figure 3.1.2-3.

3.1.2.4 The secondary side of the steam generator shall not be pressurized above 200 psig if the temperature of the steam generator shell is below 100F.

3.1.2.5 The pressurizer heatup and cooldown rates shall net exceed 100F/hr. The spray shall not be used if the temperature difference between the pressurizer and the spray fluid is greater than 430F.

3.1.2.6 With the limits of Specifications 3.1.2.3 or 3.1.2.4 or l

3.1.2.5 exceeded, restore the temperature and/or pressure to within the limit within 30 minutes; perform an engineering evaluation to determine the ef fects of the out-of-limit condition on the fracture toughness properties of me Reactor Coolant System: determine that the Reactor Coolant System remains acceptable for continued operations or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and reduce the RCS Tavg to less than 200F. while maintaining RCS temperature and pressure below the curve. within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

Amendment No. 22. 28. 37, J34. :61 18

JOB PERFORMANCE MEASURE Page 6 of 6

A :

006 Kl.04 2.7/2.8'

.stion 3: Why can' t Aux Spray te used if the normal Pzr Spray isolation, CV-1009, can 1 NOT be closed?

i An2 Wars With CV-1009 open, part of the Aux spray would flow back down intra the normal spray line. This would cause unevaluated thermal stresses on the normal spray piping.

R3forince: 1104.002, Rev. 50 page 11.

1203.013, Rev. 15 page 7.

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CJWORK PUUd NO. PenrwrunwguaggC PLAN TmE:

• PAGE: 11 of 230 1104.002 MAKEUP & PURIFICATION SYSTEM OPERATION REV: 50 CHANGE:

5.18.2 Ensure Pressuri:er Spray Isolation (CV-1009) is fully closed prior to initiation of high pressure auxiliary spray. This will prevent partial aux. spray flow into the normal spray line and RCS cold leg, which would otherwise cause an unevaluated thermal stress.

5.18.3 Severe water hammer may occur when high pressure aux, spray is initiated. The operator shall ensure spray is cut in slowly to minimize the possibility of water hammer.

5.18.4 Due to the 1Laited flow between the PZR and RCS while on high pressure aux. spray, boron addition will tend to concentrate in the RCS rather than uniformly mix in PZR and RCS. Sampling of RCS and PZR water space will be necessary to determine total boron concentration.

5.18.5 Once high pressure aux. spray has been initiated, flow should not be secured completely due to thermal stress.

PZR heaters may be used to counter the effect of the spray.

5.19 Modulating valves may indicate full closed, yet not be fully torqued closed, thereby allowing leakage past the valve.

5.20 At RCS pressures >150 psig, cpening the following valves simultaneously could result in exceeding Letdown Relief VLV ( PSV-1236) capacity and overpressuriting letdown system piping.

• Letdown Orifice Block (CV-1222)

• Letdown Orifice Bypass (CV-1223)

• Letdown Block Orifice Manual Bypass (MU-4) I l

.2.

• f the flow is stopped downstrea.n of the makeup tank (T-4) with maximum letdown flow, the makeup tank will be overpressurized in i approximately 5 minutes. 1 Max: mum allewaole f1:w enrouen the seal in]ects:n filter F-2 s l ~ gpm.

... ';ummer cf allowec successive starts with motor nitially at amolent temperature is 2 starts. Nummer of allowed successive starts with motor nitially at ratec temperature is 1 start.

..;4 Oue to the close tolerances in the makeup /HPI pumps (P-36A/B/C),

Operation for even a few seconos with their respective suction valve

losed will result :n camage to the pump.

.25 Operation of makeup pumpts: with suction aligned from makeup tank T-4) only, and all inlets to T-4 isolated, will lead to vacuum being crtwn in T-4 wnten will result in maxeup pump camage.

.26 The Aux Lube Oil Pump snould not be run for mvre than 5 seconcs on a running MU Pump to minimize

:1 loss.

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1 l PAGE: 7 cf 23 l ROCJWORK PLAN NO. j PROOEDURE/ WORK PLAN TTTI.E:

REV: 16 1203.013 NATURAL CIRCULATION COOLDOWN I CHANGE: 1 I

NOTE

1. During a natural circulation cooldown practically no flow exists in the head region. Fluid temp will remain near that RCS temp when RCPs were secured and will drop following ambient lossen. This ambient cooldown rar.e will be ~5*F/hr.

2. RV Head steam bubble formation would be indicated by RV level indicators l on ICCMDS display, rapid rise in PZR lovs1 while depressurazing, or rapid i drop in PZE level while pressurizing. ,

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3. If a steam bubble is indictated in the RV Head, cooldown rate shall be reduced to <50*F/hr, unless SCH is less than adequate.

4. y,RCS press is maintained within limits of Attachment A, and cooldown rate is masntain=d <50*F/hr, RV Head steam bubble formaation should not  !

prevent depressurization and cooldown tu DHR operations.

3.11 If indication of RV Head steam bubble occurs, perform the following:

3.11.1 Unless directed .cherwise by Ops Manager, terminat.e depressurization, then pressurize slightly to reduce the size of the bubble and ensure continued natural circulation. l l

3.11.2 Proceed with cooldown and depressurization at <50*/hr, urd:.ss SCH is less than adequate.

I 3.11.3 Hopeat bubble-reducing maneuver to minimize voiding.

3.12 Control RCS press during cooldown by one or more of the following:

CAUTION

.. .e :: nl:n pressure AUX spray wnen Pressuriter Spray Isolation ,0V-1009)

anne: ce :1:sec :an result in :nermal snocx cf :ne spray ;;ne ::nnection

:ne ::.: .ea pipe.

. Jse cf spray wnen temp cifference between PZR ano spray fluic is >430*F ,

.101ates TS 3.1.2.5 anc must ce evaluated erler to restart. i i

I NOTE l

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Fe: 10CTR50.54 (x), reasonacle action that departs from a Tecnnical 2cecification may be taken in an emergency when this action is immeciately neeceo : protect the publi health and safety and no action consistent j with tecnnical specifications that can provice acequate or equivalent i protect::n is 1=meciately apparent. :y' Such action shall be approvec by an SFO p:::: to taxing :ne actier.. This action is reportacle within one neur unce: 10CFR50.72 (b) (1; (1) (B), " Deviation from Teen specs author::ed

,e:

r 100FF50.54(x)."

I :. ::ers are ;n Orcer ef ::eference anc ceoenc en availability

..:.1 Ty:.e EFY as necessa / :: ::nt::1 RCC press.

JOB PERFORMANCE MEASURE Page 1 of 8

""1: X REV #: 9 DATE:

TLwA EUMBER: ANO-1-JPM-RO-ED012 SYSTEM: Electrical System Operations TASK Startup Y-11 Inverter with load on the alternate source l l

JTA: 10625120101 l l

KA VALUE RO: 3.1 SRO: 3.1 KA

REFERENCE:

062 A4.07 l l

APPROVED FOR ADMINISTRATION TO: RO: X SRO: X l l

TASK LOCATION: INSIDE CR: OUTSIDE CR: X BOTH: l l

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE): I PLANT SITE: Simulate SIMULATOR: LAB:

POSITION EVALUATED: RO: SRO:

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:

TESTIMG METHOD: SIMULATE: PERFORM:

APPROXIMATE COMPLETION TIME IN MINUTES: 12 minutes REFERENCE (S) : OP 1107.003, Rev. 8 PC-3 EXAMINEE'S NAME: SSN: - -

, EVALUATOR'S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN .

THIS JPM AND IS DETERMINED TO BE: I SATISFACTORY: UNSATISFACTORY: l l

PERFORMANCE CHECKLIST COMMENTS:

i l

l Start Time Stop Time Total Time SIGNED DATE:

SIGNATURE-INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED IMDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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JOB PERFORMANCE MEASURE j Page 2 of 8 EXAMINER SHALL' REVIEW THE FOLLOWING WITH THE EXAMINEE:

7..a examiner shall. review the " Briefing Checklist - System Walkthrough" portion of

, OP.1064.023 Attachment 6 with the examinee. ,

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JPM INITIAL TASK CONDITIONS: Inverter Yll is shut down. The Inverter manual switch  :

is in the " Alternate source to Load" position. '

'RS-1 is being supplied from Y-11

, . alternate source.

TASK STANDARD: " Inverter Supplying Load" light on. " Alternate Source f

Supplying Load" light out. Manual switch in " Inverter to Load" position. [

TASK PERFORMANCE AIDS: Copy of OP' 1107.003, Section 8.3 l 1

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Page 3 of 8

'tJ'TIATING CUE:

T. SS/CRS directs that you startup and place inverter Y-11 in service. l 1

CRITICAL ELEMENTS (C): 9, 12, 14, 16 l I

l PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT 1 Verify DC Input Verified DC Input j Breaker open. breaker on inverter J open 1 POSITIVE CUE:

Bkr. open, ]

' j 2 Verify Inverter Verified inverter i Output Breaker output breaker is l open. open.

l POSITIVE CUE:

Inverter output r breaker open.

3. Verify Alternate Verified Alternate Source AC input source AC input breaker closed. breaker closed.

POSITIVE CUE:

Alternate Source AC input closed.

4. . Verify Y-11 Verified Y-ll Manual Manual selector selector switch (HS-switch (HS-1122) 1122) in the in the Alternate Alternate Source To Source To Load Load position.

position.

POSITIVE CUE:

Y-ll Manual selector switch is in the Alternate Source To Load position.

5. -Verify RSl Verified RS1 Transfer Transfer switch switch (HS-1123) ~ at (HS-1123) in Y- the top of Y-11 in 11 to RS-1 the Y-11 to RS-1 position. position.

POSITIVE CUE:

RS-1 Traar f er switch is in Y-11 to RS-1 position.

TRANSITION NOTE: The examinee should proceed to the South Electrical Equipment Room (behind the orange door).

6. Verify Y-11 At B-51 verified B-breaker B-5141A 5141A closed by closed. observing breaker handswitch in the g POSITIVE CUE: closed position.

Breaker B-5141A is closed.

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i JOB PEF.FORMANCE MEASURE Page 4 of 8 l PERFORMANCE CHECKLIST l -ST1UDARDS l N/A l SAT l UNSAT TRANSITION NOTE:

Tha examinee should proceed from the South Electrical Equipment Room (behind the orange door) to tha D01 bus.

7. Verify DC Supply AT D01 verified DC feeder breaker Supply feeder breaker D01-22A closed. D01-22A handle in the closed position. ,

POSITIVE CUE:

D01-22A CLOSED.

i NEGATIVE CUE:

• D01-22A open.

8. Verify battery Verified battery D07 D07 disconnect disconnect D-13 D-13 closed. closed, i POSITIVE CUE:

Battery D07 disconnect is closed. ,

(C) 9. Close the DC On the inverter, Input Bkr. placed the DC Input breaker handle in the POSITIVE CUE: closed position.

DC Input breaker closed. '

[

NEGATIVE CUE

DC input breaker open l 10. Wait 60 seconds Waited 60 seconds for for inverter to the inverter to stabilize. stabilize.

l POSITIVE CUE:

Inverter has stabilized.

!' 11. Check inverter Checked inverter

! output is - 120 output voltage ~120 l volts and Volts and frequency

frequency is - ~60 Hz.

ji 60 Hz.

i l POSITIVE CUE: )

Inverter output is )

~120 volts /60 Hz.

l NEGATIVE CUE:

Inverter output is

O volts /0 Hz. Breaker.

(C) 12. Close Inverter On the front of the

, Output breaker. inverter closeo the Inverter output POSITIVE CUE: breaker.

' Inverter output breaker closed. l 1

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JOB PERFORMANCE lEASURE Page 5 of 8 PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT f-

13. Verify the Verified the " UNIT IN inverter " UNIT SYNC" light ON.

IN SYNC" light ON.

POSITIVE CUE:

UNIT IN SYNC light on.

NEGATIVE CUE:

UNIT IN SYNC light is not on.

(C) 14. Place the manual Placed the manual selector switch selector switch (HS-(HS-1122) in the 1122) in " NORMAL

" NORMAL SOURCE SOURCE TO LOAD" TO LOAD" position.

position.

POSITIVE CUE:

Switch in NORMAL SOURCE TO LOAD position.

15. Verify the Verified " UNIT IN inverter " UNIT SYNC" light on, and IN SYNC" light frequency between is on and 59.5 and 60.5 Hz.

frequency is between 59.5 and .

60.5 hertz. -

POSITIVE CUE:

Inverter UNIT IN SYNC light is on NEGATIVE CUE:

UNIT IN SYNC Light is not-on.

(C) 16. Shift load to Depressed the the inverter. "IfNERTER TO LOAD" push-button.

POSITIVE CUE:

" INVERTER SUPPLYING LOAD" light ON.

NEGATIV:: crJE:

" ALTERNATE SOURCE SUPPLYING LOAD'_' light ON.

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i JOB PERFORMANCE MEASURE Page 6 of 8 i l

~

PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT

17. Verify INVEPTER Verified INVERTER 1 SUPPLYING LOAD SUPPLYING LOAD light '

light on and on and ALTERNATE ALTERNATE SOURCE SOURCE SUPPLYING LOAD SUPPLYING LOAD light out.

light out.

POSITIVE CUE: I INVERTER SUPPLYING LOAD light on and ALTERNATE SOURCE j SUPPLYING LOAD light out.

18. Check local Reset alarms on local alarm panel and alarm panel. l reset all- j related alarms.

POSITIVE CUE:

All alarms clear on local alarm panel.

19. Verify RS1 Called control room INVERTER TROUBLE to RS1 INVERTER alarms are TROUBLE alarms are clear, clear.

POSITIVE CUE:

Control Room reports all inverter trouble alarms clear.

1 END l

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JOB PERFORMANCE MEASURE Page 7 of 8  ;

062 A3.03 2.3/2.3 Jusufication for use of <2.5 K/A:

Improper breaker operation may result in loss of power to vital 120VAC panels that could result in plaat  ;

trip..

Question: If the SYNC light is not on what acuons are required?

Answer; l Electrical Maintenance assitance is required to correct die problem. ,

Reference - Inverter and 120VAC Vital AC Distribution (1107.003) Rev 8 PC 4 page19.

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l PROCJWORK PLAN NO. PROCEDUREJWORK PLAN TITLE: PAGE: 19cf146 j 1107.003 INVERTER AND 120V VITAL AC DISTRIBUTION REV: 8 j CHANGE:

l NCKMES l

1. If ALTERNATE SOURCE SUPPLYING LOAD 11ght is on, the load remains on I alternate source regardless of position of manual selector switch.

2. If manual selector switch is in ALTERNATE SOURCE TO LOAD position, the load, remains on alternate source regardless of position of static switch. ,

I 8.3.7 Switch Y11 manual selector switch (HS-ll22) to NORMAL SOURCE TO LOAD position as follows.

l A. Verify Inverter Y11 UNIT IN SYNC light is l on. I 1

l B. Place Inverter Yll manual selector switch l (HS-1122) in NORMAL SOURCE TO LOAD l position.

1 8.3.8 Shift load to Inverter Y11 as follows:

A. Verify Inverter Y11 UNIT IN SYNC light is on and frequency is between 59.5 and 60.5 hertz.

1 C'J d3 TION Transferring out of sync may cause loss of load. If IN SYNC light is not on, Electrical Maintenance assistance is required.

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B. Depress Inverter Y11 INVERTER TO LOAD pushbutton (PB-1100).

C. Verify Inverter Y11 INVERTER SUPPLYING LCAD light comes on and ALTERNATE SOURCE i SUPPLYING LCAD light goes out. l NOTE l

.. Inverter Y11 is now in normal operating mode.

2. Inverter Output Overvoltage alarm may take as much as 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> to clear as inverter reaches normal operating temperature.

S.3.9 When alarm conditions clear, reset Yl; local alarm panel. Alarm reset not required to continue.

l 2.3.10 When local alarm panel is reset, verify RS1 j INVERTER TROUBLE (K01-A5) alarm in control room

' is clearec. Alarm reset not required to l continue.

E.3.11 l' appilcaole, exit LCC entered for RS panel en alternate source. Otherwise N/A.

. ...- . .. . .. . . . - , . . ~ . - . . . . _ . - . . --..... - - _ . . . . . . . . . . . . _

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JOB PERFORMANCE MEASURE Page 8 of 8 K&A- 062 K5.03 2.4/2.6 Justification for use of <2.5 K/A:

Improper breaker operation may result in loss of power to vital 120VAC pancis that could result in plant trip.

l Guesti:n:~ Why does the inverter have to be in sync before using the static switch to change from the alternate source?

Answer: The static switch is a make-before-break switch and no interlock exists to prevent switching

. out of s>w.

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Reference Inverter and 120VAC Vital AC Distribution (1107.003) Rev 8 PC 4 page 6.

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NJWORK PLAN NO. Mt0CEDUREhWORK PUUd TITLE. TAGE: 6 of 146 REV: 8 1107.003 INVERTER AND 120V VITAL AC DlSTRIIUTION CHANGE:

Switching to and from the alternate source using the static switch requires that the system be in sync. Using the manual selector switch also requires the systems to be in sync because the switch is a make-before-break contact, however, there is no interlock to prevent switching out of sync.

Y28 has an additional breaker on the front of the cabinet, " Alternate Source AC Input to the Static Switch". This breaker can be used to allow nalntenance i on the static switch while still supplying alternate AC power to C540. Y28 l has a slightly different control and instrument arrangement and has no fault l I

protection breaker inside the cabinet. Y41 has no rectified AC input and the Alternate Source AC Input breaker is connected in the circuit similar to the Y28 " Alternate Source AC Input to the Static Switch" breaker. l Power distribution to and from the inverters is as follows:

Alternate Inverter AC Input Source DC Input Output tot 1 Y11 B-5141A D01-22A RS1 Y13 B-5315 D01-52B RS3 Y15 B-5714 D01-53A RS1 or RS3 Y22 B-6543 D02-42A RS2 l Y24 B-6145A D02-22A RS4 '

Y25 B-6315 D02-32 RS2 or RS4 Y41 B-5643A D-4184 RCl Y28 B-6134B B-6134A D02-41B C540 l Instrument power supplies in C27 provide a source of DC voltage for balance of plant (BOP) instrumentation. There are two 120V AC supplies to this panel.

Y '. ; creaker 38 supplies the normal DC power supply. YO2 breaker 6 supplies tr.e stancby DC power supply. A power supply selector switch in C27 can i

nnect either DC power supply to the load. Or, in AUTO, the two DC power i supplies are auctioneered such that the one with the highest output voltage w;.1 supply the lead. l Watn tne power supply selector switch in AUTO, the DC power supply will not be

.:st if one cf the input sources (YO1 or YO2) is lost.

A .1 sting of the instruments supplied by C27 BOP power supply is contained in tne Eechtel design drawing, Schematic Diagram Miscellaneous Instrumentation Power Supplies (E-330).

Instrument cower supplies in C28 provide a source of DC voltage for other instrumenta 1:n. There is only one 120V AC supply to this panel, YO1 breaker

6. There are two DC power supplies in C28 with a power supply selector switch as in C27. However, with a single source of power (YO1), loss of tnis input power will result in loss of the DC power supply. A listing of the instruments supplied by the C28 power supply is contained in the Bechtel cesign crawing, Auxiliary Systems Miscellaneous Instruments (E-254).

Page 1 of 6 I

4 JOB PERFORMANCE MEASURE UNIT: I REV # 1 DATE:

TUOI NUMBER: ANO-t JPM-RO-AOP18 SYSTEM / DUTY AREA: EMERGENCY AND ABNORMAL OPERATIONS TASK: PERFORM ACTIONS FOR A LOSS OF DECAY HEAT REMOVAL JTA#: 13035510401 KA VALUE RO: 33 SRO: 36 KA

REFERENCE:

025 AA2 04 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE: SIMULATOR: PERFORM LAB:

POSITIONEVALUATED: RO: SRO:

ACTUAL TESTING ENVIRONMENT: SIMULATOR:_. PLANT SITE: LAB:

TESTING METHOD: SIMULATE: PERFORM:

APPROXIMATE COMPLETION TIME IN MINUTES- 7 MINUTES REFERENCE (S): 1203.028 REV 14. Section 1 EXAMINEE'S NAME: SSN - -

EVALUATOR'S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY: UNSATISFACTOI Y:

PERFORMANCE CHECKLIST COMMENTS:

1 k-Start Time Stop Time Total Time SIGNED DATE:

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDL%E BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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( TUO! NUMBER: ANO-1 JPM-RO-AOPl8 t

- DIE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE: l The examiner shall rev ew the " Briefing Checklist System Walkthrough" ponion of l OP 1064.023 Attachment 6 with the examinee.

JPM INITIAL TASK CONDITIONS: Decay Heat Removal System is in service with RCPs oft l

Pressurizer level is droDDinE raDidly 1

F l TASK STANDARD: The running decay heat pumD (P34B) was manually stoDDed, one Decay Heat Suction Valve was closed (CV-1050 or CV 1404 or CV-1410) and the "B" DH PumD suction

valve (CV-1434) is shut i

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TASK PERFORMANCE AIDS: Loss of Decay Heat Removal AOP after immediate actions are

! comDieted.

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Simulator setuD: recall an IC with "B" Decay Heat Removal Pump in scruce and RCPs off. Insert a malfunction

!. which causes an RCS leak inside the auxiliary building.

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Page ' of 6 l

l TUO! NUMBER: ANO 1-JPM-RO-AOP18 l l

! INITIATING CUE:

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The SS/CRS informs you that the WCO has loacted a large leak on the pump seal for ""B" Decay heat pump and directs you to perform the immediate actions for Loss of Decay Heat Removal due to a DH S3 stem Leak.

l CRITICAL ELEhiENTS (C): 1.2.8 l I

l(C) PERFORMANCE CHECKLIST STANDARD N/A l SAT UNSAT 1

1. Stop the running Decay Heat Removal On panel C16 (P-34B) stopped the ,

Pump (P-34 A). running Decay Heat Removal Pump l (C) using its handswitch.  ;

POSITIVE CUE: green light ON, red light  !

OFF above DHR Pump handswitch.

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2. Close at least one Decay Heat Suction On panel Cl4 (CV-1404) or C16 (CV-  !

valve (CV-1050 or CV-1404 or CV-1410). 1410) or C18 (CV-1050), closed at least l one of the three Decay Heat Suction POSITIVE CUE: green light ON, red light valves. Observed green light ON, red (C) OFF for valve (s) that examinee closed. light OFF for the valve (s) mamputated.

NEGATIVE CUE: pressurizerlevelis lowering.

1 NOTE TO EXAMINER l After the above steps are completed Examinee may reference Loss of Decay Heat Removal AOP (1203 028) for follow up actions.

3. Notify Shift SuperintendenuCRS to implement EAL classification.

I POSITIVE CUE: EAI -'*sification in progress.

4. Determme if maintenance activities in  ;

the Reactor Building could be affected by RCS Level Rise, perform local evacuation i of the affected areas.

POSITIVE CUE: No maintenance activities are in progress inside the Reactor building.

5. Deternune if RCS temperature will Monitor ICCMDS and/or SPDS for CET exceed 280*F. temperature.

POSITIVE CUE: RCS temperature is 150*F and slowly rising.

l Page 4 of 6 (C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT

6. Determine that containment closure per 1203.28 Attachment G is not required.

Time to steam release >lhour e RCS pressure <l50 psig.

• RCS press > DH sys max press limit per 1102.010 Att A not applicable POSITIVE CUE contaiment closure is not required.

7. Deternune that leak is not common to both DH system.

POSITIVE CUE: Local verification by operator in P34B vault reveals leak on P#SB seal.

8. Isolate the leak in the "B" DH system by Close CV-1434 using handswitch on closing P34B suction valve (CV-1435). C-18.

(C)

POSITIVE CUE: CV-1434 indicates closed. l l

l END

Page 5 of 6 K&A 005 K4.07 3.2/3.5 Question: At what RCS pressure is the auto-close interlock for the Decay Heat Suction Valves reset?

Answer: 290 psig.

Reference Deacy Heat Removal Operating Procedure (1104.004) Rev 63 PC 1 page 14.

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PROC / WORK PLAN NL. PROCEDURE #dORK PLAN TTTLE: P E: 14 Cf 77 1104.001 CORE FLOOD SYSTEM OPERATING PROCEDURE REV: 29 CHANGE:

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?.0 Drainan; CFT T-2A to RB Sump iDWDH) During Reactor Shutdown l

9.1 Determine amount of borated water to be drained and verify dirty liquid system is available to process required amount.

l CAUTION Vented gas may be radioactive.

9.2 Reduce CPT T-2A pressure to ~50 psig by opening Core Flood Tank T-2A Vent (CV-2417), then close CV-2417. l j 9.3 Open Core Flood Tank T-2A Drains to DWDH (RBD-1A and RBD-2A).

l 9.4 Monitor RB sump and ensure floor drain handles drain flow and does not back up during draining evolution.

9.5 When desired level is reached, close RBD-1A and RBD-2A.

10.0 Draining CFT T-2B to RB Drain Header During Reactor Shutdown 10.1 Determine amount of borated water to be drained and verify clean liquid waste system is available to process required amount. ,

1 NOTE l Draining CPT T-2B to ABEDT is a containment breach and requires tracking on either Category E Valve Log (Form 1015.035A) or containment Closure Breach List (Form 1015.002D).

i 10.2 Unlock and open RBDH Isol to ABEDT (RBD-23 and RBD-24)

A. If required, make appropriate entry in Category E Valve Log (Form 1015.035A).

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B. If required, make appropriate entry en Containment Closure Breach List (Form 1015.002D).

10.3 Open RBDH Isol to ABEDT fRBD-14).

CJkUTION Vented gas may oe radioactive.

10.4 Reduce CPT T-2B pressure to ~50 psig by opening Core Flood Tank T-2B Vent (CV-2420), then close CV-2420.

10.5 Dpen Core Flood Tank T-2B Drains to RBD (RBD-1B and RBD-2B).

10.6 When desired level is reached, close RBD-1B and RBD-23.

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Page 6 of 6 K&A 005 K3.013.9/4.0 Question: If Decay Heat removal is lost containment closure must be established prior to what?

Answer: Containment closure must be established prior to steam release.

Reference Loss of Decay Heat AOP (1203.028) Section 2 Rev 14 page 11.

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POOC#tORK PLAN No. ' PQOCEDURE/ WORK PLAN TITLE: PAGE: 11 @f 54 1203.028  ! LOSS OF DECAY HEAT REMOVAL QEV: 14 j CHANGE:

SECTICN 2 -- DH REMCVAL SYSTEM LEAK tcontinued)

NOTE

1. Conta:nment closure must be established prior to steam release.

2. Decay Heat Removal and LTOP System Control (1015.002), Form 1015.002B provides estimate of time to 200*F, time to steam release, time to core uncovery, heatup rate, and recruired makeup rate.

3.4 If any of the following conditions occur, initiate containment closure

%r Attacnment G of this procedure, while continuing with this section.

Time remaining to steam release is g becomes <1 hour and DH removal cannot be immediately restored.

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• RCS press >150 psig and RCS loops not filled.

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• RCS press > Decay Heat Sys. Max. Pressure limit of Plant Shutdown and Cooldown (1102.010), Attachment A.

3.5 g leak is common to both DH systems and is unisolable, GO To applicable " Loss of Both DH Systems" section of this procedure.

CAUTION

1. If RCS loops are not filled and DH pump is started with high flow, severe water hammer can damage DH system pipe.

2. If RCS press is >150 psig and DH pump is dead-headed, DH system design cress can be exceeded.

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3.6 !solate leak and restore DH Pemoval system as follows:

2.6.1 Verify EH pumps (P-34A and P-34B) off.

1 3.6.2 If, leak is in "A" DH system '

and is unisolable, close P-34A Suction From RCS (CV-1434).

l 3.6.3 g leak is in "B" DH system and is unisolable, close P-34B Suction From RCS (CV-1435).

3.6.4 g "A" DH system is to be placed in service, perform the j follcwine:

A. Verify DH suction press <75 psig.

B. Ver:fy P-34A Suction Frcm BWST 'CV-1436) closed.

l C. Open P-34A Suction From FCS (CV-1434).

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I JOB PERFORMANCE MEASURE I

Page 1 of 6 UNIT 1: X REV #: 0 DATE:

TUOI NUMBER: ANO-1-JPM-RO-AOP25 SYSTEM: Emergency and Abnormal Operatons I TASK: Respond to loss of loadcenter B2.

JTA 106263904A4

{ KA VALUE RO: 3.4 SRO: 3.9 KA

REFERENCE:

062 A2.01

! APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:

l SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

l PLANT SITE: SIMULATOR: PERFORM LAB POSITION EVALUATED: RO: SRO:

l ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:

! TESTING METHOD: SIMULATE: PERFORM:

APPROXIMATE COMPLETION TIME IN MINUTES: 15 minutes l REFERENCE (S): AOP 1203.046, Rev. 1 PC3 l

1 EXAMINEE'S NAME: SSN: - -

EVALUATOR'S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STA"TARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

l SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

l Stort Time Stop Time Total Time l

i SIGNED DATE:

S!GNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

1 JOm PERFORMANCE MEASURE Page 2 of 6 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

The examiner shall review the " Briefing Checklist - System Walkthrough" portion of OP1064.023 Attachment 6 with the examinee.

JPW INITIAL TASK CONDITIONS: A breaker fault -- has resulted in the loss of loadeenter B2.

1 Unit is at 100% power.

TASK STANDARD: AOP 1203.046, steps 3.2.1 through 3.2.9 completed.

TASK PEELFORMANCE AIDS: __ Copy of AOP 1203.046, Rev 1, section 3.2 1

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l l JOB PERFORMANCE MEASURE  !

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Page 3 of 6 j INITIATING CUE:

l The SS directs you respond to loss of loadeenter B2 in the control room. I CRITICAL ELEMENTS (C): 1, 3, 8 1 l

(C) PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT

1. Place ICW pumps P-33B On panel C09, and P-33C in pull-to- handswitches for P-33B lock, and P-33C placed in (C) pull-to-lock.

POSITIVE CUE:

Handswitches in pull-to-lock.

NEGATIVE CUE

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!' Handswitches in normal-after-stop or normal-after-start.

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2. Verify suction and on panel C09, verified j discharge crossconnect valves CV-2238, CV- l l

valves open. 2239, CV-2240, CV-2241 indicate RED.

POSITIVE CUE:

CV-2238, CV-2239, CV-2240, CV-2241 indicate RED.

NEGATIVE CUE:

CV-2238, CV-2239, CV-2240, l CV-2241 indicate GREEN. i

3. Isolate Letdown. At C16, Letdown isolated by closing POSITIVE CUE: Letdown Coolers outlet j (C) Letdown flow FI-???? CV-1221.

Indicates bottom of scale.

l Examiner Note

• t Toll examinee that step 3.2.4 has been completed.  ;

4. Verif y ICW booster At C09, verified P-  !

pump P-114A or P-114B 114A or P-114B I running. indicated RED.

POSITIVE CUE:

P-ll4A or P-114B indicate RED.

NEGATIVE CUE:

P-114A or P-114B indicate GREEN.

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JOB PERFORMANCE MEASURE Page 4 of 6 (C) PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT

5. Verify CRD Cooling on panel C09, verified Water Pump P-79A P-79A indicated RED.

running.

POSITIVE CUE: I P-79A indicates RED.

l 6. Ver11y a MW Pump on panel CO2, verified l Turbine oil pump indicating lights were l i running for each RED for at least one operating Main oil pump on M N Pumps Feedwater pump. A and B.

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l POSITIVE CUE: '

P26A, P27A, or P28A indicates RED.

P26B, P27B, or P20B indicates RED.

7. Verify Condensate Contacted inside AO to Transfer Pump P-9A verify P-9A running. l running.

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POSITIVE CUE:

P-9A running.

8. Isolate Letdown On panel C04, closed l Cooler. RC to Letdown Coolers, I CV-1213, ir. dica tes l (C) POSITIVE CUE: GREEN.

CV-1213 indicates GREDI.

NEGATIVE CUE:

CV-1213 indicates RED.

END i

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JOB PERFORMANCE MEASURE Page 5 of 6 .

KAA. 008 Kl.02 3.3/3.4 Question: What effect does a loss of RCP Seal Injection to the RCP scais under this condition have?

?

Answer: Atempt to restore seal injection or seal cooling within 2 minutes. Continued operation without seal injection or seal cooling will cause seal damage due to overheating.

Reference Reactor Coolant Pump and Motor Emergency AOP (1203.031) Section 3 page 9.

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1 PROC / WORK PLAN NO. PROCEDURE, WORK Plat.' TITLE: PAIE: 9 cf 25 1203.031 REACTOR COOLANT PUMP AND MOTOR EMERGENCY REV: 13 CHANGE:

l SECT!CN 3 SIMULTANEOUS LOSS OF SEAL INJECTION AND SEAL COOLING FLOW 1.0 2YMPTCMS

• RCP SEAL INJ FLOW LO (K08-A7)

• RCP SEAL COOLING FLOW LO (K08-E7)

• RCP BLEED OFF TEMP HI (K08-C7) 2.0 IMMEDIATE ACTION None.

3.0 FOLLOW-UP ACTIONS CJLUTION Continued RCP operation without seal in]ection or seal cooling will cause seal damage due to overheating.

3.1 Attempt to restore seal injection or seal cooling within 2 minutes, while continuing with this procedure.

3.2 If at least 1 RCP in each loop is unaffected, begin reducing reactor power at maximum rate, using Rapid Plant Shutdown (1203.045), to within limits of unaffected RCP combination.

3.3 If either seal injection or seal cooling cannot be restored within 2 minutes, perform the following:

NOTE

1. High power / pumps reactor trip setpoints are:

. One pump per loop - 155i i

• 3 pumps in ene loop 'O. Trippina 1 RCP with reactor power >925 may result in reactor trip on nigh power /imoalance/ flow.

l 3.3.1 If tripping the affected RCP(s) will result in reactor trip on high power / pumps, perform the following:

A. Trip reactor.

B. Trip affected RCP(s).

C. While continuing with follow-up actions, refer to Emergency Operating Procecure (1202.XXX).

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JOB PERFORMANCE MEASURE ,

Page 6 of 6 '

<&A 008 A3.02 3.2/3.2 Question: Given ICW Pumps P33A and P33C are running, ifICW Pump P33A trips. What automatic actions occur?

Answer: ICW Pump P33B will auto stan (10 see time delay), suction valve (CV-2240) and discharge valve (CV-2238) will open.

Reference Annunciator Corrective Action 1203.012K Rev 31 page 13.

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PROCJWORK Pl>W NC l PROCEDUREJWORK PLAN TITLE: # AGE: 13 Cf 25 I i 1203.031 REACTOR COOLANT PUMP AND MOTOR EMERGENCY REV: 13 CHANGE:

SECTICN 3  ;

3IMULTANECUS LOSS CF SEAL INJEC"'!ON AND SEAL COOLING FLOW l tcontinued) i NOTE

1. If no RCPs are running, a second RCP snould be started ~30 seconds after the first RCP to prevent pump damage due to inadequate flow through the l hydrostatic bearing and pump cavitation. l l

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2. Example of upper cavity seal pressure between 20% and 65% of RCS pressure:

431 psig to 1400 psig with RCS pressure 2155 psig.

3. Example of lower cavity seal pressure between 40% and 80% of RCS pressure:

862 psig to 1724 psig with RCS pressure 2155 psig.

3.7.4 If the following conditions are met, restart RCP(s) as ,

follows: 1 e Upper cavity seal pressure 20% and 65% of RCS pressure  ;

e Lower cavity seal pressure 40% and 80% of RCS pressure

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e Except in case of emergency, at least one RCP already l running or two RCPs available for restart  !

A. Place Seal Injection Flow Interlock Bypass switch for respective RCP(s) in BYPASS.  !

B. Start oil pumps for respective RCP(s).  ;

l C. Start RCP.

1. If only one RCP is running, start the second RCP 730 seconds after the first RCP.

a. If second RCP cannot be started, except in case of emergency, trip running RCP.

D. Step oil pumps fer running FCP(s).

l E. Return Seal In]ection Flow Interlock Bypass switch (es) l to NORMAL.

1 3.7.5 Monitor RCP and seal performance. Verify seal parameters l return to normal.

3.7.6 If any of the following exceed normal limits, stop RCP.

• Cavity pressure e Seal leakage o Pump vibration l

Page 1 of 6 JOB PERF0FF.ANCE MEASURE UNIT: 1 REV # 1 DATE:

TUOZ NUMBER: ANO-1-JPM-RO-RPS01 SYSTEM / DUTY AREA: REACTOR PROTECTION SYSTEM TASK: PLACE A CHANNEL OF RPS IN MANUAL BYPASS JTA#: 10125020101 KA VALUE RO: 3.6 SRO: 3.6 KA

REFERENCE:

012 000 A4.03 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE: SIMULATOR: PERFORM LAB:

POSITION EVALUATED: RO: SRO:

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:

TESTZNG METHOD: SIMULATE: PERFORM:

3XIMATE COMPLETION TIME IN MINUTES: 5 MINUTES REFERENCE (S): 1105.001 REV. 16 PC 1 EXAMINEE'S NAME: SSN - -

EVALUATOR'S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

Start Time Step Time Total Time CIGNED DATE:

TTURE INDICATES THIS JPM MAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A

.!FIED INDIVIDUAL (NOT THE EX7d4INEE) AND IS CURRENT WITH THAT REVISION.

Page 2 of 6

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TUOI NUMBER: ANO-1-JPM-RO-RPS01

.CXAMINER SHALL REVIEW THE TOLLOWING WITH THE EXAMINEE:

Th3 Examiner shal review the " Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.

JPM INITIAL TAKS CONDITIONS: The plant is operating at 100% power with all ICS stations in automatic. A potential problem exists in the "A" RPS cabinet that could lead to a chtnnel trip.

TASK STANDARD: The "A" RPS cabinet is in Manual Bypass TASK PERFOPJRNCE AIDS: Simulator and 1105.001 and the Manual Bypass key.

~ . _ _ _ _ . _. _ - _ _ . . _ . . _ _ _ _ _ . _ _ _ . _ _ .

Page 3 of 6 r

T'JOI NUMBER: ANO-1-JPM-PO-PPS01 I

.. .IATING CUE:

The CRS directs you to place the "A" RPS channel in Manual Bypass.

CRITICAL ELEMENTS (c): 5 C PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT

1. Verify no other RPS channel is Looked in the RPS cabinet in manual bypass. in the back of the control reem and verified no manual Note: Due to the uniqueness of the (or channel) bypass lamps design in the simulator, all are lit or verified that channel indications are located in K08D3, RPS Channel Bypass, one RPS cabinet. annunciator is clear.

POSITIVE CUE: no manual (or channel) bypass lamps are lit or KOBD3 RPS Channel Bypass is clear.

2. Verify no EFIC Channel is in On the EFIC cabinets, Maintenance bypass that does not verified that no correspond to the RPS channel to " Maintenance" lamps are lit l

be placed in manual bypass. for any channel or verified that K12F7, EFIC CH Maint POSITIVE CUE: no " Maintenance" Bypa s s , annunciator clear.

lamps lit for EFIC cabinets or K12F7 EFIC CH Maint Bypass clear.

, 3. Place the SASS Rx Power input On C03, compared NI to ICS selector switch on C03 in indicators and determined the "Y" position, if the ICS needs to be placed in manual operation.

t Note: If a difference exists Then selected the "Y" between compared values of >1%, tne input to ICS for Rx power.

Diamond and Reactor Demand stations of ICS should be placed in Manual.

Note: if simulator and/or plant ccmputer unavailable tell examinee l that all four power range I

instruments indicate the same value.

POSITIVE CUE: "Y" position gelected.

4. Obtain the RPS Manual Bypass From the key locker in the key fros..the SS. SS office or from the ,

examiner, obtained the RPS l l POSITIVE CUE: give key to examinee. Manual Bypass key.

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Page 4 of 6

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NUMBER: ANO J F M- F.0- RPS D 1 a PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT

5. In the RPS cabinet, placed the In the RPS cabinet, key switch for the appropriate inserted the key in the key channel on the selected Rx Trip switch in the "A" Reactor c' module to the bypassd position. Trip Module and placed the C

switch in the bypass Note: In the simulator at this time position.

(5-7-96), the "A" RPS cabinet is laid out as at the plant but is not powered up. Therefore, the examiner will have to cue the examinee as lights change status, etc.

6. Verify the manual bypass lamps Verified the Manual Bypass on the Rx Trip module and the lamp on the Rx Trip Module indicating panel go on bright. went BRIGHT and the Manual Bypass lamp on the Note: The Rx Trip module lamp will indicating panel for "A" not illuminate, so the examinee RPS went BRIGHT.

would have to point out the light.

POSITIVE CUE: manual bypass lamps on bright.

7. Verify Auxiliary Relay lamps Verified Auxiliary Relay for Manual Bypass to EFIC and lamps for Manual Bypass Manual Bypass to annunciator are to EFIC and Manual on bright. Bypass to annunciator are on bright.

NOTE: located in the left side of the RPS cabinent.

POSITIVE CUE: lamps on bright.

8. Verify the associated EFIC On the EFIC cabinet, the channel Maintenance light is " Maintenance" lamp for the flashing. "A" EFIC channel is verified to be flashing.

POSITIVE CUE: light is flashing.

9. Verify the annunciator for RPS On K08, veriflec the CHANNEL BYPASSED (K00-D3) is in annunciator is in alarm for alarm. RPS CHANNEL BYPASSED.

POSITIVE CUE: KOBD3 in alarm.

END

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Page 5 of 6 i i

012 K4.06 3.2/3.5 Question: If the "B" EFIC channel is in bypass and the "A" RPS channel bypass switch is placed in the bypass position what occurs?

Answar: The "A" RPS channel will go to bypass and the "B" EFIC channel will be '

automatically removed f rom bypass even though it's key switch is in the bypass position. I Reference NI & RPS Operating Procedure (1105.001) Rev 16 PC 1 page 11.

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.PROCJWORK PLAN NO. l PROCEDURE / WORK PLAN TITLE: PAGE: 11 Cf 31 1105.001 NI & RPS OPERATING PROCEDURE REV: 16 CHANGE: i 1

'0.0 Placing a RPS Channel in Manual Bypass NOTE Only cne RPS Channel may be placcc in Manual Bypass at a time.

10.1 Determine which RPS Channel is to be placed in Manual Bypass and verify no other RPS Channel in Manual Bypass.

CAUTION Placing a RPS Channel in Manual Bypass will remove any noncorresponding EFIC Channel f rom Maintenance Bypass causing possible EFIC actuation.

10.2 Verify no EFIC Channel in Maintenance Bypass that does not correspond to the RPS Channel to be placed in Manual Bypass.

10.3 Place SASS Neutron Flux selector switch on C03 in the "X" or "Y" position as follows:

10.3.1 Compare Plant Computer point N1I56HI to N1I78HI.

A. If Plant Computer is not available, compare the highest of NI-5 and NI-6 to the highest of NI-7 and NI-8 on C03.

10.3.2 If the difference between the compared values is >l%, place the Diamond and Rx Demand H/A stations in manual.

10.3.3 If placing RPS Channel "A" or "B" in Manual Bypass, place l Neutron Flux selector switch to the "Y" position.

10.3.4 If Placing RP5 Channel "C" or "D" in Manual Bypass, place l Neutren Flux selector switch to the "X" position.

0.3.5 l' ICS H/A statiens were placed in manual for this step, stations may ce returned to to per ICS Cperating Procecure (OP 1105.004), " Transferring ICS Control Stations to Auto" section.

10.4 Cbtain the RPS Manual Bypass key from the Shift Superintencent.

10.5 Place key switch en the selected Rx Trip module to the bypass position and verify the following:

0.5.1 Manual Bypass lamps on the Rx Trip module and indicating panel go on bright.

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Page 6 of 6 j l

.a. 012-K2.01 3.3/3.7 1 1

Question: What is the power supply for the "A" RPS channel cabinet? l 1

Answar: Panel RS-1 breaker 1.

(Breaker number not required fer credit) )

Reference Inverter and 120V Vital AC Ditribution'(1107.003) Rev 8 PC 4 Exhibit A page 135. l l

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PROCJWORK PLAN NO. PROCEDUREMORK PLAN TITLE: PAGE: 136 ~146 9107.003 INVERTER AND 120V VITAL AC DISTRIBUTION RW: 8 CHANGE:

EXHIBIT A OP 1107.003 Exhibit A l PANEL RS1 REVISED 9/18/96 4

l Power Source: Inverter Y11 o_r Y15 l Location: Control room i NOTE: All breakers except spares should be closed.

l 1 "A" RPS Cabinet C41 2 ESAS Analog-1 Panel C88 l

l 3 Spare 4 ESAS Digital-1 Panel C86 Reactor Building Pressure 5 CRD #1 C49 6 Transmitter PT-2400 to "A" RPS l

CV-7910 position indication C19 LPI/ Decay Heat Pump Brg. CLR E-50A Rad. Monitor Panel C24 7 Inlet CV-3840 and C1B Indication 8 Rad. Monitor Panel C25 Bay 1 9 NNI X C47 Normal Supply 10 Auxiliary Equipment Panel C486-1 H: Analyzer C178 11 SV-1840 - Hot Leg Sample Isol. 12 EFIC Channel A Panel C37-1 l

Instrument Cabinet C544 l 13 Panel C09 14 (ICS Room)

EFIC Trip Interface Instrumentation 15 Panels C511 and C513 16 Cabinet C539 l Penetration Room Ventilation 17 Panels C03 & C04 Indicator Power 18 Flow Switch C28 i

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ADMINISTRATIVE SECTION TEST #1 SRO ADMINISTRATIVE OUESTION Page 1 of 12  ;

-Operating Test i SRO Subject A1 (Closed Reference)

QUESTION Al-1:

Reference:

K&A 2.1.4. 2.3/3.4 One hour aAer shiA turnover the CBO Reactor is called home for a medical emergency. No replacement watch  !

stander is on site. How long do you have to obtain a replacement watch stander?

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f ANSWER: 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. l L

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REFERENCE:

Conduct of Operations (1015.001) page 35. i t

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PROCAWORK PLAN NO. PROCEDURE / WORK PLAH Tm.E: PAGE: 35 cf 55 1015.001 CONDUCT OF OPERATIONS REV: 50 CHANGE:

9.5.14 Potential situations which have or could result in the degradation of plant security barriers or security systems such as:

• Removal of portions of protected or vital area barriers, including fences, hatches, or portals that allow unauthorized access to the protected area or vital areas e Removal of. equipment that had formed part of the barrier, such as piping or valves that would allow passage of small objects into or out of a vital area e Creation of holes in protected and vital area barriers l to facilitate construction or modifications 1

10.0 SHIFT TURNOVER AND RELIEF 10.1 On duty Shift Operating Personnel shall be relieved at their assigned duty station by qualified oncoming Shift Operating Personnel or other qualified individuals assigned by the on duty Shift Superintendent.

I 10.2 When it is obvious that a person is not capable of assuming watch I

duties, proceed as follows:

• Shift turnover shall not be made to relief personnel

• The Shift Superintendent shall be apprised of relief personnel reporting for work under the apparent influence of alcohol or drugs,_obviously physically ill, or in such a psychological or emotional state that his effectiveness may be impaired 1

1 10.3 The minimum shif t complement requirements delineated on Attachment 1 as appropriate shall not be violated, except as stated below:

1

• When unexpected incapacitation or other loss of on duty crew memners occurs, shift crew composition may be less than the nunimum requirements for a period of time not to exceed 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, provided immediate action is taken to restore the snift crew composition to within the minimum requirements.

10.4 Prior to normal relief time, On-Duty crew members shall complete the applicable portions of the turnover document (Shift Relief Sheet Form l 1015.015A or 1015.016A) and sign the blanks provided on the Shift l Relief Sheet.

10.5 The Shift Superintendent being relieved should easure completion of the Shift Relief Sheet, Form 1015.015A or 1015.016A, as applicable, to assist in the transfer of informatien to oncoming licensed personnel.

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ADMINISTRATIVE SECTION TEST 01 SRO ADMINISTRATIVE OUESTION Page 2 of 12 EXAMINEES COPY l QUESTION Al 1;(Closed Reference)

One hour aAer shiA turnover the CBO Reactor is called home for a medical emergency. No replacement watch stander is on site. How long do you have to obtain a replacement watch stander?

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ADMINISTRATIVE SECTION TEST #1 SRO ADMINISTRATIVE OUESTION -

Page 3 of 12 Opemung Test i SRO Subject A1 (Closed Reference)

QUESTION A1-2:

Reference:

K&A 2.1.21 3.1/3.2 List two locations you can obtain a controlled copy of a procedure?

ANSWER:

Controlled copies of procedures can be obtained from the following locations:

1. Document Controlfiles

2. Document Control Satellite Files

3. Control Room binders.

REFERENCE:

Procedure Control (1000.006) Rev 46 PC 1 page 32 COMMENTS:

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PROC./ WORK PLAN NO. PAOCEDURE/ WORK PLAN TITLE: l PACE: 32 cf 80

'1000.006 PROCEDURE CONTROL REV: 46 CHANGE:

E.6.4 :f curing the performance cf Abncrmal Cperatins Procecures, plant : nditiens are rest: rec sucn that :entinuing tne procecure would be inappropriate, then an SRO may autnerire operations perscnnel to exit the procecure.

6.6.5 When not directly referencing the procecure, tne procedure user is still responsible for performing the activity as specified in the procedure. The decision to have a procedure in hand and directly referenced should be based on the following: (OCAN098704)

A. Qualifications and experience of procedure user.

B. The repetitive or routine nature of the activity.

C. The importance of the activity with respect to plant safety and availability.

D. The overall complex _ y of the job.

E. Individuals performing procedures having specific steps wnich must be initialed should have a copy of the procedure in their possession unless they are being directed step by step by an individual with a copy of the procedure.

F. Initial steps may be initialed by an individual in direct contact with the procedure user in the field who has performed a step. For large, complex procedures, the procedure user need only have a copy of the section he is performing.

6.6.6 Controlled copies of procedures that are required to be used during the performance of tests or work shall be made from Document Control files, Document Control Satellite files, er tne Control Room binders. PM procedures may also ce :ssuec from any of these locations or generated cy SIMS.

Chemistry procecures are cen---ileo procecures anc can ce useo from any Chemistry work 1; cation for chemistry relatec tasks.

6.6.7 The Controlled Copies of procedures shall be considered valid fer use for a perico not to exceed seven 7) days.

Use of tne procedure may continue provided the user verifles that the procedure remains current, once every seven C) days. Copies shall contnin the date, time and signature of the indivicual verifying that the copy is valid for use.

d.6.3 Supplements, attacnments, anc f:rms should be verified to ensure that the current revision is being useo. However, the ::py coes not require documented verification.  :: :s eacn Organi:aticn's responsici.it', to implement guacance ::

ontrol tne use f cupplementz, attacnments anc forms.

1:0-:90-21

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ADMINISTRATIVE SECTION TEST 01 SRO I ADMINISTRATIVE OUESTION l Page 4 of 12 J

' EXAMINEES COPY 1 l

I Operating Test'l SRO (Closed Reference) . '

1

- QUESTION Al 2: l 3

' List two locations you can obtain a controlled copy of a procedure? l 1

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i ADMINISTRATIVE SECTION TEST 01 SRO ADMINISTRATIVE OUESTION  ;

Page 5 of 12 l l Operating Test i SRO Subject A2 (Open Reference) l QUESTION A2-1:

Reference:

K&A 2.2.7 2.0/3.2

An emergency situation exists that requires immediate action to protect the health and safety of the public. No procedural guidance exists to cover this event. List 3 of 5 actions required when you desiate from license conditions or technical speciDcations.

ANSWER:

1. Ensure no action consistent with technical speci6 cations can provide adequate or equivalent protection.

2. Obtain SS/CRS (SRO) approval prior to taking the action.

3. Repon the deviation within I hour to NRC as a 50.54(x) desiation.

4. Make appropriate station log entries.

5. Document actions taken for evaluation of possible procedure changes.

REFERENCE:

Procedure Control (1000.006) Rev 46 PC 1 page 31. l 1

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FROC.MORK PLAN NO. PZOCEDURE/ WORK PLAN TITLE: PAGE: 31 cf 80 'i 1000.006 PROCEDURE CONTROL REV: 46

, CHANGE: ,

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6.5 9 If an emergency s;tuatien requires immeciate action te l

protect puolic nealth ano safety, to prevent persennel in]ury, or to prevent equipment damage, anc the action j conflicts with precedural requirements, then the fellowing  ;

steps shall ce taxen:

l A. If time permits, obtain approval from the SS/CRS prior ,

to taking the actien; otherwise, complete the action i and notify the SS/CRS 1mmeciately thereafter. l l

B. Issue a Condition Report.  :

1 6.5.9 If an emergency situation requires immediate. action to l protect public health and safety, to prevent personnel in]ury, or to prevent equipment damage, and the action .{

requires departure from license conditions or technical specifications, then the following steps shall be taken:

A. Ensure that no action consistent with the technical specifications can provide adequate or equivalent protection.

B. Obtain approval from the SS/CRS prior to taking the action. (OCNA038618)

C. Report the event within one hour in accordance with 10CFR50.72 (bl (l) (1) (B) (Deviation from Technical Specifications authorized by 10CFR50.54(x)).

D. Make appropriate entry in the Station Log.

l l E. Document actions taken for evaluation of possible procedure changes.

6.6 PROCEDURE USE .;CAN048903) 10CAN089204) 6.6.. Many procecures are written with sect.:ns navine a clearl, refinec purp se. These sect 1:ns may e asec :: per::rm an I

activity without per:0rming ne entire precedure. :n su:n

ases, :nitia. Concita:ns, Prerequisites, Limits anc Precauti:ns anc Festoraticn shall be understoca anc verifiec, as they apply to the activity to be performed, I prier to proceauze use.

6.6.2 Maintenance :co crders may specify partial performance of specif:: steps or sections of a procedure to support  ;

troubleshooting, :orrective maintenance, or l post-maintenance test.ng. i 6.c.3 If a prececure centre 111ng the operation of a system or i

omponent exists, equipment may be operated within tne l

. mits Of tne procecure t: :cliect coerational data flow, j pressure, etc... In suen :ases, a new prc:ecure er worr. l pian :: no: requirec.

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ADMINISTRATIVE SECTION TEST 01 SRO l ADMINISTRATIVE OUESTION  :

Page 6 of12 EXAMINEES COPY i

i i-Operating Test 1 SRO (Open Reference)

QUESTION A2-1 i l' What is the Federal Limit for Occupational Whole Body (TEDE) exposure? +

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ADMINISTRATIVE SECTION TEST 01 SRO ADMINISTRATIVE OUESTION  ;

Page 7 of 12 }

Operating Test 1 SRO Subject A2 (Closed Reference) l

! QUESTION A2-2:

Reference:

K&A 2.2.21 2.3/3.5 l

j Who is responsible for determining surveillance requirements for equipment prior to returning to senice after  ;

! maintenance?  !

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ANSWER: Operations Personnel i I l l l l

REFERENCE:

Control of Maintenance (1000.024) Rev 44 page 13 & 14.  !

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PROC. WORK PLAN NO. PROCEDUREWORK PLAN TTTLE: PAIE: 13 cf 74 CONTROL OF MAINTENANCE REV: 44 1000.02A CHANGE:

a Pil659 (OCNA087919) 5.4 PIANNING AND SCHEDULING (P&S) 5.4.1 Initiate and schedule Repetitive Task Job Orders for Preventive Maintenance (PM), Mandatory Preventive Maintenance (MPM), Environmental Qualification (EVQ),

Surveillsace Test (ST), Inservice Inspection (ISI), i Refueling (RFI.) , and rianned Maintenance (PIM) .

5.4.2 Establish priorities on approved job requests and reject duplicates. Additionally, job requests affecting plant operations are concurrently reviewed by operations liaison personnel.

5.4.3 Convert approved job requests into job orders.

5.4.4 Plan work activities and assemble work packages.

5.4.5 Develop a schedule of work activities, issue work packages .

and coordinate the performance of the scheduled work j activities. l 5.4.6 Screen job requests for items constituting minor maintenance and provide these JRs to the applicable discipline Superintendents for correction.

P9058 (OCAN06B420) 5.4.7 Obtain input from Engineering when necessary to support a Job Order. ,

s A. The following is examples of when Engineering Support may be required:

• Multiple equipment failures e Obsolete parts i e Complex task with high risk factor e PMT review and requirements e High risk systems as listed in ANO P&S Liaison Desk Guide.

5.4.8 For modifications being performed by Maintenance, update the following Modifications Database fields: Cutage No.,

Remarks and Date Installation Began.

5.5 OPERATIONS PERSONNEL 5.5.1 Provide cperations input to P&S to assist planners in the development of work packages.

5.5.2 Determine technical specification time limits for the work, tagout and release equipment for work wnen applicaele.

_ _ . _ _ . - _ _ _ , . __ _ _ _ _ _ .m ._ _ _ . . ..___ _ __ _ . _ . _ . _ _ _ _ . _ _ _ _

I PROC.fWORK PLAN NO, PROCEDURElWORK PLAN TITLE: PAGE: 14 Cf 74 [

1000.024 CONTROL OF MAINTENANCE RR 44 CHANGE:

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{ P6767 (0CAN06BS10) 5.5.3 Perform applicable post-maintenance testing.

lP6767 (OCAN06SS10) 5.5.4 Identify and perform required surveillance tests after any maintenance activities which correct equipment failures, or -

which might change equipment characteristics.

5.5.5 Review the impact statement and concur that the work may commence with the existing plant condition. l 5.5.6 May add Operations Hold points in the body of a Job Order.

These hold points may be handwritten or stamped. The l intent is to allow the Shift Superintendent to insert hold l points such that work may begin or continue that has no ,

plant impact while later approving sections of the job to ]

begin that do impact the plant. It is preferred that j Planning be involved when operation hold points are added j to a Job Order. 2 l

1 5.6 MAINTENANCE PERSONNEL 1 l

5.6.1 Perform and document the work required by the job order.

i 5.6.2 Prepare work plans and procedures when necessary to support '

i a job order.

5.6.3 Perform research and requisition parts as necessary to support a job order. If the job order is to be returned to P&S for material hold, include all applicable parts j l information (stock number, manufacturer, etc.) and the j purchase requisition. '

l P6767 (OCAN06BS10) 5.6.4 Perform applicable post-maintenance testing.

5.6.5 Review 3cb order packages to ensure understanding scepe anc complexity before commencement of work.

5.6.6 Prov2.de adequate documentation of Priority 1 repairs.

5.6.7 Obtain Technical Assistance from Engineering when necessary to support a Job order.

5.6.8 Report plant material condition discrepancies to the applicable Maintenance Superintendent for inclusion into minor maintenance work activities.

5.6.9 Provide manpower availability input to the scheduling section of P&S as required.

5.6.10 Develop maintenance history from completed job orders and associated information.

l l t 5,6.11 Perferm planning functions for repetitive tasks and Scb  !

4 orcers as appropriate in accordance with the Planner'r Desk s Guice, NPS 922008.

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i ADMINISTRATIVE SECTION TEST 01 SRO ADMINISTRATIVE OUESTION Page 8 of 12

. EXAMINEES COPY Operating Test 1 (Closed Reference)

QUESTION A2-2:

Who is responsible for determining suncillance requirements for equipment prior to returning to senice after maintenance?

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i ADMINISTRATIVE SECTION TESTdi SRO l ADMINISTRATIVE OUESTION -

Page 9 of12 Operating Test i SRO Subject A3 (Open Reference)

QUESTION A31: Reference; K&A 2.3.7 2.0/3.3 When the need for an RWP is identified, how can radiological conditions for the proposed work area be obtained?

I' l ANSWER: Live-time information

!- Routine survey data Historicalinformation Anticipated conditions

REFERENCE:

Radiological Work Permits (1012.019) Rev 6 PC 1 page 7 I'

COMMENTS:

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i PROCJWORK PLAN NO. PROCEDURE / WORK PLAN TITLE: PAGE: 7 Cf 19 1012.019 RADIOLOGICAL WORK PERMITS REV: 6 CHANGE:

6.2 INITIATION AND PROCESSING 6.2.1 When the need for an RWP is identified, determine the following:

A. Radiological conditions for the proposed work area using one or more of the following methods:

(OCAN089702) e live-time information e routine survey dat.

e historical information e anticipated conditions B. The dose estimate to do the job, l

C. The anticipated impact of the work on radiological I conditions in the proposed work area, D. Radiological controls anticipated. Controls must be consistent with applicable requirements of 1601.300,

" Job Coverage".

E. .The requirement for a pre-job briefing, F. The need for independent dose tracking.

6.2.2 WHEN, based on the information obtained in 6.2.1:

A. The estimated dose is less than .1 person-rem and the estimated effective dose rate is less than 2.5 mrem /RWP-hr., AND B. There is no need to track dose independently, AND C. A pre-job briefing is neither required nor desired; THEN, identify the Stand--d RWP that adequataiv addresses the radiological protection controls for the work to be perfermed. i 6.2.3 Assign the RWP number to the apprcpriate work document and route for further processing.

6.2.4 WHEN: the estimated dose is greater than or equal to .1 person-rem and the estimated ef f ect ive dose rate is greater than or equal to 2.5 mrem /RWP-hr.,

THEN perform the following:

A. Input the required job information for the RWP in the computer program.

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i ADMINISTRATIVE SECTION TESTG1 SRO r

, ADMINISTRATIVE OUESTION i

Page 10 of 12 l EXAMINEES COPY l i

Operating Test 1 (Open Reference)

QUESTION A3-1:

When the need for an RWP is identified, how can radiological conditions for the proposed work area be obtained?  ;

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ADMINISTRATIVE SECTION TESTal SRO i ADMINISTRATIVE OUESTION I Page 11 of 12 Operating Test 1 SRO Subject A3 (Closed Reference) i QUESTION A3-2:

Reference:

K&A 2.3.8 2.3/3.2  !

i Whose approval is required to submit a Reactor Building Purge Gaseous Release Permit? l l

ANSWER: ShiA Superintendent l j

REFERENCE:

Reactor Building Ventilation (1104.033) Rev $5 PC 4 Attachment B page 23.

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. _ _ _ _ . _ -. - . . . _ ___ ._ . . . . _ . _ _ . _ . _ . . ~ . _ _ _ . . . . . . . _ . ~ . _ _ _ _ _ . _

PROC / WORK PLAN NO. - l PROCEDUREAMORK PLAN TITLE: PAGE: 23cf57  ;

1104.033 REACTOR BUILDING VENTILATION REV; 55 1

{ CHANCE:

I ' I ATTACHMENT 3 Page 1 of 9 REACTOR BUILDING PURGE GASEOUS RELEASE PERMIT Permit n Date (Assigned by Nuclear Chemistry)

INITIALS 1.0 Request (Operations) r 1.1 Indicated stack flow prior to purge x 10' CfH 1.2 Indicated RB pressure prior to purge psig j 1.3 Request I&C Tech to perform SPING 1 (RX-9820) Channel l' Functional Test 1304.076.

1.4 Shift Superintendent approval (Signature) 1.5 Submitted to Nuclear Chemistry.

Date Time 2.0 Analysis (Nuclear Chemistryl 2.1 Containment air samples obtained for gamma spectroscopy by 2.1.1 Record METE number Cal Due Date 2.2 Gamma spectroscopy analysis performed by .

i 2.3 Gamma spectrescopy report reviewed by .

2.4 Preliminary release report generated by .

3.0 SPING Validation Prior to Purge (Nuclear Chemistry) 3.1 Verify SPING 1 (RX-9820) Channel Functional Test 1304.076 successfully performeo and sample pump restartec. l 3.2 Verify SPING 1 cperable by performing a source check per "Eberline Radiation Monitoring System", 1604.051 Attachment 5.

~3.3 Verify'SPING 1 channels 1, 3, 5, 7, 9, 10, 14, and 15 operable per 1604.051 Attachment 4.

3.4 Set new SPING 1 channel 5 and 7 alarm setpoint(s) as applicable per " Determining Setpoints For Gaseous Releases" Form 1604.051E and 1604.051.

L 3.5 Edit the 1sotcpic Distribution using analysis data per 1604.C51.

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ADMINISTRATIVE SECTION TEST 01 SRO ADMINISTRATIVE Ot!ESTION Page 12 of12 EXAMINEES COPY

' Operaung Test 1 (Closed Reference)

QUESTION A3-2:

Whose approval is required to submit a Reactor Building Purge Gaseous Reicase Permit?

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ADMINISTRATIVE SECTION TEST 01 SRO ADMINISTR ATIVE JPM Page 1 of 3 Operating Test 1 SRO Al (JPM-1)

Reference:

K&A 2.1.17 3.5/3.6 initiating cue:

A fire is reported on El 317' of the auxiliary building in the Dirty Liquid Waste Panel. Make appropriate announcernents and pages.

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Reference:

Smoke, Fire or Explosion AOP (1203.034) Rev 11 Section 2 page 4.

ANO Prefire Plan Unit i Vol IB Zone 4EE Standard:

1. Momentarily depress the Fire and Medical Tone Pushbutton.

2. Make the following announcement twice:

e Attention all personnel. Attention all penonnel. There is a fire in the Unit 1 Auxiliary Building, elevation 317*. The ANO Fire Brigade is responding. All other personnel stay clear of Unit 1 Auxiliary Building, elevation 317',

3. Determine affected fire zone number and name using the prefire plan. (Fire Zone 4EE General Access Area)-

4. Inform Fire Brigade of the fire zone number and name using tim emergency pagers or the plant page system.

COMMENTS:

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, l, . PROCJWORK PLAN NO., { PROCEDURE / WORK PLAN TITLE: PAGE: 4cf12 3

l 1203.034 SMOKE, FIRE OR EXPLOSION REV: 11 1 CHANGE:

SECTICN 2 - FIRE OR EXPLOSICN 1.0 SYMPTCMS l

One or more of the following:

1.1 Report of fire or explosion.

1.2 Annunciator FIRE (K12-A1) alarm and confirmation of fire.

1.3 Annunciator TURBINE MAIN GEN CO2 SYSTEM TROUBLE (K16-C2) alarm and confirmation of turbine generator bearing fire.

2.0 IMMEDIATE ACTION 2.1 Activate the Fire Brigade emergency pagers using instructions on the l base radio.

l l 3.0 FOLLOW-UP ACTIONS -- CONTROL ROOM SUPERVISOR 3.1 Momentarily depress the Fire and Medical Tone pushbutton.

i 3.2 Make the following announcement twice: l l

l

" Attention all personnell Attention alJ personnell There is a fire in ... (give location).

The ANO Fire Brigade is responding.

All other personnel should stay clear of the (give location)." l l

3.3 Determine affected fire zone number and name using Pre-Fire Plan,

" Fire Zone / Fire Area Cross Reference" tab.

l 1.4 When proper fire rene number and name are determined, inform Fire Brigade using the emergency pagers or the plant page system.

l NOTE

-he eni, assureo communication tool is tne por*' ole radio. The clai 1 te.epnene anc Galtrenics are cackups.

I.5 Monitor Maintenance / Emergency Team radio channel - CH 1.

2.6 g any in3ured personnel, activate the Emergency Medical Team emergency pagers using instructions on the base radio and refer to Personnel Emergency (1903.023).

l

T!RE 2:NE. 4-EE SENERA* ACCEC AP EA EL. .~ rT FIRE AREA B

1.0 OCCUPANCIES

Normally unmanned.

2.0 FIRE BRIGADE ACCESS:

By Stairway No. I to elevation 317', thru Door #7. ionly means of access) 3.0 PLANT PERSONNEL EGRESS:

Only egress route is Stairway No. 1, Door #7 to elevations above.

4.0 LIGHTING / COMMUNICATIONS:

DC powered emergency lighting in zone and at stairwell door for equipment and access lighting. Gaitronics call station G-14 on west end of Radwaste Processing Area (Zone 20-Y) at el. 335', Call station G-13 is located in :ene east of Stairway No. 1.

NOTE: The only assured means of communication is portable radio. If phones or gai-tronics are operable, they can be used as secondary means.

5.0 BARRIERS SEPARATING REDUNDANT SAFE SHUTDOWN EQUIPMENT:

None

6.0 HAZARDS

MATERIAL CLASS 6.1 Fire: Oil, Cleaning Solvent B Other Combust. A Transient materials A/B 6.2 Radias an: :entrolled Access. Low te mocerate in most areas. The following portions of the :ene are considerea h ch radiation areas:

Rm. 1 Quench Tank Transfer Pump (Door 163)

Rm. 2 Aux. Bldg. Drain Transfer Pump (Door 163)

Pa. 3 Aux. Bldg. Equipment Drain Tank (Door 1) (Locked High Rad-Hot Particle Red Zone)

Rm. 5 Crud Burst Filter (Door 155)

Rm. 5A Dirty Waste Filters Rm. 7 Dirty Waste Drain Pumps Rm. 8 Dirty Waste Drain Tank Rm. Q Filtered Waste Monitor Tank and Pumps (Limited Accessi 6.3 Hazardous Substances: None 6.4 Physleal Hazards:

. Multiple small :::ms ::uld result ;n personnel d sorientation.

e Valve pit at south enc near entrance 2:ne 12-EE.

• Sump p;; at nortn ena west f Sta:rway 'i c . .

1E317002. DOC IB-4-EE-1 REV. O

-I 1

6.5 Elettrical Ha: arcs:

Electrical Eculement Circuit Breakers Dirty Liquid Radwaste Control C113 & K112

& Annun.

Power Panel PP #1 52-3186B (B31)

Laundry Drain' Pump P45 52-3134 (B31)

Aux. Bldg. Sump Pump PSIA 52-3141 (B31)

Aux. Bldg. Sump Pump PS1B 52-4141 (B41)

Quench Tank Transfer Pump P44 52-3122 (B31)

Aux. Bldg.' Drain Transfer Pump P46 52-3136 (B31)

Filtered Waste Pump PS3A 52-3126 (B31)

Filtered Waste Pump PS3B 52-4126 (B41)

Dirty Waste Drain Pump PS2A 52-3132 (B31)

Dirty Waste Drain Pump PS2B 52-4132 (B41)

Radwaste Filter Crane L13A Brker. 31 (PP1) 6.6 Compressed Gases:

A) Cylinders (self-contained): None identified B) Non-self-contained: None identified

'7.0 FIXED FIRE SYSTEMS:

Suppression: None Detection: None.

8.0 MANUAL SUPPRESSION:

Portable Extinguishers:

• ABC-112 outside doorway to Stairway No. 1 in Radwaste Processing Area (Zone. 20-Y) at el. 335'.

• ABC-190 in west end of Radwaste Processing Area (Zone 20-Y) at - e1.

335'. In Zone:

'e CO2-230 near door #6.

Hose Reel Stations; e HR-28 outside doorway to Stairway No. 1 in Radwaste Processing Area (Zone 20-Yl at el. 335' (Primary) e HR-26.in south end of Radwaste Processing Area (Zone 20-Y) at el. 335'

'(Secondary)

. NOTE: Use_of Secondary hose reel station will probably require extra lengths ,

L of hose for extension. H 1

LIn Zone:

1

e HR-49 south of door #6. (Secondary) i

!- i 1

1E317002. DOC *B-4-EE-2 REV, 0

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^ .: /ENTI1.ATICN :

.1 Fixec System control

a. Supply Fans Damper Handswitch Panel Normal VSF7B FD-150-135 HS-7620 MCCB15 FD-79-195 FD-79-196 l FD-23-10 l

l CV2113 CV2106 i

l Emergency -- -- -- --

1 Exhaust VEF8A FD-23-9 HS-7603(A) C-350 l VEF8B FD-79-193 HS-7604(B) C-350 I FD-79-194 l CV2103 j l CV2104 i CV2116 CV7603 l CV7604

9.2 Manual

None 10.0 AFFECTED COMPONENTS OF INTEREST:

COMPONENT DESCRIPTION CV-3822 DH Cooler (E35A) SW Inlet I ,

CABLES AFFECTING OTHER COMPONENTS OF INTEREST:  !

None 11.3 AVAILABLE SAFE SHUTDCWN INSTRUMENTATICU All sources of assured safe shutdown instrumentstlen are available :Or a fire in this fire zone. See " Components of Interest" list in the Introduction Section of the Pre Fire Plans.

12.0 GUIDELINES FOR FIRE ATTACK:

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! 12.1 Staging Area Location:

Stairway No. 1 Alternate: Radwaste Processing Area Corridor (Zone 20-Y) at el. 335'.

1E317002. DOC 1B-4-EE-3 REV. C 1-l

1 1

. .: trategie::

• Entry made by 2 Brigace Memcers with extinguishers tunless fire is !

obviously oeyonc capabilities of extinguishers > to cetermine I extent of fire, and to extinguish fire, if acle.

• A brigade member should extend a hoseline to ene entryway and standby. An additional member should standby to charge the hoseline and assure it is unobstructed up to entry point.

• If the members making entry are unable to extinguish the fire, they should return to the staging area for hoseline. A brigade member should consider extending a secondary hoseline. An i additional memoer should provide reconnaissance of exterior :ene l boundaries for fire extension.

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• If fire is not controlled at this point, additional resources and manpower may be required.

13.0 SPECIAL PRECAUTIONS / NOTES:

• Primary hose station use requires penetration of two fire door openings.

1E317002.00C "B-4-EE-4

_ REV. O

I i (2 U

, } PUMP TANK j, ROOM ROOM

?j FILTE R Y 2 ~"

• 000R NUMBERS ROLLING ;j \ / ,'] HOOM 4 sI ' 5 & 6 ARE WATER-FIRE N y y TIGHT DOORS DOCR 483 :,y 1 CEIUNG) .l

'

• DOOR NUMBER 1 FLTER PUMP 8 TANK LOCKED HI RAD

1. ROOM 155 ROOM ly- .

E 'CHAN 0-13 ." y STAIR  :

GENNL EESS MA NO.I N  :" " "'-

4 '

4-EE 162-A __..; L 5 EAST DECAY HEAT IO-EE

,n- , ,,i, , . .1 ' REMOVAL PUMP RM.

SUMP ME PtT 230/\'

~

PIT CHAlNC A 49 GALLERY CCESS 6 i RM i 3 J

/y.

'53

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• 12-EE 8'5'RIMP WEST DECAY HEAT -

ROOM 2 REMOVAL PUMP RM.

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-:2 ENTERGY r=  :

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E ADMINISTRATIVE SECTION TEST 01 SRO ADMINISTRATIVE JPM j Page 2 of 3 '

Operating Test 1 SRO A4 (JPM-2)

Reference:

K&A 2.4.40 2.3/4.0 l

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Initiating cue:

Given the following information determine the appropriate Emergency Action lael.

JSU#1 Transformer Lock Out relay tripped on sudden gas pressure.

• SU#2 Transformer ou of service due to bushing damage.

• Reactor and Turbine are tripped.

e #1 EDG Overcrank Annunciator (K01-B2) alarmed 20 minutes ago.

e #2 EDG has failed to start automatically or manually from the control room. Actions have been in progress to start locally for ~18 minutes.

• Alternate AC generator tripped during start and is being reset.

i

Reference:

Emergency Actic' Level Classification (IN3.010) Rev 34 PC 1 EAL 4.3 page 33.

Standard:

Determine that station Blackout for >l5 nunutes enteria has been met and declare a Site Area Emergency based on EAL 4.3 criteria COMMENTS:

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r MOC./ WORK PLAN NO. I PROCEDURE / WORK PLAN TITLE: PAIE: 33cf124 1903.010 l

EMERGENCY ACTION LEVEL CLASSIFICATION l' REV: 34 l l CHANGE:

ATTACHMENT 3 UNIT ;

ELECTRICAL FOWER FAILURES 4.3

!*,NDIT:CN :

I' 514ckout for more than 15 minutes.

tMERGENCY CLASSIFICATION:

Site Area Emergency MODES All

'AITERIA:

1 i

1. All 4160V buses de-energized for greater than 15 minutes.

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ELATEC F *nL; : TAB 1-I Electrical Power Failures 4 Loss Of Centrcl Room Annunciatcrs 6 Core Melt 1 I

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ADMINISTRATIVE SECTION T EST 01 SRO  !

ADMINISTRATIVE JPM

! Page 3 of 3 l Operating Test 1 SRO A2 (JPM-3-OITIONAL))

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l l' l HOLD CARD Authorization Form (1000.27A) coanpleted with missing craft signatuur authorizing release, l missing Authorization Removal signature, and no removal sequence specified. ,

1 i

Reference:

KAA 2.2.13 3.6/3.8 i 1

Initiating cue:

I CRS directs you to remove hold cards using the attached Hold Card Authorization Form (1000.027A).

Reference:

Hold and Caution Card Control (1000.027) Rev 24 PC 2 pages 22-23 Standard:

Review of form 1000.027A reveals incomplete craft signatures, no removal authorization signature and no removal sequence specified.

COMMENTS:

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COPY ENT.f2"Y CPERATIONl INCO!PORATED COPY Arkansas Nuclear One

Title:

HOLD CARD AUTHORIZATION FORM Form No. 1000.027A Revised 11/10/97 Date: 05/10/98 UNIT 1: 1 UNIT 2: BOTH: HOLD CARD SERIAL NUMBER: 98-1-0992 Affected System: C8 Reason / Scope of Tagout: REPAIR P2A PUMP / MOTOR.

Sp::cial Conditions Required / Remarks: PUMP / MOTOR CATA8 TROPHICALLY FAILED, CRAFT TAKE NEE DED PRECAUTIONS.

E3C6-1 PROCEDURE ISSUED ACCEPTED A m RELEASED OR WORK COMPONENT PREPARED VERIFIED ADEQ TO srEC co m REVIEWED BY LEAD ACTIVITY BEING BY BY VER EXT / BY LEAD CRAFISMAN DATE CRAFTSMAN DATE NUMBER WORKED INIT (PRINT) (stGNATURE)

O/ (OSIGNgTURE) .

0G978414 P-2A DAVID BICE l[ C, d ,, 9 pfgM(( y/, ,/'y [%(Q j_y,f ,

00978416 P-2A DAVID BICE [hg d[ [( g yyyjQ hhg /j [ gg h,'Aj CC978419 P-2A DAVID BICE [kjMT .

f /g ycoy

[gg,

/Wp+r.W e sk vd

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/ M kh_.A k l TAGOUT AUTH)dess ;, 48$gdY" TAGOUT REMOVAL l pp ;m G:

}

Verify all Released by Signatures obtained.

[g Designate removal sequence and position.

'pM.-

1. .) -

If required, verify 1000.027N complete.

Is Restoration Verification Required? [ ]Yes [ ]No If NO, then N/A Verification blanks.

Operator: , _

Date l

APPROVED INS LL: s W '

YAL Operations Superv M r [ ate - Op N tibs Supervisor '

Date

PAGF. 40 " 56 Ilul.D t'AHD AUTilORIZATIOli FOPN PAGE 1 OF 2 EllTERGY OPERATIOtJS INCORPORATED ,

Ar kansas fluclea r One Page 1 of 2  ;

Title:

ilOLD CARD AUTilORIZATIOll FORN l Form No. 1000.027A Revised 11/10/97 i

Date: __ _

Ulli T 1: 1I UtilT 2: II BOTil: (l IIOLD CARD SERIAL NUMBER: ,

Atfected System: _ Reason / Scope of Tagout: -

Special Conditions Required / Remarks: _ l PROCEDURE COMPONENT PREPARED VERI FI ED ADEQ ISSUED ACCEPTED AND pgggASgp gy .

OR WORK BEING BY BY VER TO SPEC COND LEAD ACTIVITY WORKED INIT EXT # REVIEWED BY DATE DATE L CRAFTSMAN 11 UMBER ( PRIflT ) (SIGNATURE)

FT MAN (SIGNATURE)  %

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TAGOUT AUTHORIZATION TAGOUT REMOVAL

• Verify all Released By signatures obtained.

• Designate removal position and sequence. i e If required, then verify 1000.027N complete. j e Is Restoration Verification required? Yes tio If No, then N/A Verification blanks.

Operator Date APPROVED REMOVAL  ;

TO INSTALL Operations Supervisor Date APPROVAL Operations Supervisor Date l e

l form title: form no. rev. ,

Hold Card Authorization Form 1000.027 A 24 i

p JOB PERFORMANCE MEASURE Page 1 of 6 UNIT 1: X REV # 7 _ DATE:

\

..sI NUMBER: ANO-1-JPM-RO-AOP03 SYSTEM: Emergency and Abnormal Operations TASK RO2 alternate shutdown follow-up actions immediate evacuation.

JTA 13035210401 KA VALUE RO: 4.3 SRO: 4.5 KA

REFERENCE:

A06 AA1.02 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR OUTSIDE CR: X BOTH:

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE: Simulate . SIMULATOR: LAB:

POSITION EVALUATED: RO: SRO:

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:

TESTING METHOD: SIMULATE: PERFORM:

APPROXIMATE COMPLETION TIME IN MINUTES: 9 minutes

'ERENCE (S ) : AOP 1203.002, Rev. 13 PC-4(Section 1D) i

• EXAMINEE'S NAME: SSN: - -

EVALUATOR'S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

z f SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST CO!hCMTS:

Start Time Stop Time Total Time SIGNED DATE:

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

(

3 JOB PERFORMANCE MEASURE i Page 2 of 6

"E EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

.as examiner shall review the " Briefing Checklist - System Walkthrough" portion of OP1064.023 Attachment 6 with the examinee.

JPW INITIAL TASK CONDITIONS: A fire in the control room threatens imediate d mage to a maior portion of vital controls. Tnerefore, there has been an immediate control room evacuation. AOP 1203.002 Section ID complete through Step 3.3.

TASK STANDARD: Steps 3.4 through 3.9 Reactor Operator #2 foljowup actions of AOP 1203.002, (Section 1D) completed.

TASK PERFORMANCE AIDS: Copy of AOP 1203.002, Rev 13 (Section 1D) Reactor Operator #2 followup duties. .

JOB PERFORMANCE MEASURE Page 3 of 6 7"TTIATING CUE:

bd SS/CRS directs you to complete RO #2 followup duties through step 3.9.

CRITICAL ELEMENTS (C): 1, 6 (C) l PERFORMANCE CHECKLIST l STANDARDS l N/A l SAT l UNSAT TPANSITION NOTE: The examinee should transit to the Upper North Piping Penetration Room.

1. Close the RCP Seal Closed RCP Seal Bleedoff Return ISOL Bleedoff Return ISOL (CV-1274) and the (CV-1274) and the (C) Letdown Coolers Outlet Letdown Coolers Outlet (CV-1221). (CV-1221) by engaging the manual handwheel POSITIVE CUE: with the clutch lever CV-1274 and CV-1221 are and turning the closed. handwheel.

2. Verify EW P-7A to SG- Verified E W P-7A to A ISOL (CV-2627) open. SG-A ISOL open (CV-2627) by observing the POSITIVE CUE: valve stem of valve or CV-2627 is open. position indicator.

TRANSITION NOTE: The examinee should proceed to the EW pump room.

3. In the EW room, CV-2800 & 2802 verify P-7B & P-7A verified open by suctions (CV-2800 and observing valve stems CV-2802) open. UP on both valves.

POSITIVE CUE:

Valve stems UP.

TRANSITION NOTE: The examinee should transit to the Lower South Piping Penetration Room. I

4. Verify P-7A to SG B Verified EW P-7A to ISOL (CV-2620) open. SG-A ISOL open (CV-2627) by observing the POSITIVE CUE: valve stem of valve or i I

CV-2627 is open. position indicator.

TRANSITION NOTE: The examinee should transit to the EW Pump Room.

5. Verify P-7A test Verified CV-2870 recire isolation CV- closed by observing 2870 closed. valve stem in down position.

POSITIVE CUE:

Valve stem DOWN.

{

( ..

JOB PERFORMANCE MEASURE Page 4 of 6 PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT

6. Throttle P-7A Closed trip / throttle trip / throttle valve valve (CV-6601A) until (CV-6601A) until gov gov valve full open (C) ' valve is full open and and discharge pressure P-7A discharge decreased slightly.

pressure drops slightly.

POSITIVE CUE:

Governor valve EULL OPEN.

Pump discharge (PI-2811A) pressure - 1400 psig.

7. Notify TSC of Used radio or completion of steps telephone and notified EEW 1.B, l.C, l . D, TSC of completion of 1.G. steps.

POSITIVE CUE: , ,,

TSC notified of completion of steps.

NOTE:

Provide cueing as applicable for the steps which were missed.

NEGATIVE CUE:

(1) SS reports pressurizer level is decreasing.

(6) SS reports OTSG A/B level decreasing.

END

1 i JOB PERFORMANCE MEASURE Page 5 of 6 061 A1.02 3.3/3.6

-Quastion:

How is OTSG pressure controlled during an alternate

. . shutdown?

I 1

Answ3rs Initially the OTSG pressure is controlled by the Main Steam Safety valves. As additional operators become available manual control of the Atmospheric Dump Valves is established.

Reforance Alternate Shutdown AOP (1203.002)Rev 13 PC4 Attachemnt 9 3 page 78. i i

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l PnocAmonK PLAN uo. Pm-m*4 monk Puw Tmz: PAGE: 78 of 84 1203.002 ALTERNATE gg nEV: 13 I CHANGE:

ATTACHMENT 9 I Page 1 of 4 I DISCUSSION CONTINUATION

{

l.0 DESCRIPTION Alternate Shutdown capability is being provided to comply with 10 CFR 50, Appendix R, and to mitigate consequences of significant fire in either the Control Room or the Cable Spread Room because fires in these areas can result {

in loss of controls and instrumentation required for safe shutdown. Following are some of the more significant assumptions considered in development of this procedure:

HOTE This procedure will be used even if a coincident loss of off-site power has not occurred.

A. A coincident loss of off-site electrical power has occurred.

B. No coincident design basis accident occurs, only accidents that are a direct result of.the fire.

j C. Control circuits (for valves, motors, etc.) located in the fire area are assumed to cause activation of the component to the

! least desirable condition unless preventative action is taken.

l 2.0 SYSTEMS 1

The following are the safe shutdown system components utilized by the l

( Alternate Shutdown procedure and a brief description of how they are used. t 2.1 Emergency Feedwater Local control of steam-driven E W Pump (P-7A) is established with the EW Turb K3 Trip /THROT VLV (CV-6601A). EW P-7A to SG-B ISOL (CV-2620) is manually controlled to control SG-B level. These actions I

are accomplished by RO #2.

RO #1 will manually control EW P-7A to SG-A ISOL (CV-2627) to control the SG-A level.

Steam release will be initially controlled by the mechanical steam relief valves and, as additional operators become available, by manual control of the ADVs.

I f The EW CST (T-41B) will provide the initial source of water to the i EFW system with the CST (T-41) and service water, the backup sources, l

if necessary.

l l As time permits, the P-7B train of EW will be made available for

backup purposes, a

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JOB PERFORMANCE MEASURE Page 6 of 6 K&A 061 K5.05 2.7/3.2 Guestion:

If the EFW Pump (P7A) is found tripped, what discharge pressure is maintained after the pump is relatched?

An2wer:

1400# as indicated in local pressure indicator (PI-2811A). 3 R2ference Alternate Shutdown AOP (1203.002) Rev 13 PC 4 Section ID page 25.

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PROCJWORK PUW NO. W"*4WONC PLAN mtE3 PAGE: 25 of 84 1203.002 ALTERNATE SHLTTDOWN REV- 13 CHANGE:.

SECTION 1D Page 2 of 2 REACTOR OPERATOR #2 FOLLOW-UP ACTIONS S

3.6 In LSPPR, verify E W P-7A to SG-B ISOL (CV-2620) open.

3.7 Close or verify closed P-7A Test Recire Isolation (CV-2870).

NOTE E W pump P-7A discharge pressure may be read locally at PI-2811A.

3.8 Slowly throttle EFW TURB K3 Trip / Throttle Valve (CV-6601A) until EW TURB K3 GOV Servo (CV-6601B) is full open and P-7A discharge pressure drops slightly.

3.8.1 If P-7A has tripped, close CV-6601A, relatch trip mechanism and .

slowly open CV-6601A until pump discharge pressure is -1400 psig as read on PI-2811A.

3.9 Notify TSC (by radio or telephone Ext. 6601, 6602, 6603) of the following alignment completions from Attachent 1. For any alignment that could not be completed, refer to Attachment 1 to provide details of specific item number to TSC.

System Attachment 1 Item EW 1.B 1.C 1.D 1.G 3.10 Throttle E W P-7A to SG-B ISOL (CV-2620) as directed by TSC.

3.11 Throttle CV-6601A as necessary to i tintain pump discharge pressure at

-1400 psig as indicated on PI-28113, 3.12 Open EN P-7B to SG-B ISOL (CV-2626).

3.13 In LSPPR, open RB Coolers VCC-2A & 2B PI-3812A ISOL (SW-3812A).

3.13.1 Verify service water header pressura >40 psig on RB SW C',R VCC 2A/B IN PRESS (PI-3812A).

3.14 Close g verify closed P-7B Test Recire Isolation (CV-2869) .

3.15 Notify TSC of the following alignment completions from Attachment 1.

For any alignment that could not be completed, refer to Attachment I to provide details of specific item number to TSC.

System Attachment 1 Item EFW 2.A 2.D SW 7.A

JOB PERFORMANCE MEASURE Page 1 of 7

NIT 1: X REV #: 15 DATE:

..JI NUMBER: ANO-1-JPM-RO-EDG10

- SYSTEM: Abnormal / Emergency Operations

. TASK: EDG-2 No DC Start JTA: 106451104A4 KA VALUE RO: ~4.0 SRO: 4.3 KA

REFERENCE:

064-000-A4.01 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X i

!-TASK LOCATION: INSIDE CR: OUTSIDE CR X BOTH:

L j SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

l

^ PIANT SITE: Simulate SIMULATOR: LAB l

POSITION EVALUATED: RO: SRO:

ACTUAL TESTING ENVIRONMENT: SIMUIATOR: PLANT SITE: LAB l

l TESTING METHOD: SIMULATE: PERFORM:

APPROXIMATE COMPLETION TIME IN MINUTES: 18 l REFERENCE (S): OP 1104.036,'Rev. 37 PC 2 EXAMINEE'S NAME: SSN: - -

. EXAMINEE'S SIGNATURE: DATE:

EVALUATOR'S NAME:

l THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

1 l

l. Start Time Stop Time Total Time l'

! SIGNED DATE:

( SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED

, INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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JOB PERFORMANCE MEASURE 1 ,

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""'E EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

.nz examiner shall review the " Briefing Checklist - System Walkthrough" portion of OP1064.023 Attachment 6 with the examinee.

JPW INITIAL TASK CONDITIONS: Station Blackout is in progress and a fault in tha EDG DC control circuit is preventing EDG auto start.

TASK STANDARD: EDG-2 running, Breaker A408 closed, control room notified diesel is ready for loading.

l TASK PERFORMANCE AIDS: OP 1104.36, Section 11 l

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""'TIATING CUE:

i hv8/CRS directs you to perform a No DC Start of EDG-2 to the point of starting an HPI pump, then call the control room j l

CRITICAL EI.ENENTS (C) : 2, 4, 5, 6, 7,10 ,11 ,12 Start Time PERFORMANCE CHECKLIST: STANDARDS N/A SAT UNSAT

1. Place engine local Rotated engine control control selector switch to MAINT. I switch in MAINT. position.

POSITIVE CUE:

Selected to MAINT.

(C) 2. Place breakers D2114A Opened cabinet for

& D2116A in open to voltage regulator prevent engine S/D (E21)/ local engine when DC power is. . control cabinets (C108 I restored. and opened breaker l POSITIVE CUE: D2116A and D2114A i Breaker (s) in open or off position.

NEGATIVE CUE:

Breaker D2114A not open.

NOTE: Travel to the control room should be avoided to save time on an action of minimal

• -aining value. When this step is reached inform the trainee that the breakers are open.

3. De-energize ES Digital Breakers RS1-4 and Channels by opening RS2-4 are opened.

RS1-4 and RS2-4.

POSITIVE CUE:

Breakers RS1-4 and RS2-4 open.

Troncition Note: The examinee should travel to the A4 switchgear room. l (C) 4. Open designated Opened breakers A409, breakers on A4. A410, A402, A403, A404, A405, A406, and POSITIVE CUE: A407 by pushing manual Breakers open. push-button on each breaker.

NEGATIVE CUE:

Breakers do not indicate open.

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JOB PERFORMANCE MEASURE Page 4 of 7 l PERFORMANCE CHECKLIST: l STANDARDS l N/A l SAT l UNSAT Tronsition Note: The examinee should proceed from the A-4 switchgear room to DG2.

(C) 5. Override Governor Pointed out red knob, run solenoid. locking pin, and  !

described installation l POSITIVE CUE: method (lift knob, Governor run solenoid is depress locking pin, overridden. lower knob while insuring locking pin remains "in").

(C) 6. Open SW cooling Opened SW cooling inlet valve. inlet CV3807 using the manual handwheel.

POSITIVE CUE:

CV-3807 is open (C) 7. Start diesel by Located air start manually opening air solenoid on side of start solenoid valve. diesel and depressed

. override plunger until POSITIVE _ CUE: engine started.

Engine is running NEGATIVE CUE:

Engine turns over but will not start

8. Verify speed at Moved to C108 and approx. 900 rpm /60 Hz. observed tachometer at approx. 900 rpm. Hoved POSITIVE CUE: to voltage regulator j Engine at 900 rpm /60 HZ. panel (Ell) and NEGATIVE CUE: verified 60 HZ.

Engine not at 900 rpm or not at 60 HZ.

9. Verify output voltage At voltage regulator is normal. panel (Ell), checked output voltage 3800- l POSITIVE CUE: 4500 volts. l Voltage is 4160.

NEGATIVE CUE:

Voltage is 0 or outside required range.

l l JOB PERFORMANCE MEASURE 1

Page 5 of 7 l l PERFORMANCE CHECKLIST: l STANDARDS N/A SAT UNSAT l l l l arr.nsition Note: The examinee should proceed from DG2 to the A-4 switchgear room.

I NOTE: Upon completion of next step (Step 10) inform trainee that auto loading of EDG-2 and l r.uto start of EDG-1 did NOT occur.

(C)' 10. Move to A4 and At A4 switchgear, close A408, manually closed A408 by opening cabinet door and POSITIVE CUE: pushing manual close on 1 A308 indicates closed. breaker. I Automatic loading of l

EDG did NOT occur.

NEGATIVE CUE:

A408 did not close, 4 automatic loading of  !

EDG did not occur.

(C) 11. Start SW pump for Moved to breaker cabinet, )

EDG-2. opened door and closed '

. A402 by pushing manual POSITIVE CUE: close push-button.

Breaker closed.

NEGATIVE CUE:

Breaker indicates open.

(C) 12. Call CR and Called CRS on radio or reports EDG-2 phone to inform diesel ready for ready for loading.

loading. 1 i

i Stop Time END i

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JOB PERFORMANCE MEASURE Page 6 of 7

\ 064 K1.04 3.6/3.9 Qusation: With DC control power off what safety devices are functional on the EDG7 l u 4 Answars . The mechanical over speed is the only functional protective

' device.

Reference. Emergency Diesel Generator Operation (1104.036) Rev 37 PC 3  !

page 21.

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PROCJWORK PLAN NO. PROCEDUREMORK PLAN TITLE: PAGE: 21 cf 160 l 1104.036 EMERGENCY DIESEL GENERATOR OPERATION REV- 37 l CHANGE:

CDMUTION With loss of control power, the only functional DG protection is the j mechanical overspeed device.

j 11.8 Start diesel generator by overriding one of the starter solenoid l valves with the override plunger. Release solenoid when engine l starts.

, 11.8.1 If DG does not start after ~5 seconds, repeat step 11.6.

l 11.8.2 If it becomes necessary to shut down the diesel:

A. Pull the EMERGENCY FUEL CUTOFF (FO-66A for DG1, FO-66B for DG2) valve handle, EE B., , Release the governor solenoid by lifting the knurled knob, thus releasing the locking pin, and push the ,

knurled knob down and ensure fuel rack lever returns to the shutdown position (black pointer moves to <1 on governor).

11.9 Verify governor maintains engine speed at ~900 RPM speed and ~60 Hz.

If nec,essary, adjust engine speed by turning speed setting knob on governor.

NO1T j Loss of DC power to field flashing circuit will cause loss of automatic voltage regulator setpoint adjustment (loss of power to motor-operated rheostat). Automatic voltage regulation should.still function.

11.10 Verify diesel generator output voltage is normal.

11.10.1 If voltage falls outside 3800-4500 volts, place Excitation control selector switch (on Ell for DG1, E21 for DG2) in MANUAL and adjust the manual voltage adjust dial as necessary.

CDM3 TION The next step will cause automatic loading of the diesel if 125V DC is l restored through a battery charger. Be prepared to manually adjust the diesel voltage and frequency each time a load is started.

l 11.11 Manually close output breaker for diesel that was started (A-308 for DG1, A-408 for DG2).

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JOB PERFORMANCE MEASURE Page 7 of 7 ns.A 064 K4.05 2.8/3.2 Qusationt If an EDG. fails to start, what is the time length from the ]

time the start signal occurs until the EDG start sequence is i terminated.

An:wsrs 45 seconds.

Refersnce Annunciator Corrective Action (1203.012A) Rev 32 page 15.

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PnocJwonK PLAN NO. AM4 WORK PUW TmK: PAGE: 15 of 184 1203.012A ANNUNCIATOR K01 CORRECTNE ACTION Rev: 32 CHANGE:  !

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l 's j Lccation: C10

, , Davice and Setpoints EDG 1 OVERCRANK l

l Alarm: K01-B2 1.0 OPERATOR ACTIONS

1. Place DG1 lockout switch in LOCKOUT position. ,

2. Refer to Tech Spec section 3.7 for operability requirements.

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3. Initiate action to determine cause of over-crank.

4. Operate fuel oil priming pump and verify " return fuel" sight glass is full. ..

5. When cause of over-crank is corrected, prove DG1 operable using Emergency l Diesel Generator Operation (1104.036), Supplement 1.

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6. Alarm may be cleared by any of the following methods:

• Place DG1 lockout switch in LOCKOUT position e Depress local RESET button l

e Place Local /Maint/ Remote switch in MAINT

• Place DG1 Output (A-308) in PULL-TO-LOCK 2.0 PROBABLE CAUSES

1. DG1 did not reach minimum speed within 45 seconds

2. Loss of fuel oil pump prime

3.0 REFERENCES

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1. Tech Spec 3.7

2. Schematic Diegram Annunciator K01 (E-451)

3. Schematic Diagram Diesel Generator Engine control (E-102)  ;

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JOB PERFORMANCE MEASURE  !

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Page 1 of 7 UNIT 1: X REV #: 3 DATE:

TUOI NUMBER: ANO-1-JPM-RO-AOP08 i

( SYSTEM / DUTY AREA: Emergency and Abnormal Operations.

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l TASK: RO#1 duties for Alt S/D with immediate Control Room evacuation JTA: 13035210401 KA VALUE RO: 4.3 SRO: 4.2 KA

REFERENCE:

A06 AA1.1 APPROVED FOR ADMINISTRATION To: RO: X SRO: X TASK LOCATION: INSIDE CR OUTSIDE CRs X BOTH:

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

i PLANT SITE: SIMUIATE SIMULATOR: LAB:

POSITION EVALUATED: RO: -

SRO:

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:

TESTING METHOD: SIMULATE: PERFORM:

APPROXIMATE COMPLETION TIME IN MINUTES: 20.0 minutes 1

REFERENCE (S): OP 1203.002, Rev. 13 PC-4 EXAMINEE'S NAME: SSN: - -

EVALUATOR'S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

l l

l Start Time Stop Time Total Time j SIGNED DATE:

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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JOB PERFORMANCE MEASURE Page 2 of 7 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

Tha examiner shall review the " Briefing Checklist - System Walkthrough" portion of OP1064.023 Attachment 6 with the examinee.

JPN INITIAL TASK CONDITIONS: There is a Fire in the Cable Spreading Room. An Alternate Shutdown is in progress. At the Alternate Shutdown Cabinet, you have received a copy of CP 1203.002 and Section ic.

TASK STANDARD: ROf1 actions for alternate shutdown completed through step 3.12.

TASK PERFORMANCE AIDS: OP 1203.002 and Section ic. l l

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INITIATING CUE:

l The first 3 steps of OP 1203.002 Section 1C have been coupleted. Perform the actions required of RO #1 through step 3.12.

CRITICAL ELEMENTS (C): 1, 6, B , 10, 11, 12 i

I C PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT C 1. At The MSIV's, open Opened instrument air y the instrument air vent vent valves IA-2691B l valves for each MSIV through E and IA-2692B (IA-2691B through E and through E.

IA-2692B through E).

POSITIVE CUE:

All 8 vent valves are open.

2. Verify CV-2667 open. CV-2667 verified open by visually observing stem POSITIVE CUE: or valve position CV-2667 is open. indicator.

3. Verify CV-2617 open. CV-2617 verified open by visually observing stem POSITIVE CUE: or valve position CV-2617 is open. indicator.

4. Verify CV-2663 open. CV-2663 verified open by visually observing stem 1 i

POSITIVE CUE: or valve position CV-2663 is open. indicator.

5. Verify CV-2613 open. CV-2613 verified open by visually observing stem i POSITIVE CUE: or valve position CV-2613 is open. indicator.

TRANSITION NOTE: The examinee should proceed to th'e Auxiliary Building 354' elevation.

(C) 6. Proceed to Aux Bldg, Used manual lever and 354'. Slowly open CV- handwheel, fully opened 1407 manually CV-1407.

POSITIVE CUE:

Valve open.

7. Check for flow noise Checked for flow noise as CV-1407 is opened. as CV-1407 was opened.

POSITIVE CUE:

No flow noise is heard.

TRANSITION NOTE: The examinee should proceed to the UNPPR.

l (C) 8. Manually open CV-1219 Opened CV-1219, CV-1220, and CV-1220. Close closed CV-1206 with CV-1206 manual lever and handwheel, verified POSITIVE CUE: valve movement CV1219, CV1220 open, CV1206 l closed l

l JOB PERFORMANCE MEASURE Page 4 of 7 PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT

9. Notify TSC of Established corrpletion communication with TSC telephone or radio, POSITIVE CUE: notified of action HPI TSC notified of completion Item 5.A, S.B, E N Item of actions 1.A EXAMINERS NOTE:

When TSC is notified have examinee throttle EW P-7A to SG-A ISOL, CV-2627 to rpproximately 50 % open.

(C) 10. Close CV-2627 to Moved to CV-2627, and approximately 50% used the manual lever open. and hand wheel to close CV-2627 to approximately POSITIVE CUE: to 50% open.

CV-2627 is approximately 50%

open.

INSTRUCTOR NOTE: Inform examinee that E W flow is controlled.

(C) 11. Open valves: . Opened E W P-7B to SG-A E W P-7B to SG-A ISOL ISOL (CV-2 67 0) , "B" HPI (CV-2670) Block Valve (CV-1227),

"B" HPI Block Valve and "A" HPI Block Valve (CV-1227) (CV1228) using manual "A" HPI Block Valve handwheel and clutch (CV1228) lever.

POSITIVE CUE:

CV-2670, CV-1227, CV-1228 are open TRANSITION NOTE: The examinee should proceed to the 354 elevation waste gas room.

(C) 12. Slowly open BWST Opened CV-1408 using Outlet CV-1408. clutch lever and manual handwheel, POSITIVE CUE:

CV-1408 is open.

13. Check for flow noise Checked for flow noise as CV-1408 is opened. as CV1408 was opened.

POSITIVE CUE:

No flow noise is heard.

TRANSITION NOTE: The examinee should proceed to the 335 elevation letdown filter area.

14. Verify service water Opened RB Coolers VCC-2C header pressure >40 & 2D PI-3813A ISOL SW-psig. 3813A and verified pressure >40 psig.

POSITIVE CUE:

Service water pressure is 50 psig.

NEGATIVE CUE:

Service water pressure is O psig.

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JOB PERFORMANCE MEASURE l

Page 5 of 7 l PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT l

15. Establish Called TSC via radio or communications with telephone. Reported l the TSC and report completion of steps  ;

completion of steps. 2.B, 6.A, 6.B, 7.B.

POSITIVE CUE:

All steps have been reported to TSC.

NOTE:

l Provide the cue for steps missed.

NEGATIVE CUE:

l Step 1 RCS is ove'rcooling

! due to high steam flow.

Step 9. A OTSG level,is going up rapidly, i Step 7, 10b or c, 11.

I Unable to establish HPI flow.

END 1

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JOB PERFORMANCE-MEASURE Page 6 of 7 KsA' 068 AK3.09 3.9/4.4 Question: How is RCS inventory controlled during Alternate Shutdown?

Answer: Intially, the "A" Train of HPI is manually aligned with the BWST suction valve open and two HPI valves full open. HPI capability will be controlled by the CRS locally starting / stopping the "B" HPI pump.

R2ference Alternate Shutdown AOP (1203.002) Rev 13 PC 4 Attachment 9 page 79.

neocasonK PLAN NO. Pear-m84400MC PUW TmE: PAGE: 79 of 84 1203.002 ALTERNATE SHUTDOWN REV: 13 CHANGE:

ATTACHMENT 9 Page 2 of 4 2.2 Electrical Power Both diesel generators will be started, tied to their respective buses, and then overridden to prevent spurious shutdown. All A3 and A4 breakers will have their breaker control power removed to prevent spurious actuations (A3 and A4 energized with one service water pump on each bus, all other loads secured). The vital 480 volt buses (B5 and B6) will be de-energized to prevent spurious actuations. The vital 480 volt load centers will later be re-energized after certain breakers have been opened to prevent undesirable spurious actuations.

These buses are required to support extended diesel generator operations, HPI, and to power the battery chargers.

2.3 Service Water one service water pump per bus (A3, A4) is verified operating, then breaker control power is de-energized to prevent spurious shutdown.

The valves and sluice gates required to pressurize both loops are de-energized in their pre-fire alignment to prevent spurious misalignment. Service water pressure is verified locally to assure adequate component cooling. Service water is required to support sustained diesel generator, HPI pump, and possibly EFW system operations.

2.4 High Pressure Injection Initially, the "A" train (red powered) of HPI will be manually aligned with the BWST suction valve open and two HPI valves full open. HPI capability will be controlled by the CRS locally starting / stopping P-64A(B) and closing / opening the "A" (or "B" if its MOD to A3 is closed)

HPI pump breaker.

As time permits, the redundant train of HPI will be aligned and verified for backup purposes. If necessary, the remaining HPI valves may be opened. ,

Instrumentation Instrument strings totally independent of the Control Room and Cable Spread Room have been provided via the SPDS Alternate Shutdown display (A/S-G). The power source and cable routing of these instrument strings will assure their reliability for Control Room / Cable Spread Room fires. All other instrumentation should be considered unreliable.

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JOB PERFORMANCE MEASURE Page 7 of 7 K&A' 068 AK3.12 41.'/4.5 I

Question: State the Inunediate Action or Actions for Alternate

.

• Shutdown, Inrnediate Control Room Evacuation Section.

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Answers Manually trip the reactor and verify reactor shutdown.

R2ference Alternate Shutdown AOP Rev 13 PC 4 Section 1 page 3.

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PROCJWORK PLAN NO. PROCEDUREMPORK PULN TTTLE: PAGE: 3 of 84 1203.002 ALTERNATE SHUTDOWN REV: 13 CHANGE: g ,, j I

l SECTION 1 l

Page 1 of 2 IMMEDIATE CONTROL ROOM EVACUATION DISCUSSION Section 1 covers immediate control Room evacuation as a result of a fire in the Control Room (zone 129F) or Cable Spread Room (zone 97R). This section t

can be performed by four operators as a ndnimum. The Shift Superintendent l goes to the third floor TSC. The CRS and two RO's go into the plant. The auxiliary operator and waste control operator are left available for fire i brigade. Refer to Attachment 9 of this procedure for further discussion. j 1.0 SYMPTOMS 1.1 Fire in Control Room renders Control Room uninhabitable.

1.2 Fire in Control Room threatens immediate damage to major portions of l vital controls.

1.3 Fire in Cable Spread Room threatens immediate damage to significant I number of cables. 1 2.0 IMMEDIATE ACTION 2.1 Manually trip reactor and verify reactor is shutdown. I l

NOTE Control Room actions not completed due to need for Control Room evacuation i are accomplished by backup methods outside the Control Room.  !

3.0 FOLLOW-UP ACTIONS -- Control Room  ;

5 3.1 Manually trip Turbine and verify Turbine throttle and governor valves

< closed, hl 3.2 Actuate EFW for both SGs.

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%l 3.3 Close MSIVs and Main Feedwater Isolations for both SGs.

SG-A SG-B CV-2691 CV-2692 CV-2680 CV-2630

• .l g 3.4 Open SERV WTR to DG Coolers l

DG1 DG2 CV-3806 CV-3807 i l 3.5 Close Letdown Coolers outlet (CV-1221).

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( JOB PERFORMANCE MEASURE l

1 UNIT: 1 REV # 1 DATE:

. . {

TUOI NUMBER: ANO-1-JPM-RO-CF002 SYSTEM / DUTY AREA: CORE FLOOD SYSTEM  !

TASK CALCULATE FEED AND CONCENTRATION FOR MAKEUP TO CFT I i JTA# 10065110101 l

! KA VALUE RO: 3.5 SRO: 3.7 KA

REFERENCE:

006 020 A1.07 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH: I l

l SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

l PLANT SITE: SIMULATOR: PERFORM LAB:

POSITION EVALUATED: RO: SRO:

, ACTUAL TESTING ENVIRONM'.sT: SIMULATOR: PLANT SITE: LAB:

l TESTING METHOD: SIMULATE: PERFORM: 1 APPROXIMATE COMPLETION TIME IN MINUTES: 10 MINUTES i REFERENCE (S): 1104.001 REV. 29, PC-3, ATTACHMENT "E" l EXAMINEE'S NAME: SSN - -

I EVALUATOR *S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

I SATISFACTORY: UNSATISFACTORY:

j. PERFORMANCE CHECKLIST COMMENTS:

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Start Time Stop Time Total Time SIGNED DATE:

i SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A N QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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Page 2 of 6 TUOI NUMBER: ANO-1-JPM-RO-CF002 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

The examiner shall review the " Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.

l JPM INITIAL TASK CONDITIONS: The plant is operating at 100% power and has been at this power for 225 days. Because of various samples, etc. the "A" CFT tank level is 12.7 ft. and concentration is 2280 ppm. In order to maintain the tank operable, an addition must made to adiust the concentration and increase the level.

l TASK STANDARD: ATTACHMENT E completed and determined that 98-100 gallons of acid 62-66 gallons of water are required for the addition.

TASK PERFORMANCE AIDS: 1104.001, ATTACHMENT E, information concerning current CFT status., calculator, pencil or pen.

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Page 3 of 6 TUOI NUMBER: _ ANO-1-JPM-RO-CF002 INITIATING CLT; The CRS/SS directs you to calculate the feed volume and concentration for an addition to "A" CFT to raise the concentration from 2280 ppm to 2350 ppm and the level to 13.0 Ft. (BORON CONCENTRATION OF BORIC ACID SOURCE IS 10,000 ppmB)

CRITICAL ELEMENTS (C): 2, 3, 4, 5, 7, 8 C PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT

1. Obtain ATTACHMENT E of ATTACHMENT E of 1104.001 1104.001 is obtained from the form drawer.

C 2. Step 1.0 is filled in with Lt is recorded as the correct level 12.7 Ft. and Lt is information as given. recorded as 13.0 Ft.

C 3. Step 2.0 is completed to Feed volume (F) is determine the feed volume determined to be (F) required for the 153.6 gallons.

addition. (152-156 gal is acceptable)

C 4. Step 4.0 is completed to vi is calculated to determine initial (Vi) and be 7625.4 gal final (Vf) CFT volumes. (7620-7630 acceptable). and Vf is calculated to be 7779 gal.

(7775-7785 is acceptable)

C 5. Determine Cr, required Cti recorded as boron concentration of feed 2280 ppmB and Cte volume (F), by completing recorded as 2350 step 5.0. ppmB.

Cr is determined to be 5825.1 ppmB.

(5815-5830 gal. is acceptable range)

6. Record (F), Cr, and C3 as (F) recorded as previously calculated or 153.6 (152-156) given. gal., Ce recorded as 5825.1 (5815-5830), and Ce recorded as 10,000.

Page 4 of 6

'TUOI NUMBER: ANO-1-JPM-RO-CF002 C PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT

. C 7. Determine the boric acid (B) calculated to volume (B) required by be 89.47 (88-92 completing step 7.0. acceptable).

(B*) is calculated to be 98.42 (98-100 acceptable).

C 8. Determine the DI water (D) is calculated volume (D) required for to be 64.1 the addition by gal.(62-66 completing step 8.0. acceptable).

9. Sign, date, and record Completed the form time of completion of the by signing the _

calculation. form, dating and recording the time of completion.

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Page 5 of 6 l-

,. K&A 006 K5.02 2.8/2.9 l

1 Question:

What is the basis for the pressure and level in the Core

.- Flood Tanks?

Answer: The 600 psig of nitrogen serves as flooding head to inject the tank contents into the RCS during LOCA. The combined volume of both tanks is sufficent to cover the core -3/4 to l terminate fuel clad temperature transients from intermediate and large RCS pipe failures. (LOCA)

Reference Core Flood Operating Procedure (1104.001) Rev 29 PC 3 page 2.

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Pnocm0RK PLAN NO. Mt0CEDUREMORK PLAN Tm.E: PAGE: 2 of 77 1104.001 CORE FLOOD SYSTEM OPERATING PROCEDURE REV: 29 CHANGE:

1.0 PURPOSE To provide instructions for operating and testing the core flood system during startup, normal operation, and plant shutdown.

'2.0 SCOPE This procedure includes instructions for the following:

2.1 Initial filling, draining, pressurizing, depressurizing and venting the two Core Flood Tanks (T-2A and T-2B).

2.2 Establishing and maintaining tank levels and pressure limits per Tech Spec 3.3.3.A. l 2.3 Establishing and maintaining proper tank boric acid concentration limits per Tech Spec 3.3.3.B.

2.4 Demonstrating core flood check valve operability, using a test supplement,.,per Tech Spec 4.5.1.1.3. I

3.0 DESCRIPTION

The core flooding system is a self-contained, self-actuated and passive subsystem of the emergency core cooling system. Borated water is stored in the two core flood tanks (CFT's) at a concentration greater than 2270 ppmB and less than 3500 ppmB. The system automatically floods the core when RCS  !

l pressure decays to about 600 psig. A nitrogen gas space, ~1/3 of tank volume, is maintained between 585 and 615 psig in the CFT's to provrl:- adequate flooding head.

A 2700 ppmB solution is used to ensure adequate margin to the Tech Spec' limit (2270 ppmB) is naintained. It also offsets. dilution if makeup from the MU and purification system at RCS concentration is used to replace CFT sampling losses. MU and purification system makeup from T-4 is used only as a last resort in the event normal makeup is not available and entering a Tech Spec l action statement on low CFT level is imminent.

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t Fast action of the CFT's terminates fuel clad temperature transients during intermediate and large RCS pipe failures, thus maintaining core geometry.

The combined volume of the two CFT's is sufficient to cover the core to the j . 3/4 point, assuming no water remains in the reactor vessel following a LOCA.

Both CFT's are required to be operable to perform this function.

The MOV's at the CFT outlets are opened during plant heatup and pressurization i

at about 730 psig. Redundant alarms based on MOV position and RCS pressure l are provided at C16 and C18.

The CFT outlet MOV's are closed during plant cooldown at about 700 psig to prevent dumping the tanks and violating RCS NDTT requirements (Tech Spec  ;

3.1.2.9).

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K&A 006 A1.13 3.5/3.7 l I

Question: How often are the Core Flood Tanks required to be sampled?

Answer: Monthly and following any makeup.

Reference Core Flood Operating Procedure (1104.001) Rev 29 PC 3 page 5.

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PROCJWORK PUW No. PROCEDURE / WORK PLAN TTRE: PAGE: 5 of 77 1104.001 CORE FLOOD SYSTEM OPERATING PROCEDURE REV: 29 CHANGE:

5.4 When containment integrity is established and prior to reaching RCS pressure of 800 psig, each Cn shall be at least as follows (Tech Spec 3.3.3):

5.4.1 CFT level

• Admin limit - 12.7 to 13.3 feet

• Tech Spec limit - 12.6 to 13.4 feet 5.4.2 CFT Pressure e Admin Limit - 585 to 615 PSI e Tech Spec Limit - 575 to 625 PSI 5.4.3 C n boron concentration >2270 ppmB (T.S. limit).

5.4.4 The MOV discharge valves from both CFT's (CV-2415 and CV-2419) open and breakers locked open and tagged (T.S.

limit).

5.4.5 One of two pressure instrument channels and one of two level instrument channels per CFT operable (T.S. limit).

5.5 Boron concentration in CFT's should not exceed 3500 ppmB.

5.6 CFT's shall be sampled for proper boron concentration monthly and after each makeup (Tech Spec Table 4.1-3) .

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g CFT's shall be sampled for fluoride, chloride and sulfate after each makeup. (Engineering Report 93-R-1016-01) 5.7 C n's level and pressure channel checks shall be performed per CBO Turbine Logsheet (OPS-A6).

5.8 Do not run CFT MU and Recire Pump (P-132) without adequate cooling

. water flow.

5.9 When operating the chemical addition system, observe limits and precautions of Chemical Addition (1104.003).

5.10 When opening CPT Isolation Valves as RCS pressure is increased during Startup, monitoring of C N levtl and pressure is necessary to detect check valve leakage.

5.11 When draining CFT Makeup Tank (T-110), coordinate with Health Physics to address radiological concerns.

5.12 Batch Controller Outlet (CV-1250) must remain closed during fill of T-110 from Batch Controller to prevent flow from Makeup and Purification System to T-110.

5.13 opening Core Flood addition and sample valves WU-35A, MU-35B, Nz-3, N -5 or CF-2 circumvents the double-valve isolation penetration design. When RCS is <200*F, Containment Closure control, Attachment G of Decay Heat Removal and LTOP System Control (1015.002) applies.

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l JOB PERFORMANCE MEASURE Page 1 of 6 i i

UNIT 1: X REV #: 0 DATE:

-TUOI NUMBER: ANO-1-JPM-RO-AOP26 SYSTEM: Emergency and Abnormal Operatons l

TASK: Respond to' loss of loadcenter B6 JTA 106263904A4 KA VALUE RO: 3.4 SRO: 3.9 KA

REFERENCE:

062 A2.01 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CRs BOTH:

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE: SIMULATOR: PERFORM LAB:

POSITION EVALUATED: RO: '

SRO:

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:

TESTING METHOD: SIMULATE: PERFORM:

APPROXIMATE COMPLETION TIME IN MINUTES: 15 minutes REFERENCE (S): AOP 1203.046, Rev. 1 PC3 EXAMINEE'S NAME: SSN: - -

EVALUATOR'S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE: ,

SATISFACTORY: UNSATISFACTORY:

I PERFORMANCE CHECKLIST COMMENTS: i I

Start Time Stop Time Total Time SIGNED DATE:

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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JOB PERFORMANCE MEASURE Page 2 of 6 1

. HE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

.as examiner shall review the " Briefing Checklist - System Walkthrough" portion of '

OP1064.023 Attachment 6 with the examinee. i l JPN' INITIAL TASK CONDITIONS: A breaker fault has resulted in the loss of loadeenter B6.  ;

1 Unit is at 100% power. P-36B is the operating makeup pump. l TASK STANDARD:'AOP 1203.046, steps 3.6.1 through 3.6.~1 completed.

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TASK PERFORMANCE AIDS: Copy of AOP 1203.046, Rev 1, section 3.6 I i

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JOB PERFORMANCE MEASURE Page 3 of 6  ;

7"1tTIATING CUE:

L.3 SS directs you respond to loss of loadcenter B6 in the control room. l l

CRITICAL ELEMENTS (C): 2, 3, 4, 5, 6 i (C) PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT

1. Verify MCC B55 and B56 On panel C09, are selected to the energized bus.

POSITIVE CUE:

NEGATIVE CUE:

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2. Isolate Letdown. On panel C09, closed valves CV-1214 and CV-(C) POSITIVE CUE: , . , 1216.

CV-1214 and CV-1216 indicate GREEN. i I

NEGATIVE CUE:

CV-1214 and CV-1216 indicate RED. l

3. Stop the Makeup pump. At C16, stopped P-36B.

l POSITIVE CUE:

sc) P-36B indicates GREEN.

4. Close RCP Seal At C09, placed Injection Block valve. handswitch for CV-1206 j to Close.

(C) POSITIVE CUE:

CV-1206 indicates GREEN.

l NEGATIVE CUE:

CV-1206 indicates RED.

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JOB PERFORMANCE MEASURE Page 4 of 6

) PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT

5. Open T-G L.O. Coolers On panel C09, took CV-Temp cont valve. 4026 handswitch in i (C)

MANUAL and opened.

POSITIVE CUE:

CV-4026 indicates RED.

6. Open T-G H2 Temp Cont On panel CO2, took CV-valve. 4018 handswitch in (C) MANUAL and opened. I POSITIVE CUE:

CV-4018 indicates RED.

7. Verify DG2 starts. On panel CO2, checked DG2 running (rpml?.

POSITIVE CUE:

DG2 running, i l

8. Verify A2 feed to A4 On panel C04, checked {

is tripped. A-409 indirates GREEN.

POSITIVE CUE:

A-409 indicates GREEN.

9. Verify DG2 output On panel C04, checked i breaker closes. A-409 indicates RED l POSITIVE CUE:

A-408 indicates RED.

10. Verify SW pump on A4 On panel C04, checked 1 restarts. P-4B(C) indicates RED j POSITIVE CUE:

P-4B(C) on A4 indicates RED.

11. Verify feeder breaker on panel C04, checked to B6 closed. A-401 indicates RED.

POSITIVE CUE:

A-401 indicates RED.

11. Verify feeder breaker On panel C04, checked to B6 closed. B-612 indicates RED.

POSITIVE CUE:

B-612 indicates RED.

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END i

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JOB PERFORMANCE MEASURE Page 5 of 6 KAA' 004 K3.02 3.7/4.1 -

Question: . Why is letdown isolated in this event?

Answer: Loss of YO2 causes the Letdown Demin Inlet valves to fail closed. This will cause the Letdown Relief valve to lift and

' fill up the ABEDT (T-11).

1 Reference 1203.046 Rev. 1 PC 3 page 11 I

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PROCJWORK Pt.AN NO. PROCEDURE / WORK PUW Tm.E: PAGE: 11 Of 14 REV: 1 1203.046 LOSS OF LOADCENTER CHANGE:

3.6 Loss of Loadcenter B6 3.6.1 Verify MCC B55 and B56 are selected to the energized bus.

NOTE Loss of YO2 causes Makeup Filter Inlet and Purification Demineralizer Inlet

• valves to fail closed resulting in lifting Letdown Relief valve discharging to Aux Bldg Equipment Drain Tank (T-11).

3.6.2 Isolate Letdown by closing Letdown Cooler Outlets (CV-1214 and CV-1216).

NOTE

1. If the operating Makeup Pump is on bus A4, the Aux Lube 011' pump will not start due to loss of power. In this case the Makeup Pump should be tripped without starting the Aux Lube 011 pump.

2. With loss of YO2, RCP Seal Injection Block (CV-1206) will not autoclose on low flow.

3.6.3 Stop the Makeup Pump if running.

3.6.4 Close RCP Seal Injection Block (CV-1206) .

NOTE Loss of YO2 causes T-G L.O. Coolers E-15A&B Temp Cont Viv CV-4026 and T-G H Temp control Valve CV-4018 to close if in AUTO due to loss of temperature input.

3.6.5 Place T-G L.O. Coolers E-15A&B Temp cont Viv CV-4026 in MANUAL and open.

3.6.6 Place T-G H2 Temp control Valve CV-4018 in MANUAL and open.

3.6.7 Verify the following:

- A. DG2 starts.

B. A2 Feed to A4 (A-409) is tripped.

C. DG2 Output (A-408) closes to re-energize bus A4.

D. Operating Service Water Pump on bus A4 restarts.

E. A4 Feed to B6 (A-401) is closed.

F. A4 Feed to B6 (B-612) is closed.

3.6.8 H A-401 or B-612 cannot be closed, and it is determined the fault is not on bus B6, consider powering bus B6 from B5 per " Bus B5 to B6 Crosstie to Energize Dead Bus" section of ES Electrical System Operation (1107.002).

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JOB PERFORMANCE MEASURE Page 6 of 6 I

i AccA 004 K4.03 2.8/2.9  !

t Question: What is the maximum demineralizer inlet temperature allowed?

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Answer: 13$'F - ,

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Reference Makeup and Purification System Operation (1104.002) Rev 50 PC 3 page 10 i

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PROCJWORK PLAN NO. PROCEDUREMORK PUW TITLE: PAGE: 10 ef 230 1104.002 MAKEUP & PURIFICATION SYSTEM OPERATION REV: 50 CHANGE:

5.6 Maximum flow through a Letdown Cooler (E-29A & B) is 87.5 gpm per cooler.

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5.7 Allowing flow through a. primary Makeup Filter (F-3A or F-3B) in excess of 80 gpm can lead to filter damage.

5.8 Allowing flow through a purification DI in excess of 123 gpm can compact the resin and restrict letdown flow.

l 5.9 Restricting flow through a Purification Demineralizer (T-36A or T-36B) to <25 gpm can cause channeling of resin and reduce efficiency of demineralizer.

5.10 Maximum purification demineralizer inlet temperature is 135'F.

5.11 Placing a purification demineralizer in service that has not been l borated will result in a reduction in RCS boron concentration.

5.12 Ensure clean,wpste system is aligned to receive waste from letdown system prior to positioning Letdown 3-Way Valve ( CV.-124 8 ) to BLEED.

Otherwise letdown line will over-pressurize.

5.13 When makeup pumps are subject to HPI actuation, maintain MU tank pressure / level relationship within limit'of Exhibit A. Exceeding the limit reduces the time available for isolating the MU tank after FPI actuation.

5.14 When venting the makeup tank, the waste gas system shall be aligned to compress the gas for storage unless samples indicate negligible activity in the makeup tank.

5.15 MU Tank T-4 Relief Valve (PSV-1249) is not designed to relieve water. l l For uncontrollable high MU tank water level, open MUT Vent Valve i (CV-1257).

5.16 Some operation and valve lineups will require exposure to possibly high radiation levels. These should be conducted rapidly and j accurately to minindze exposure. l 5.17 Neither Makeup /HPI Pump P-36B MOD to Bus A3 nor MOD to Bus A4 should be operated under load. Verify both breakers (A-307 and A-407) for P-36B open before operating MOD'S.

5.18 The following limits and precautions apply to the high pressure auxiliary spray system.

5.18.1 The use of high pressure auxiliary spray can cause severe thermal stresses in piping and components. Use high pressure auxiliary spray only when directed by Emergency Operating Procedure or Natural Circulation Cooldown (1203.013).

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Page 1 of G JOB PERFORMANCE MEASURE UNIT:~ 1 REV # 4 DATE:

TUOI NUMBER: ANO-1-JPM-RO-ED001 SYSTEM / DUTY AREA: ELECTRICAL DISTRIBUTION TASK: ENERGIZE BUS A2 FROM DG2 DURING A DEGRADED POWER SITUATION JTA#: 10626070601 KA VALUE RO: 3.7 SRO: 4.1 KA

REFERENCE:

062 000 A2.11 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CRs X OUTSIDE CR BOTH:

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE: SIMULATOR: PERFORM LAB:

POSITION EVALUATED: RO: SRO:

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:

?ING METHOD: SIMULATE: PERFORM:

APPROXIMATE COMPLETION TIME IN MINUTES: 6 MINUTES REFERENCE (S): DEGRADED POWER EOP 1202.007, REV. 4, PC ' 5 EXAMINEE'S NAME: SSN - -

EVALUATOR'S NAME:

l THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

L SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

Start Time Stop Time Total Time i

IED DATE:

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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NUMBER: ANO-1-JPM-RO-ED001

, THE EXAMINER SHALL REVIEW WITH THE EXAMINEE: ,

1 Tha~ eittminer shall review the " Briefing Checklist - System Walkthrough" portion of  !

OP 1064.023 Attachment 6 with the examinee.

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JPM INITIAL TASK CONDITIONS: Offsite power NOT available, both EDG's are rupplying their respective vital buses. EDG's are NOT overloaded.

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TASK STANDARD: #2 EDG supplying A2 through A-409 without overloading the 1

disntl.

TASK PERFORMANCE AIDS: EOP 1202.007, Degraded Power.

SIMUIATOR SETUP:

. .11 IC2 then insert malfunction for Loss of Offsite Power (ED183).

Actusto MSLI for both OTSGs.

Close CV-1221.

Isolcto RCP Seal Bleedoff (normal and to QT). ,

Plac2 A1,A2,H1,H2 feeder breakers in P-T-L.  !

Plces condensate pumps and ICW pumps (P33's) in P-T-L. j Placa HPI pump in service with seal injection in service. i i

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Page 3 of 6 NUMBER: ANO-1-JPM-RO-ED001 INITIATING CUE:

Tha CRS directs you to make all preparations and energize A2 from DG2 per OP1202.007, step

97. Attechment 1 of OP1202.007 has been completed and off-site power is un-available.

CRITICAL' ELEMENTS (C): 6, 7 C PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT

1. Check A2 LO Relay Checked that A2 L.O.

Trip alarm clear Relay Trip alarm is (K02-A7). clear (K02-A7).

POSITIVE CUE:

Alarm is clear.

2. On C10, open B-112... B-112 opened.

POSITIVE CUE:

Green light on.

NEGATIVE CUE:

Red light on.

3. On C10, turn sync switch On panel C-10, turned for breaker B-142 on. sync switch for B-142 to ON position.

POSITIVE CUE:

Sync switch for B-142 is on.

4. On panel C-10, close Closed B-142 breaker B-142.

POSITIVE CUE:

Red light on.

NEGATIVE CUE:

Green light on.

NOTENInformlexaMineeNhatAttachment1,'*DegradedPowerBreakerAlignmentandUVRelay Def yt"(hasjbeenicompleted. ;

5. Place Bank 4 On panel C04, Pressurizer heaters pressurizer heater in off. group 4 handswitch is placed in off.

POSITIVE CUE:

Bank 4 heaters control switch in off.

(C) 6. Turn sync switch for On panel C-10 sync A-409 on. switch for A-409 placed in on.

POSITIVE CUE:

Sync switch for A409 is on.

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NUMBER: ANO-1-JPM-RO-ED001 C PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT  ;

(C)' 7. Close A-409. On panel C-10, A-409  ;

HS taken to close.

POSITIVE CUE:

Red light on.

NEGATIVE CUE: '

Green light on.

8. Check KW meter on C10 EDG2 loading checked to verify load less to be 5; 2750 KW.

than 2750 KW.

9. On Panel C-10, turn A- A-409 sync switch 409 sync switch off. turned to off.

POSITIVE CUE:

Sync switch for A-409 in l off. ,

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l l lK&A 062 A2.01 3.4/3.9 lQuantion: ^

The unit is in a Degraded Power condition. Both EDG's are operating.

i The #1 EDG Fuel 011 Transfer Pump (P-16A) develops a motor fault and l

trips. What design feature allows for continued operation of both EDG's?

l Anrwart The EDG fuel oil transfer system can be operated to supply both EDG Day Tanks using #2 EDG Puel Oil Transfer Pump (P-16B) from either fuel oil storage tank by cross connecting both storage tank outlets to the suction of the operating transfer pump.

Reforance Emergency Diesel Generator Operation (1104.036) Rev 37 PC 2 page 33 & 34.

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1 PaoC. work PLAN NO. PROCEDUREMORK Pt.AN TirLE. PAGE: 33 of 160 l

1104.036 EMERGENCY DIESEL GENERATOR OPEiMTION Rp: 37 CHANGE:

13.3.5 Fill DG1 Fuel Oil Day Tank T-30A as follows:

A. Open DG1/DG2 Emerg Diesel Fuel Tank Crossovers (FO-10A l and FO-10B). j i

Open DG1/DG2 Fuel Transfer Pumps P-16A/P-16B B. l Crossovers (FO-11A and FO-11B).

C. Station operators at T-30A and Control Panel C108 and establish communications. I

,g l H.3.11 CAUTION l Manual operation of Fuel Transfer Pune can cause day tank overflow. l I

D. Start and stop P-16B, in manual, as necessary to fill T-30A.

E.

• g DG2 is operating, and it is necessary to refill T-303, open FO-77B and start P-16B to refill T-30B.

Closely monitor T-30A and T-30B levels. DO NOT l overfill T-30A or T-30B.

CAUTION With both Diesels operating and being supplied with fuel by one transfer pump, operators must manually direct fuel oil flow to both T-30A and T-30B. l Control is established by opening and closing T-30A/B Fuel Oil Day Tank Inlets (FO-77A and FO-77B) or manually starting and stopping the available fuel transfer pump.

13.4 y both diesels are available and'it is necessary to supply fuel oil to DG1 and DG2 using P-16A, perform the following:

13.4.1 Verify DG1 Fuel Oil Day Tank (T-30A) level 2200 gal.

13.4.2 Place F-16A handswitch on C107 in OFF.

13.4.3 Unlock and close DG1 Fuel Oil Day Tank T-30A Inlet (FO-77A).

13.4.4 Make appropriate entries on Category "E" Valve Log (Form-1015.035A) and Safety System Status Board.

MtOC./ WORK PLAN NO. PftOCEDURE) WORK PLAN TTTLE: PAGE: 34 of 160  ;

I 1104.036 EMERIENCY DIESEL CENERATOR OPERATION REV: 37 CHANGE:

PC-t 13.4.5 Fill DG2 Fuel Oil Day Tank T-30B as follows:

A. Open DG1/DG2 Emerg Diesel Fuel Tank Crossovers (FO-10A and FO-10B).

B. Open DG1/DG2 Fuel Transfer Pumps P-16A/P-16B Crossovers (FO-11A and FO-11B).

C. Station operators and establish communications at T-30B and Control Panel C107.

g g l (4.3.71 CAUTION Manual operation of Fuel Transfer Pump can cause day tank overflow.

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D. Start and stop P-16A in manual, as necessary, to fill l T-30B.

.E . . If f DG1 is operating and it is necessary to refill T-30A, open FO-77A and start P-16A to refill T-30A. I closely monitor T-30A and T-30B levels. DO NOT l overfill T-30A or T-30B.

13.5 WHEN fuel oil cross-connect is no longer needed, restore normal system lineup as follows:

13.5.1 Open and lock FO-77A and FO-77B.

13.5.2 Perform required independent verification of Category "E" Valves. Make appropriate entries on Category "E" Valve Log (Form 1015.035A). l l

13.5.3 Close DG1/DG2 Fuel Transfer Pumps P-16A/P-16B Crossovers l (FO-11A and FO-11B).

13.5.4 Close DG1/DG2 Emerg Diesel Fuel Tank Crossovers (FO-10A and FO-10B).

13.5.5 Place DG Fuel Transfer Pump handswitches in AUTO (P-16A l handswitch on C107, P-16B handswitch on C108). l t

Page 6 of 6 I l

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l K&A 062 Kl.04 3.7/4.2 j Question: When both EDG's are operating why is it not allowed to tie both to the l grid simutaneoulsy?

Answer: By maintaining one EDG dedicated to its ES bus a single grid disturbance can not result in the loss of both EDG's.

Raference Emergency Diesel Generator Operation (1104.036) Rev 37 PC 2 page 6 l

1 C.

MtOCMORK PLAN NO. PROCEDUMUWORK PLAN Tm.E: PAGE: 6 cf 160 t

1104.036 EMERGENCY DIESEL GENERATOR OPERATION REY: 37

! CHANGE.

5.2 Any visible tubing vibrations during D,G surveillances, or, water, air, or oil leaks are to be promptly reported. Elevated leaks may allow oil system to draw in air when shut down, draining pipes.

l (4.3.11' 5.3 Diesel run time unloaded or at low load (<75%) should be minimized in order to prevent carbon fouling (isproper combustion) and excessive turbocharger gear train wear.

5.4 During periods of known off-site electrical grid disturbances, neither diesel should be paralleled with the grid. This will prevent a loss of the diesel generator from protective relay actuation such as ,

overload or reverse power.

5.5 When both diesel generators are in operation, do not tie them to the grid simultaneously. One DG shall be dedicated only to its ES bus.

Otherwise a single grid electrical fault may cause a loss of both emergency diesel generators.

5.6 Governor booster pump tubing should be inspected for leaks during

. diesel run to prevent loss of governor-control oil pressure.

5.7 The Shift Superintendent shall be notified of any oil spill that has the potential of reaching Lake Dardanelle.

5.8 Do not attempt diesel generator restarts until engine has stopped (O RPM).

5.9 Either the AC or DC soak back pump (P-106A3 or_ P-106Al for DG1, P-106B3 o_r P-106B1 for DG2) must be operational before operating the diesel and must continue to operate a minimum of 30 minutes after the diesel is shutdown to cool the turbocharger bearings.

5.10 In parallel operation, maximum allowed reactive load is 400 KVAR out )

and 100 KVAR in.

5.11 -Maximum current: 450 amps. Do not exceed except in emergency.

Maximum ambient temp for diesel operation is 122*F.

5.12 Verify ventilation fans operate to maintain ambient temp < maximum allowed.

5.13 Maximum engine outlet water temperature is 205'F. l 5.14 Minimum oil pressure is 35 psig when diesel is operating at 900 RPM.

5.15 Except for automatic starts and tests when opposite train components are inoperable, do not operate the diesel until all cylinders are cleared of water.

5.16 Do not operate the diesel unless service water is available for cooling.

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Paga 1 of *,'

l JOB PERFORMANCE MEASURE UNIT: 1 REV # 5 DATE:

.TUOI NUMBER: ANO-1-JPM-RO-DHR03 l

SYSTEM / DUTY AREA: DECAY HEAT REMOVAL TASK _ ESTABLISH DECAY HEAT REMOVAL USING P-34A JTA#: 106:15210101 i KA VALUE RO: 3.3 SRO: 3.4 KA

REFERENCE:

005 000 0013

~ APPROVED FOR ADMINISTRATION TO: RO: X SRO: X j TASK LOCATION: INSIDE CR X OUTSIDE CR BOTH: j SUGGESTED TESTING ENVIRONMENT.AND METHOD (PERFORM OR SIMULATE):

]

l PLANT SITE: SIMULATOR: PERFORM LAB l l

i POSITION EVALUATED: RO: SRO:

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:  ;

TESTING METHOD: SIMULATE: PERFORM:

. PROXIMATE COMPLETION TIME IN MINUTES:

15 MINUTES REFERENCE (s): 1104.004 REV. 63 PC 1, 1102.010 REV. 49 i

EXAMINEE'S NAME: SSN - -

I EVALUATOR'S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:  !

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i Start Time Stop Time Total Time i SIGNED DATE:

GNATURE--INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A I dALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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I Page 2 of 7 TUOI NUMBER: ANO-1-JPM-RO-DHR03 ofE EXAMINER SHALL REVIEW THE FOLLOWING WITH TIE EXAMINEE:

The examiner shall review the " Briefing Checklist - System Walkthrough" portion of OP l IC64.023 Attachment 6 with the examinee.

JPM INITIAL TASK CONDITIONS: Plant shutdown and cooldown per OP 1102.010 is 1

crmplete to step 14.5. Decay heat removal with P34A is to be established per l

l OP 1104.004. Breakers B-5255/B-6255 are closed.

TASK STANDARD: P-34A decay heat pump started and then secured due to SW cooling supply vn1ve CV-3840 failure to open. This is an Alternate success Path JPM.

TASK PERFolGOLNCE AIDS: OP 1104.004, Rev. 59 KDMIATOR SETDP:

'cftre the JPM begins: insert component malfunction SV3840_a;0 to prevent CV-3840 (LPI/ Decay sat Pump Brg CLR E-50A Inlet) from opening.

When pung is started fail pump bearing temperature to 200*r in one minute using override AO TR6500P_T. Bring in to alarm annunciator K09-E8 (DH Pump /MTR Temp Hi) within one minute.

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Page 3 of 7 .

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TUOI NUMBER: ANO-1-JPM-RO-DHR03

.NITIATING CUE:

OP 1104.004 is complete up to step 7.2.2. The SS/CRS directs that P34A be placed in service with DHR flow at 2000 gpm. l l

ZNSTRUCTOR NOIT: Ensure B-5255 and B-6235 are closed.

CRITICAL ELEMENTS (C): 1, 2, 3, 5, 7, 10, 11, 15 C PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT C 1. Close Decay Heat P-34A Closed CV-1436.

Suction from BWST (CV-1436).

I POSITIVE CUE: l CV-1436 red light off, green )

light on.

C 2. Open Decay. Heat P-34A Opened CV-1434.

Suction fonn RCS (CV- i 1434). l POSITIVE CUE:

CV-1434 red light on, green light off.  !

C

3. Open DH Suction RB Opened CV-1404.

Isolation CV-1404.

- I POSITIVE CUE: i CV-1404 red light on, green.  !

light off.  ;

i NOTE: INFORM EXAMINEE THAT STROKE TESTING OF CV-1410 AND CV-1050 IS NOT REQUIRED.

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4. Verify breaker B-6255 Verified breaker closed AND white Open closed and white Permit light ON -at CV- open permit light 1410 handswitch on C16. on.

POSITIVE CUE:

B-6255 is closed and open permit light is on.

C 5. Open CV-1410. Opened DH suction POSITIVE CUE:

CV-1410 red light on, green light off.

6. Verify breaker B-5255 Verified breaker closed AND white Open closed and white Permit light ON at CV- open permit light 1050 handswitch on Cid. on.

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1 Page 4 of 7 TUOI NUMBER: ANO-1-JPM-RO-DHR03 C' PERFORWANCE CHECKLIST STANDARDS N/A SAT UNSAT C 7. Open DH Suction Valve CV-Opened DH suction 1050 valve CV-1050.

POSITIVE CUE:

CV-1050 red light on, green light off.

8. Close decay heat cooler Closed CV-1428 E-35A outlet valve CV-1428.

DOSITIVE CUE:

CV-1428 closed.

9. Position E-35A Cooler Positioned CV-1433 Bypass (CV-1433) to - to - 50% open.

50% as indicated on HIC-1433.

POSITIVE CUE:

CV-1433 - 50% open.

'C 10. Open CV-1401 Opened CV-1401.

POSITIVE CUE:

CV-1401 red light.on, green light off.

NO2T 20 IA OPERA 20R: insert component analfunction SV3840_a;0 to prevent CV-3840 (LPI/ Decay Heat Pump Brg CLR E-50A Inlet) froa opening.

When pung is started fail pump bearing temperature to 200*F in one minute using override AO TR6500P_T. Bring in to alarm annunciator K09-E8 (DH Pump /MTR Temp Hi) within one minute.

11. Start P-34A. Started P-34A.

POSITIVE CUE:

P34A started, red light ON.

NEGATIVE CUE:

P34A did not start,. green light ON and no flow indicated.

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Page 5 of 7  !

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l l 'rUOI NUMBER: ANO-1-JPM-RO-DHR03 l C PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT l

12. Verify LPI/ Decay Heat On C-18, verified 1 Pump Brg CLR E-SOA Inlet CV-3840 and CV-3822 )

(CV-3840) and Decay HT open. Identified i CLR Se?;vice Water E-35A that CV-3840 did Inlet (CV-3822) open. NOT open.

POSITIVE CUI:: )

CV-3822 red light is on, green  !

light off. l NEGATIVE CUE:

CV-3840 green light ON, red j light OFF.

13. Attempt to open CV-3840 Ordered Waste locally. - -

Control Operator to open CV-3840 POSITIVE CUE: 1 cally. j WCO has been dispatched to l manually open CV-3840.

14. Monitor P-34A bearing Monitored P-34A temperatures. temperature at recorder TR6500 on C13 or on the plant Faulted Cue: computer.

P-34A bearing temperature is

,190*F.

15. Stop P-34A. Stopped P-34A by taking HS-1417 on C18 to the stop POSITIVE CUE: position.

(C) green light ON, red light OFF for P-34A.

NEGATIVE CUE:

P-34A bearing temperatures at 199'F and rising.

END l

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Paga 6 of 7 3 EA 005 K4.05 2.5/2.9 Qusstion: How is the idle Decay Heat Pump suction aligned during refueling activities if a leak develops on the transfer canal seal plate gasket?

Antwer The idle Decay Heat pump suction is aligned to the RB Sump.

R1ference Refueling Abnormal Operations (1203.042) Rev 3 Section 2 page 6.

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l Pesocswasuc puw No. Penr*r-uwonst rum Tm2. PAGE: 6 Of 7 REV: 2 1203.042 REPUEUNG ABNORMAL OPERATIONS CHANoE:

SECTION 2 -- TRANSFER CANAL SEAL PLATE GASKET FAILURE 3.5.2 Stop draining of RB sump if in progress.

3.5.3 Align the idle decay heat pump (if available) to take suction from the RB sump.

3.5.4 If the idle pump is not available, stop the running Decay Heat pump and shut the suction valve from the RCS and open the suction valve from the RB sump.

3.5.5 Throttle the decay heat cooler outlet and bypass valves and start the decay heat pump.

3.5.6 Adjust flow to maintain a level in the Fuel Transfer Canal.

3.6 If, for any reason, all the fuel assemblies and control components cannot be returned to the Reactor Vessel, they may be transferred to the Spent Fuel Pool as follows:

3.6.1 Verify the Fuel Transfer Canal level is being maintained with the decay heat system, if necessary, at approximately the same level as the Spent Fuel Pool.

3.6.2 Open SF-45, 3.6.3 Transfer the assemblies or components to the Spent Fuel Pool for storage.

3.6.4 Close SF-45.

NOTE Spent fuel assemblies can not be cooled in the deep end of Fuel Transfer Canal when the canal is pumped down.

3.7 After all fuel assemblies and control components have been placed in either the Reactor Vessel or the Spent Fuel Pool, the Fuel Transfer Canal may be pumped down for repair of the seal plate gasket.

3.8 Notify HP Supervisor prior to pumping down the Fuel Transfer Canal to increase the frequency of surveys of the Fuel Transfer Canal area.

References CR-1-95-0236-76, Radiological hazards associated with CSA lift apply to fuel handling.

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i Page 7 of 7

.t.A 005 K5.03 2.9/3.1 r

-Quastion: What is the primary source of water to initially fill the  !

. . fuel transfer canal and why? ,

s An: war: ' The BWST (T3) is the primary source of fill water because  ;

it is fill grade borated water, i l . Reference Filling and Draining Fuel Transfer Canal (1102.015) Rev 19 $

page 3. i i

System Training Manual 1-05 page 25. i i

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Decay Heat Removal System STM 1-05 Rw. 6 The LPI system can also supply NPSH to the HPI (makeup) pumps when RCS pressure is to high (>l50 psig) for LPI flow to the core to occur and the BWST is empty. This conditions can occur when a small to intermediate sized RCS leak requires the HPI system to inject water into the RCS from the BWST. The suction of the LPI pump is aligned to the RB Sump and the discharge of the LPI pump is s

aligned to the HPI pump suction. This mode of operation is referred to as " piggyback" mode. The " piggyback mode of operation is covered in greater detad in section 2.6.

2.4.1 LPI Mode Suction (Refer to Figure 5.13)

Soumet Dunng an emergmcy edaa the DHR/LPI Pumps can be supplied water from two sources Intial supply of water will be frorn the BWST. Durmg a LOCA event water from the BWST will be iniected into the Reactor Vessel by the HPI and/or the LPI pumps dependag on RCS pressure. Water from the RCS leak will be call-wl in the RB Sump. The DHR/LPI pumps will be ahaned to the RBS when level in the BWST reaches - 6 Ft. 'Ihis allows the DHR/LPI pumps to provide the long tenn cooling of the core by takmg suction from the RBS and injectag into the Reactor Vessel through the normal DHR-LPI/CFT nozzle. The transfer of secoon  !

from the BWST to the RBS is ccatmiled by the operator thmugh the l motor operated isolation valves for each suction source.

2.4.2 Borated Water The Borated Water Storage Tank (BWST) is a field erected, Storage Tank plastic lined, Scissuc Class I storage tank. The BWST is located outside the reactor and annliary buildings withm a fenced in protected area. The BWST is designated as T-3 with a design capacity of

~404,700 gallons. Each foot change in the BWST is equal to ~9639 gallons. The design pressure and t gre for the BWST is 4.33 psig and 150'F. The BWST is vented to atmosphere through a four ,

inch line with isolation valve BW-9. This line also has a non-isolable one inch lins. To provide additional overpressure and vacuum )

i protocuan the BWST is equipped with a dual actmg rehef valve (PSV-1412) mounted on a 8 inch line. PSV-1412 will lift when a positive pressure of 3 psig is sensed in the tank. To prevent from i collapsing the tank during high outflow conditions PSV-1412 will open when a vacuum of.127 inches of mercury is sensed.  ;

The BWST is required by Tech. Specs. to maintain a specified i level band, boron concentration, manual outlet isolation valve locked '

open and a nummum temperature wienever RB Integnty is required.

'Ihe BWST level limits ensure sufficient borated water is available to provide water for ECCS and RB Spray.

BWST water is used to supply the following functions. l Fuel Transfer Canal fill for Refueling Operations.

Supply borated water during emergency conditions.  !

Alternated supply of Makeup water to the Makeup Tank for reachmg cold shutdown.

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l JOB PERFORMANCE MEASURE UNIT: 1 REV # 2 DATE:

)

1 I TUOI NUMBER: ANO-1-JPM-RO-EOP07  !

l- SYSTEM / DUTY AREA: ABNORMAL AND EMERGENCY OPERATIONS l

)

TASK: PERFORM REACTOR TRIP IMMEDIATE ACTIONS j JTAW: 13035010601 KA VALUE RO: 4.0 SRO: 4.6 KA

REFERENCE:

007 EK3.01 i

APPROVED FOR ADMINISTRATION TO: RO: X SRO: X l TASK LOCATION: INSIDE CR X OUTSIDE CR BOTH:

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE): 1 i

PLANT SITE: SIMULATOR: PERFORM _ LAB:

POSITION EVALUATED: RO: SRO:

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:

TESTING METHOD: SIMULATE: PERFORM APPROXIMATE COMPLETION TIME IN MINUTES: 5 MINUTES REFERENCE (S): 1202.001 REV. 26, 1202.012 REV. 3 PC-5 l

EXAMINEE'S NAME: SSN - -

EVALUATOR'S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

Start Time Stop Time Total Time l

SIGNED DATE:

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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l TUOI NUMBER: ANO-1-JPM-RO-EOP07 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

The examiner shall review the " Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.

JPM INITIAL TASK CONDITIONS: Plant is operating at 100% power. RCS pressure is at 1790 psig but the reactor has not tripped, the CBOT is not in the control room.

I TASK STANDARD: Immediate actions of 1202.001 Reactor Trip are completed. This is an immediate action JPM.' Actions for failure of all control rods to insert have been completed. (Alternste success path JPM).

l TASK PERPORMANCE AIDS: Repetitive task 12, Emergency Boration.

NOTE: This is an alternate success path JPM and is intended to be performed on the l simulator, not simulated. Therefore, no positive or negative cues are provided. ,

i Notes to IA Operator and Examiner:

1. Prior to starting this JPM, insert the following malfunctions to stick 2 rods out:

RD363, RD370

2. RT-12 is allowed for performance for emergency boration.

3. The immediate actions are order independent.

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l Page 3 of 6 l

TUOI NUMBER: ANO-1-JPM-RO-EOP07 INITIATING CUE:

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The CRS directs that you manually trip the reactor and perform the Beactor Trip procedure immediate actions.

( NOTE TO EXANZNER: THIS IS AN ALTERNATE SUCCESS PATH JPM THAT INCLUDES A TAtTLT WREN TBE REACwR IS TRZPPED.

CRITICAL ELEMENTS (C): 1, 5, 6, 7, 8, 9, 11, 13 I

(C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT

1. Depress the reactor trip On C03, depressed the (C) pushbutton. reactor trip pushbutton.

, POSITIVE CUE: ,,

l Reactor trip push' button depressed.

2. Identify that 2 rods have On C13, observed 2 rods have failed to insert. failed to trip.

INSTRUCTOR NOTE:

The following ste'p is optional at the trainees discretion.

3. Depress CRD Power Supply on C03 depressed CRD Power Breaker Trip PBs on C03 Supply Pbs (A501 and B631).

(A501 and B631).

POSITIVE CUE:

Breakers A501 and B631 open (Green light on)

4. Verify all rods inserted on C13, observed rod bottom  !

and power dropping. lights for all control rods '

except 2 have come on.

NOTE TO EXAMINER: Give exaaxinee a copy of RT12, Emergency Boration, if examinee requests it. )

(C) 5. Open BWST outlet to OP HPI On C16 or C18, CV-1407 or Pump (CV-1407 or CV-1408). CV-1408 opened (associated valve for the running HPI POSITIVE CUE: pump).

CV-1408 red light on green light off (C) 6. Set Batch Controller for Batch set key depressed, maximum batch size. 999999 gallons batch size set by depressing POSITIVE CUE: eppropriate keys. Depressed l Batch size indicates 999999 enter and lower display keys l on upper display. in sequence (red LED next to I display key should be on).

NEGATIVE CUE:

[ Batch size indicates 500 (or

! whatever is on upper display).

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Page 4 of 6 TUOI NUMBER: ANO-1-JPM-RO-EOP07 (C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT

7. Open CV-1250. On C04, handswitch for CV-1250 is placed in the open (C) POSITIVE CUE: position and CV-1250 CV-1250 is open (red light on opened.

green light off)

8. P39A, P39B or both Started 1 or 2 boric acid started. pumps on C04.

(C)

POSITIVE CUE:

P39A and /or P39B red lights on green lights off.

9. Start the Batch Batch controller started by controller, depressing run pushbutton.

(C)

POSITIVE CUE:

Lower display digital reading is increasing.

NEGATIVE CUE:

Lower display digital reading is staying at O.

10. Set pressurizer level Verified pressurizer level control setpoint to 220 setpoint on CV-1235 inches. controller is set to 220 inches. (If not at 220", set POSITIVE CUE: it to 220").

Pressurizer level control setpoint at 220".

NOTE TO EXAMINER:

Inform examinee " consider that emergency boration started and an additional operator has taken over the duties for finishing RT12."

11. Depress the turbine trip On C01, depressed the (C) pushbutton, turbine trip pushbutton.

POSITIVE CUE:

Turbine trip pushbutton depressed.

12. Verify turbine throttle On Col, verified by and governor valves are observation that all closed. throttle and governor valves are closed.

POSITIVE CUE:

Turbine governor and throttle valves indicate zero.

(C) 13. Reduce letdown by closing on C04, rotated the pot on CV-1223. CV-1223 controller to zero and verified letdown flow on POSITIVE CUE: C04 lowers.

Letdown flow indicator decreased to ~40 gpm.

14. Check SCM adequate. On ICC display on C19 or panel C04, verified by POSITIVE CUE: observation that SCM is SCM indicates 59 'F. adequate.

NOTE: Adequate SCM is 2 30*F.

NOTE: Immediate action steps are order independent.

END

Page S of 6 I KAA 024 AK3.02 4.2/4.4 + f Question: Why is' Emergency Boration not required if only one CRD fails to fully insert? j Answer: A penalty is already assesed when available shutdown margin is calculated of one stuck rod.  ;

t Reference Reactivity Balance Calculation (1103.015) Rev 38 Work Sheet B3 page 16.

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Page 16 of 47 Calculation of Available Shutdown Margin Page 1 of 1

1. Reference Conditions: A. 0% Power C. 2155 psig E. No boron B. 532*F D. No xenon F. No CRAs

2. Burnup EFPD RCS Boron Conc ppm Leakrate gpm

.,... T-ave 'F Rod Index  % Gp 8  %

Imbalance %Pwr Max Quad Tilt  % Quadrant

3. From Attachment B-1:

p(Fuel) = %Ak/k

4. From Attachment B-2: Inverse Boron Worth (IBW) = ppm /tAk/k p(Boron) = (Boron Cone) =

t Asw )

p(Boron) =

4Ak/k NOTE Rod worth is reduced bv'iO% for conservatism. Stuck rod assumes most reactive rod or pair of rods stuck out. Group 8 is assumed to be at nominal hot full power position.

l 5. From Attachment B-5, Table 1: p(CPAs) = %Ak/k (Use value for all rods inserted)

From Attachment'B-5, Table 3: p(Stuck Rod) = %Ak/k Adjusted p(CRAs) =( p( CRAs ) x (0.9)] - p(Stuck Rod)

= (( ) x (0.9)) - ( ) = %Ak/k Adjusted

• p(CRAs) = %Ak/k

6. From RHOBAL Program:

l p(Xenon) =

%Ak/k

7. Available Shutdown Margin: ,

l ASDM = p( Fuel ) - p( Boron ) - Adjusted p(CRAs) - p( Xenon )

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= ( ) -

( )-( ) -

( )

l l- Available Shutdown Margin = %Ak/k

8. If the available shutdown margin is not -1.5 %Ak/k or more negative, refer to

, " Instructions" section of this procedure.

Performed by Date Time Reviewed /

Ves.ified by CRS or S/S Date Time

, FORM TITLE. FORM NO. REV.

WORK SHEET B-3 1103.015D 38

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K&A 007 EA1.06 4.4/4.5 .

Question: What indicates that a control rod is fully inserted aAer a reactor trip? l 4

Answer: Each rod has a green "In Limit" lamp that is activated by the 0% absolute position limit  ;

switch. )

Reference System Training Manual 1-02 Rev 4 page 17, l

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Control Rod Driva System STM 1-02 Rev. 4 there is a reed switch every 2 inches of rod travel. Switches located on the indivulual buffer amplifier cards can be used to switch either strmg offin the event of a failure in one of the stnngs.

2.6.2 Relative Position The relative position indication receives its signal by monitoring l

Indication System the input pulses to the CRDM motor. Refer to figure 2.38. Every other phase of the six phase input to the CRDM is used to drive a stopping motor which operates a rheostat N-ing the rhoostat vanes the signal to the RPI amplifier which converts the signal into a reistive position !='I=: , Readout is on the Position Indication Panel (PIP).

De relatrve and absolute indications should agree within their respective accuracy's, except when the control rod is tripped from the withdrawn position. In this case, the absolute PI would follow the control rod as it dropped to its in-limit, but the relative PI would remam where it was before the drive was tripped. His is true l ,

because no input pulses are applied to the motor during the trip.

l Followmg a trip, the relative PI must be reset to zero; this is done at the PIP using the relative PI reset pulser. He accuracy of relative position inde= tina is 1/16 inch.

I 2.6.3 Position Each control rod has a position indication meter on the PIP i Indication Panel (PIP). which is located directly in front of the main console on C14. Refer l to figure 2.39. De meter indicates rod position in units of percent ,

l withdrawn. There are 69 vemcal scale meters arranged in a j horizontal line for convenient comparison at a distance (68 meters are l used). Provisions are made for identifying each rod group by codmg I alternate groups black and white. . Each meter has a green light l labeled "In Limit" and a red light labeled "Out Limit", a white )

" Control On" light and an amber " Fault" light associated with it.

Note: the "In Lumst" bght is actuated by the 0% hmut switch and the "Out Limit " bght is actuated by the 100% hmst switch.

Two switches are also mounted on the PIP. One is used to select either absolute or relative readout on the panel display. The second switch controls the reset pulser. This switch is used to return the relative PI to zero in the event of a tnp or ifit is otherwise desired to artificially change the relative PI readout. The reset pulser is used in conjunction with the group and individual rod select switches located on the Diamond Panel (operators control panel).

He control on light indicates that the group or individual CRDM is ready to or is being moved (it is " Enabled").

l The individual fault lamp indicates that a rod is more than seven mches out of alignment with the average position of all rods in its associated group.

2.6.4 Group Average Four group average meters are mounted on the main console Indication (C03) just above the Diamond Panel. Refer to figure 2.59. A two position selector switch is used to select either the four safety groups i

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Page 1 of 5 l

JOB PERFORMANCE MEASURE

. UNIT: 1 REV # 5 DATE:

TUOI NUMBER: ANO-1-JPM-RO-PZR04  !

SYSTEM / DUTY AREA: PRESSURIZER SYSTEMS TASK CONTROL RCS PRESSURE IN MANUAL IN RESPONSE TO RCS PRESSURE HI ANNUNCIATOR JTA# 10105010101 I KA VALUE RO: 3.6 SRO: 3.5 KA

REFERENCE:

010 000 A3.02 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE: SIMULATOR: PERFORM LAB: _

POSITION EVALUATED: RO: SRO:

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:

TESTING METHOD: SIMULATE: PERFORM:

APPROXIMATE COMPLETION TIME IN MINUTES: 5 MINUTES REFERENCE (S) : 1203.012H REV. 29 PC 1 EXAMINEE'S NAME: SSN - -

EVALUATOR'S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

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l Start Time Stop Time Total Time SIGNED DATE:

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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Page 2 of 5 TUOI NUMBER: ANO-1-JPM-RO-PZR04 l THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

The examiner shall' review the " Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.

JPM INITIAL TASK CONDITIONS: Plant is at steady state power operations when the RCS PRESSURE HI/LO KO9-C1 annunciator alarms.

TASK STANDARD: Pressurizer Spray Valve CV-1008 manually opened and RCS pressure lowered to clear RCS PRESSURE HI/LO annunciator.

TASK PERFORMANCE. AIDS: 1202.012H, Annunciator K09 Corrective Action NOtt TO ZA OPERATOR: fail pressuriser spray valso so that it doesn't work in auto by inserting override DZ BS1003_AIT and then make snapshot with high RCS pressure with heaters turned automatically off.

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TUOI NUMBER: ANO-1-JPM-RO-PZR04 INITIATING CUE:

The SS/CRS directs you to perform corrective actions for annunciator K09-C1, RCS PRESSURE HI/LO.

CRITICAL ELEMENTS (C): 3, 5, 6 i

(C) PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT

1. Confirm validity of Verified RCS pressure high annunciator by comparing RC by comparing indicators on pressure indications on C04. C04 or by SPDS or by plant computer POSITIVE CUE:-all RCS pressure indicators on C04 indicate 2260 and rising.

Zafosan examinee that the SS is referringr to Tech Specs for RC pressure .ILuits.

2. Verify all pressurizer On C04, verified that all heaters are off. heaters are on by observing

red lights on for the POSITIVE CUE: heaters on. heaters.

3. Place all PZR pressurizer On C04 all handswitches in heaters handswitches in OFF off position with grean

(C) poistion lights only on.

POSITIVE CUE: Heaters off.

4. Verify Pressurizer Spray Deterndned that the

! valve CV-1008 open. Pressurizer Spray valve CV-l 1008 is closed when it i NEGATIVE CUE: CV-1000 green should be open (by observing light ON, red light OFF. green light ON and red light OFF for CV-1008 on panel '

i C04.

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5. Place Pressurizer Spray Placed Pressurizer Spray

control Mode switch in HAND. Control Mode switch in HAND (C) on panel C04.

POSITIVE CUE: mode switch in HAND.

6. Open CV-1008. On C04, opened Pressurizer Spray. valve (modulating (C) POSITIVE CUE: RCS pressure is valve) as necessary to

lowering, RCS PRESSURE HI/LO control RCS pressure and cleared. cleared RCS PRESSURE HI/LO 9- annunciator.

NOTE: examinee would now operate Spray valve in manual as necessary until repairs can

! be made.

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Page 4 of 5  ;

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1 K&A 010 K1.08 3.2/3.5 1

Question: At what pressurizer level are all heaters interlocked offl j e l f i Answer: : 55 inches. i Reference Pressurizer Operation (1103.005) Rev 27 PC3 page 2.  !

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PROCMORK PLAN NO. MtOCEDURE/ WORK PLAN TITLE

• PAGE: 2 of 33

'1103.005 PRESSURIZER OPERATION REV: 27 CHANGE:

1 1.0 PURPOSE 1

1.1 This procedure provides instructions for performing various pressurizer and Quench Tank related operations.

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• l 2.0 SCOPE i

, 1 l This procedure covers pressurizer operations during startup, nornal operation l and depressurization. It also covers ERV testing and Quench Tank operation.  ;

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3.0 DESCRIPTION

l 3.1 The pressurizer controls RCS pressure and absorbs volume changes in the RCS caused by density variations. Electric heaters in the pressurizer heat water to the saturation temperature for the desired RCS pressure. The steam bubble formed in the pressurizer acts as a surge chamber during changes in coolant density. J 3.2 During a RCS Tave drop, the resultant contraction of coolant causes an t out-surg,e.from the pressurizer. RCS pressure drops and some of the l pressurizer water flashes to steam, minimizing the pressure drop. As pressure drops, additional pressurizer heaters are energized to restore normal RCS pressure.

3.3 During a RCS Tave rise, the resultant coolant expansion causes an  !

in-surge into the pressurizer. The pressurizer steam bubble is  !

i compressed, pressure rises causing some steam to be condensed, which l aids in cont:alling the pressure rise. All pressurizer her.ters are j de-energized above 2155 psig. During all conditions other than MFW pump trip at >80% Rx power, a pressure rise to 2205 psig causes the Pressurizer Spray Valve (CV-1008) to open and admit reactor coolant to the steam space through the spray nozzle. When pressure has returned to normal the spray valve closes (2155 psig). If Rx power is >80% and l a MFW pump trips, a 125 psig bias is applied to the spray valve causing it to open at 2080 psig and close at 2030 psig. This minimizes the RCS pressure spike following MFW pump trip.

3.4 A continuous spray flow of 1 gpm is maintained during normal operation by a Spray Line Minimum Flow Rate Valve (RC-4), which bypasses the pressurizer spray valve. This minimizes surge and spray line temperature differentials, thus minimizing thermal shock on spray nozzle, and helps maintain pressurizer boren concentration near or equal to that in the RCS.

3.5 There are three bundles of pressurizer heaters divided into five banks. There is a total of 117 heaters, each rated at 14 KW. Heater banks 3, 4, and 5 are on-off control. Heater banks 1 and 2 have a variable output and modulate to maintain -2155 psig reactor coolant system pressure. All heaters are interlocked off at 555" in the pressurizer.

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i KAA' 010 K4.03 3.8/4.1 Question: What is the Electro-Magnetic Relief Valve setpoint? -

l' Answer: 2450 psig.

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. Reference Pressurizer Operation (1103.005) Rev 27 PC 3 page 3. l l

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PROCJWORK PUUd NO. PROCEDURFJWORK PLAN TITLE: PAGE: 3 Of 33 1103.005 PRESSURIZER OPERATION REV: 27 CHANGE [h_l In the event of Pressurizer Code Safety (PSV-1001, PSV-1002) or ERV (PSV-1000) leakage, heater load will rise at a rate of 8.75 KW for each 0.1 gpm leakage. Analysis has shown that with a pressurizer

. steam space leak of $1 gpm, vital powered heaters can maintain 220*F SCM for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. Steam space leakage in excess of 1 gpm has not been analyzed and may be beyond pressurizer heater capacity during loss of offsite power.

3.6 RCS pressure excursions which exceed the pressurizer spray capacity will open the ERV (PSV-1000) at 2450 psig and discharge excess steam to the Quench Tank (T-42). When pressure drops to 2395 psig, the ERV will close. According to T.S. 4.1-2.16 RCS Vent Paths must be demonstrated operable by having flow verified through them at least once per 18 months during cold shutdown. The ERV is one of these vent paths.

3.7 Pressurizer level is controlled by the Makeup and Purification system.

During normal operation, level is controlled by a level signal to the Pressurizer

• Level Control Valve (CV-1235). The level setpoint can be adjusted for various pressurizer operations. There are two level detectors and two temperature detectors on the pressurizer, Temperature Transmitters (TE-1001A, TE-1002A) and Level Transmitters (LT-1001, LT-1002). Each level signal is temperature compensated by its associated temperature detector and displayed on either Pressurizer Level Indicator-Switch (LIS-1002) or Pressurizer Level Recorder-Switch (LRS-1001) on C04. The Level Transmitter Selector (HS-1002) on C04 connects one of the temperature-compensated levels as input to the following:

• Pressurizer Level Control (LIC-1000)

• PZR LEVEL HI/HI alarm

• PZR LEVEL LO LO ALARM

= PZR low level interlock to PZR heaters

• Pressurizer Level Indicator (LI-1000) on Dasey Panel (C166)

4.1 REFERENCES

USED IN PROCEDURE PREPARATION l l

7 4.1.1 LIC-96-014 ANO-1 Pressurizer Heater Technical Specification j q-g Requirements 1

4.1.2 Unit One Technical Specifications 4.1-2.16, 4.1-2.17, 4.0.5 4.1.3 NRC INFO Notice #89-32: Surveillance Testing of LTOP Systems

4.1.4 ANO-89-05566

Fail Safe Valve Testing

4.1.5 CR-1-90-43

ERV Stroke Time 4.1.6 BWSI-770603-091 Pressurizer Spray Valve Operation 1

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Page 1 of 6 f JOB PERFORMANCE MEASURE l j j UNIT: 1 REV # 1 DATE:

j TUOI NUMBER: ANO-1-JPM-RO-RPS01 SYOTEM/ DUTY AREA: REACTOR PROTECTION SYSTEM TASK: PLACE A CHANNEL OF RPS IN MANUAL BYPASS JTA# 10125020101

.KA VALUE RO: 3.6 SRO: 3.6 KA

REFERENCE:

012 000 A4.03 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X j l . TASK LOCATION: INSIDE CRs X OUTSIDE CRs BOTH:

j SUGGESTED TESTING ENVIRONMENT *AND METHOD (PERFORM OR SIMULATE):

PLANT SITE: SIMULATOR: PERFORM _ LAB:

POSITION EVALUATED: RO: SRO:

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB: l l TESTING METHOD: SIMULATE: PERFORM:

! PROXIMATE COMPLETION TIME IN MINUTES: 5 MINUTES I REFERENCE (S): 1105.001 REV. 16 PC 1 l

, ' EXAMINEE'S NAME: SSN - -

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EVALUATOR'S NAME:

J l THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDAPJ)S CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

L i

Start Time Stop Time Total Time 93GNED DATE:

"GNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A aUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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Page 2 of 6

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TUOI NUMBER: ANO-1-JPM-RO-RPS01 "dE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE .

l Th3 Examiner shal review the " Briefing Checklist - System Walkthrough" portion of OP

, 1064.023 Attachment 6 with the examinee.

JPM INITIAL TAKS CONDITIONS: The plant is operating at 100% power with all ICS stations in cutomatic. A potential problem exists in the "A" RPS cabinet that could lead to a chnnnel trip.

TASK STANDARD: The "A" RPS cabinet is in Manual Bypass l

TASK PERFORMANCE AIDS: Simulator and 1105.001 and the Manual Bypass key.

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Page 3 of 6 TUOI NUMBER: ANO-1-JPM-RO-RPS01

.NITIATING CUE:

The CRS directs you to place the "A" RPS channel in Manual Bypass.

CRITICAL ELEMENTS (c): 5 C PERFORMANCE CHECKLIST STANDARD- N/A SAT UNSAT

1. Verify no other RPS channel is Looked in the RPS cabinet in manual bypass. in the back of the control room and verified no manual Note: Due to the uniqueness of the (or channel) bypass lamps design in the simulator, all are lit or verified that channel indications are located in K08D3, RPS Channel Bypass, one RPS cabinet. annunciator is clear.

POSITIVE CUE: no manual (or channel) bypass lamps are lit or l K08D3 RPS Channel Bypass is clear.

2. Verify no EFIC Channel is in on the EFIC cabinets, Maintenance bypass that does not verified that no correspond to the RPS channel to " Maintenance" lamps are lit be placed in manual bypass. for any channel or verified that K12F7, EFIC CH Maint POSITIVE CUE: no

• Maintenance" Bypass, annunciator clear.

lamps lit for EFIC cabinets or K12F7- EFIC CH Maint Bypass clear. ,

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3. Place the SASS Rx Power input On C03, compared NI )

to ICS selector switch on C03 in indicators and determined

, the "Y" position. if the ICS needs to be placed in manual operation.

Note: If a difference exists Then selected the "Y" between compared values of >l%, the input to ICS for Rx power.

l- Diamond and Reactor Demand stations

! of ICS should be placed in Manual,

, Note: if simulator and/or plant  ;

computer unavailable tell examinee  !

that all four power range instruments indicate the same value.

POSITIVE CUE: "Y" position I selected.

4. Obtain the RPS Manual Bypass From the key locker in the key from the SS. SS office or from the examiner, obtained the RPS I POSITIVE CUE: give key to examinee. Manual Bypass key.

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Page'4 of 6 TUOI NUMBER: ANO-1-JPM-RO-RPS01 C PERFORMANCE CHECKLIST STANDARD N/A SAT UNSAT

5. In the RPS cabinet, placed the In the RPS cabinet, key switch for the appropriate inserted the key in the key channel on the selected Rx Trip switch in the "A" Reactor module to the bypassd position. Trip Module and placed the i C switch in the bypass Note: In the simulator at this time position.

(5-7-96), the "A" RPS cabinet is laid out as at the plant but is not powered up. Therefore, the examiner will have to cue the examinee as-lights change status, etc.

6. Verify the manual bypass lamps Verified the Manual Bypass on the Rx Trip module and the lamp on the Rx Trip Module indicating panel go on bright. went BRICHT and the Manual

, . Bypass lamp on the Note: The Rx Trip module lamp will indicating panel for "A" not illuminate, so the examinee RPS went BRIGHT.

would have to point out the light.

POSITIVE CUE: manual bypass lamps on bright.

7. Verify Auxiliary Relay lamps Verified Auxiliary Relay for Manual Bypass to EFIC and lamps for Manual Bypass Manual Bypass to annunciator are to EFIC and Manual on bright. Bypass to annunciator are on bright.

NOTE: located in the left side of the RPS cabinent.

POSITIVE CUE: lamps on bright.

8. Verify the associated EFIC- On the EFIC cabinet, the channel Maintenance light is " Maintenance" lamp for the flashing. "A" EFIC channel is I

verified to be flashing.

POSITIVE CUE: light is flashing.

9. Verify the annunciator for RPS On KOB, verified the l CHANNEL BYPASSED (K08-D3) is in annunciator is in alarm for alarm. RPS CHANNEL BYPASSED.

l POSITIVE CUE: K08D3 in alarm.

END l

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! 1A 012 K4.06 3.2/3.5 l

l Quastion: If the "B" EPIC channel is in bypass and the "A" RPS channel bypass ,

switch is placed in the bypass position what occurs? 1 l

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An:wer: The "A" RPS channel will go to bypass and the "B" EFIC channel will be automatically removed from bypass even though it's key switch is in the l bypass position.

Rafarence NI & RPS Operating Procedure (1105.001) Rev 16 PC 1 page 11.

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PftOCJWORK PLAN NO. PROCEDUREMf0RK PLAN TITLE: PAGE: 11 of 31 REV: 16 j 1105_001 NI & RPS OPERATING PROCEDURE CHANGE:

I 10.0 Placing a RPS Channel in Manual Bypass NOTE Only one RPS Channel may be placed in Manual Bypass at a time.

10.1 Determine which RPS Channel is to be placed in Manual Bypass and verify no other RPS Channel in Manual Bypass.

l C'JU3 TIC 24 l Placing a RPS Channel in Manual Bypass will remove any noncorresponding EFIC Channel from Maintenance Bypass causing possible EFIC actuation.

10.2 Verify no EFIC channel in Maintenance Bypass that does not correspond to the RPS Channel to be placed in Manual Bypass.

10.3 Place SASS Neutron Flux selector switch on C03 in the "X" or "Y" position hs*follows:

10.3.1 Compare Plant Computer point N1I56HI to N1I78HI.

A. If Plant Computer is not available, compare the highest of NI-5 and NI-6 to the highest of NI-7 and NI-8 on C03.

10.3.2 If the difference between the compared values is >1%, place the Diamond and Rx Demand H/A. stations in manual.

10.3.3 If placing RPS Channel "A" or "B" in Manual Bypass, place l Neutron Flux selector switch to the "Y" position.

10.3.4 If Placing RPS Channel "C" or "D" in Manual Bypass, place l Neutron Flux selector switch to the "X" position.

10.3.5 If ICS H/A stations were placed in manual for this step, stations may be returned to auto per ICS Operating Procedure (OP 1105.004), " Transferring ICS Control Stations to Auto" section.

10.4 Obtain the RPS Manual Bypass key from the Shift Superintendent.

10.5 Place key switch on the selected Rx Trip module to the bypass position and verify the following:

10.5.1 Manual Bypass lamps on the Rx Trip module and indicating panel go on bright.

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Page 6 of 6 i

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..W 012 K2.01 3.3/3.7 l

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Quastion: What'is the power supply for the "A" RPS channel cabinet?

i Answer: Panel RS-1 breaker.1.

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R3ference Inverter and 120V Vital AC Ditribution (1107.003) Rev 8 PC 4 Exhibit A page 135..

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PROCJWORK PLAN NO. Amm PLAN TTTLE: PAGE: 135 of 144 REV: 9 1107.003 . INVERTER AND 120V VITAL AC DISTRCUTION cHANOE.

EXHIBIT A OP 1107.003 Exhibit A l PANEL RS1 REVISED 9/18/96

.l. Power Source: Inverter Y11 g Y15 Location: Control room NOTE: All breakers except spares should be closed.

1 "A" RPS Cabinet C41 2 ESAS Analog-1 Panel C88 3 Spare 4 ESAS Digital-1 Panel C86 Reactor Building Pressure 5 CRD #1 C49 6 Transmitter PT-2400 to "A" RPS CV-7910 position indication C19 LPI/ Decay Heat Pump Brg. CLR E-50A Rad. Monitor Panel C24 7 Inlet CV-3840 and C18 Indication 8 Rad. Monitor Panel C25 Bay 1 9 NNI X C47 Normal Supply 10 Auxiliary Equipment Panel C486-1 l H2 Analyzer C178 11 SV-1840 - Hot Leg Sample Isol. 12 EFIC channel A Panel C37-1 Instrument Cabinet C544 13 Panel C09 14 (ICS Room)

EFIC Trip Interface Instrumentation 15 Panels C511 and C513 16 Cabinet C539 Penetration Room Ventilation i

17 Panels C03 & C04 Indicator Power 18 Flow Switch C28  ;

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ADMINISTRATIVE SECTION TEST #2 RO ADMINISTRATIVE OUESTION Page 1 of 12 Operating Test 2 RO Subject Al (Closed Reference)

QUESTION A1-1:

Reference:

K&A 2.1.20 4.3/4.2 If a procedure step is unclear or confusing what action should you take?

ANSWER:

Do not interpret the step. Obtain guidance from your supenisor.

REFERENCE:

Procedure Control (1000.006) Rev 46 PC 1 page 30. j i

l COMMENTS:

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PROCJWORK PUUd NO. PROCEDUREUWORK PLAN TITLE: PAGE: 30 of 80 j 1000.006 PROCEDURE CONTROL REV: 46 i CHANGE: )

l 6.5.2 Procedures are written for an ind'ividual who has been l trained and is qualified. Procedures are not written for l blind compliance. Procedure users are expected to j understand what they are doing and practice self-checking  ;

. *- during procedure performance. )

1 6.5.3 If a procedure step is unclear, do not interpret. Obtain guidance from your supervisor. {

6.5.4 If problems occur during procedure performance due to unexpected results, equipment malfunctions, changing conditions, or procedure deficiencies, the user shall do the following:

A. Stop work and if necessary, take actions to place equipment in a safe condition. (OCAN089201) l l

l B. Notify SS/CRS if equipment operational status is affected.

C. Consult with supervision to evaluate problem cause and follow-up actions.

D. If the activity cannot be completed, appropriate steps of the procedure may be selected and performed to l return the system / plant to a proper configuration. In this case, partial perf ormance for equipment restoration is not considered a procedure deviation.

E. If a procedure change or deviation is required to complete the activity, process and obtain approval of the change or deviation. Then proceed with the activity.

6.5.5 If an identified procedure error could affect plant or personnel safety, then immeciately change the procedure, or inactivate (using 1000.006K) the procedure until a change can be processed.

6.5.6 If changing conditions have the potential of causing previously performed steps to be invalid, an evaluation shall be performed to determine whether any steps must be repeated.

6.5.7 If a procedure and another station document are in conflict, stop and notify supervision. Appropriate corrective action shall be initiated to resolve the discrepancy.

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1 ADMINISTRATIVE SECTION TEST #2 RO ADMINISTRATIVE OUESTION Page 2 of 12 EXAMINEES COPY

u QUESTION Al-1

(Closed Reference)

, , If a procedure step is unclear or confusing what action should you take?

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' ADMINISTRATIVE SECTION TEST #2 RO ADMINISTRATIVE OUESTION Page 3 of 12 Operating Test 2 RO Subjec' A1 (Open Reference) .

QUESTION Al-2:Refert-2: K&A 2.1.30 3.9/3.4

, , Where and how can the main turbine be tripped?

ANSWER:

Using the Turbine Trip Pushbutton on C01 Locally at the front standard using the Turbine Trip Intr.

REFERENCE:

Alternate Shutdown AOP (1203.002) Rev 13 PC 4 page 3 and 6 COMMENTS:

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PROCJWORK PLAN NO. PROCEDURE / WORK PLAN TITLE: PAGE: 3 of 84 )

1203.002 ALTERNATE SHUTDOWN REV: 13 CHANGE: g,y SECTION 1 Page 1 of 2 IMMEDIATE CONTROL ROOM EVACUATION i l

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~ " DISCUSSION Section 1 covers immediate Control Room evacuation as a result of a fire in the Control Room (zone 129F) or Cable Spread Room (zone 97R). This section can be performed by four operators as a minimum. The Shift Superintendent goes to the third floor TSC. The CRS and two RO's go into the plant. The auxiliary operator and waste control operator are left available for fire brigade. Refer to Attachment 9 of this procedure for further discussion.

1.0 SYMPTOMS 1.1 Fire in Control Room renders Control Room uninhabitable.

1.2 Fire in Control Room threatens immediate damage to major portions of vital controls.

1.3 Fire in Cable Spread Room threatens immediate damage to significant number of cables.

2.0 IMMEDIATE ACTION 2.1 Manually trip reactor and verify reactor is shutdown.

NOTE Control Room actions not completed due to need for Control Room evacuation are accomplished by backup methods outside the Control Room.

3.0 FOLLOW-UP ACTIONS -- Control Room

• 3.1 Manually trip Turbine and verify Turbine throttle and governor valves

• closed.

l hj. 3.2 Actuate EN for both SGs. I hl 3.3 Close MSIVs and Main Feedwater Isolations for both SGs.

i i i SG-A SG-B CV-2691 CV-2692 CV-2680 CV-2630 h*l 3.4 Open SERV WTR to DG Coolers DG1 DG2 CV-3806 CV-3807 l 3.5 Close Letdown Coolers Outlet (CV-1221).

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PROCM.NIK PLAN 6 O. PROCliDURE/ WORK PLAN TITLE: PAGE: 6 of 84 1203.002 ALTERNATE SHUTDOWN REV: 13 CHANGE: g.j i --

l SECTION 1A Page 2 of 4 SHIFT SUPERINTENDENT FOLLOW-UP ACTIONS l , ,

3.3 Perform radio check.

l  ? 3.3.1 Verify non-Fire Brigade Auxiliary Operator verifying SW I

( aligned to EDGs.

3.4 Manually trip both Main Feedwater Pumps locally.

I 3.5 Manually trip main turbine with TRIP lever at front standard.

3.6 Go to Technical Support Center (3rd floor admin. building).

NOTES

1. Emergency Plan implementing procedures and the Emergency Coordinator's Notebook are available in the TSC.

2. Performance of either Section 1 or 2 of this procedure constitutes a condition reportable under 10CFR50.54(X), " Action taken in emergency.

which departs from Tech. Spec. requirements."

l 3.7 Initiate Emergency Plan per Emergency Action Level Classification l (1903.010), and perform the following:

3.7.1 At a minimum, an Alert should be declared and all emergency teams called out.

3.7.2 Initiate a Condition Report.

3.7.3 Within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> make required NRC notifications via hotline.

3.7.4 Call out at least one additional cperator per classification.

i NOTES i

1. Extra operators are numbered beginning with operator #3 in order to distinguish extra operators from RO #1 and RO #2.

2. ADV control will have priority initially if extra operators are available; however, as time elapses, the priority for assigning extra operators may shif t to aligning vital MCCs first. i

3. Gloves, hearing protection, and a copy of Exhibit A are located in ADV l Operation tote bag in Alternate Shutdown locker.

3.8 When extra operators are available, assign extras as follows, unless plant conditions dictate otherwise:

A. Operator #3 -- perform Exhibit A (ADV control).

B. Operator #4 -- assist CRS by performing Attachments 3 and 4.

C. Operator #5 -- assist RO #1 by performing Attachment 5.

3.9 Call up Alternate Shutdown display on SPDS (A/S-G).

3.10 Verify radio or telephone communications established.

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l ADMINISTRATIVE SECTION TEST #2 RO l

1 ADMINISTRATIVE OUESTION i Page 4 of 12 l . EXAMINEES COPY Operating Test 2 RO (Open Reference) l

,. . QUESTION A12:

i .. Where and how can the main turbine be tripped?

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ADMINISTRATIVE SECTION TEST #2 RQ l ADMINISTRATIVE OUESTION

! Page 5 of12 Operating Test 2 RO Subject A3 (Closed Reference)

QUESTION A3-1:

Reference:

KAA 2.3.10 2.9/3.3 During perfonr.ance of Control of Secondary System Contamination (1203.014) how is radiation exposure to the polisher control panel and the train bay minimized?

ANSWER:

C & D polishers are preferred to be left in service to maximize distance from the polisher control panel and the

! train bay and the contaminated resin.

REFERENCE:

Control of hand y System Contamination (1203.014) Rev 11 page 1.

COMMENTS:

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PROCJWORK PLAN NO. PROCEDURE / WORK PLAN 1TTI.E: PAGE: 1Of4 1203.014 CONTROL OF SECONDARY SYSTEM CONTAMINATION REV: 11 l CHANGE:

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DISCUSSION This procedure is used in the event of a primary to secondary SG *,ube leak.

The intent is to prevent an un-monitored radioactive release from the Turbine

,, Building. Instructions are provided to minimize both the spread of contamination and personnel exposure to radiation.

Also provided in this procedure are instructions for handling large amounts of contaminated water.

1.0 SYMPTOMS Control of secondary system contamination required by either Small Steam Generator Tube Leaks (1203.023) or Tube Rupture (1202.006).

l l 2.0 IMMEDIATE ACTION l

None.

3.0 FOLLOW-UP ACTIONS,..

3.1 If trench dump is in progress, stop trench dump by placing the following handswitches in OFF:

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• Trench Sump Pump (P-122A)

• Trench Sump Pump (P-122B)

• Emergency Trench Sump Pump (P-97)

-3.2 If shutdown is required, perform the following:

3.2.1 Align condensate Polishers to prevent wide spread contamination of polisher resin and reduce secondary system activity level as follows:

A. Inform Control Room personnel of intent to remove all but two polishers from service.

NOTE To minimize radiation exposure to personnel at the polisher controls and in the train bay, it is preferred that C & D polishers remain in service.

1 B. If only one polisher is in service and flow can be maintained >1500 gpm/ polisher with two polishers, perform the following:

l 1. Place an idle polisher in service per Condensate l Demineralizer System Operation and Regeneration  !

(1106.024), Section 10. i

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l ADMINISTRATIVE SECTION TESTC2 RO ADMINISTRATIVE OUESTION Page 6 of 12 l EXAMINEES COPY Operating Test 2 RO (Closed Reference)

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,, QUESTION A31 l During performance of Control of Secondary System Contamination (1203.014) how is radiation exposure to the l polisher control panel and the train bay minimized?

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l ADMINISTRATIVE SECTION TEST 02 RO  !

ADMINISTRATIVE OUESTION 1 Page 7 of 12 l l

Operating Test 2 RO Subject A3 (Open Reference) l l QUESTION A3-2:

Reference:

K&A 2.3.11 2.7/3.2 l Concerning the Liquid Radwaste Process Monitor (RI-4642), describe how it is checked available for a liquid release.

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l l ANSWER: If the monitor count rate is $1000 epm perform the following j e Verify no Liquid Releasce is in progress using FI-4642.

i e Select " Check Source" on RI 4642 and verify the monitor count rate responds to l check source with a count rate increase >100 cpm.

If monitor count rate is >1000 cpm, then verify that count rate is <4.22E6.

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REFERENCE:

Clean Waste System Operation (1104.020) Rev 36 PC 2 Attachment C page 75 and 78.

1 COMMENTS:

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PROCJWORK PLAN NO. PROCEDUREMORK PUW TITLE: PAGE: 75 of 90 .

1104.020 CLEAN WASTE SYSTEM OPERATION REV: 36 CHANGE:

ATTACHMENT C Page 2 of 7 ,

l 1.4 Initial tank level  %. Record local or '

, ,. remote level indication. (circle one) l 1.5 Check Liquid Radwaste Process Monitor (RI-4642) available by one of the following methods:

1.5.1 If monitor count rate is s:1000 cpm perform the following:

A. Verify no Liquid Release in progress using FI-4642.

B. Select " Check Source" on RI-4642 and verify the monitor responds to check source with a count rate increase >100 cpm.

l. 1.5.2 , M monitor count rate >1000 cpm, then verify that count rate is <4.22E6.

l 1.6 Verify that RI-4642 is not inoperable for any other reason.

l 1.7 Submitted to Nuclear Chemistry by OPS Date Time i

Section 1.0 Performed By 2.0 Analysis (Nuclear Chemistry) 2.1 Tank sample obtained for gamma spectroscopy l'

analysis by I \

2.2 Tank sample obtained for pH analysis by l l

i 2.3 If required for weekly sample for oil and grease, tank ,

sample obtained. Otherwise N/A. '

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. _ _ _ _ ___ . ~_______._.--m_ -_ _ . _ . - - _ _ _ ._- . . . . _ _ _ ___ . .. -___m-PnoCAWORK PLAN NO. PpmuMUWORK PLAN Tm.E: PAGE: 78 of 90 1104.020 CLEAN WASTE SYSTEM OPERATION RW: 36 i CHANGE.

ATTACHMENT C Page 5 of 7 3.7 From tank to be released, determine operating procedure

., , attachment to be used to perform release.

3.7.1 If Laundry Drain Tank, use Laundry Waste Processing (1104.015), Attachment B. Otherwise N/A.

A. Laundry Drain Tank (T-19A or T-19B)

B. Laundry Drain Tank (T-109A/T-109B) i 3.7.2 If Filtered Waste Monitor Tank (T-21A or T-21B), 4 use Dirty Liquid Waste & Drain Processing (1104.014), Attachment D. Otherwise N/A.  ;

I 3.8 Control Room personnel shall record data in section 1.0 and  ;

N/A the appropriate steps on the attachment used to perform j the release., .

l l 3.9 If Liquid Radwaste Process Monitor (RI-4642) is operable I and available, verify proper operation of radiation monitor i and interlocks as follows. Otherwise N/A.  !

l 3.9.1 Verify the following valves closed: )

A. EWMT Disch to CW Flumes (DZ-25)

B. LZ Drain Pump P-45 Discharge to Flume (LZ-5)

C. Treated Waste Discharge to Cire Water Flume (CZ-58) 3.9.2 Check Liquid Radwaste Process Monitor (RI-4642) available by one of the following methods:

A. If monitor count rate is s1000 cpm, select CHECK SOURCE on RI-4642 and verify that the monitor responds to check source with a count rate increase >100 cpm.

B. If monitor count rate >1000 cpm, then l Verify that count rate is <4.22E6.

ADMINISTRATIVE SECTION TEST #2 RO ADMINISTRATIVE OUESTION Page 8 of12 EXAMINEES COPY

- Operating Test 1 (Open Reference)

, QUESTION A3-2:

Concerning the Liquid Radwaste Process Monitor (RI-4642), describe how it is checked available for a liquid release.

ADMINISTRATIVE SECTION TEST #2 RO ADMINISTRATIVE OUESTION Page 9 of12 Operating Test 2 RO Subject A4 (Open Reference)

QUESTION A4-1:

Reference:

KAA 2.4.32 3.3/3.5 How can you as an operator in the Control Room know when an annunciator panel has lost AC or DC power?

ANSWER:

Here are two smalllamps on each panel. One is for AC power the other for DC power. These lamps are l normally lit and extinguish if the respective power is lost.

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REFERENCE:

Loss of Control Room Annunciators (1203.043) Rev 0 PC 1 page 1 ,

1 COMMENTS: ,

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PROC ANORK PLAN NO.

m ARKANSAS NUCLEAR ONE i!!!!!!!E Entergy uoa.o43 8'"8 "'" """"""*"""""'" "" '

OPmWm ABNORMAL LOSS OF REV:

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CHANGE:

OPERATING CONTROL ROOM ANNUNCIATORS DISCUSSION This procedure was developed in response to concerns expressed by INPO and the NRC in PIE-92-0218-B concerning Loss of Control Room Annunciators.

1.0 SYMPTOMS ,

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1.1 Loss of both AC power available lamp and DC power available lamp below any I control room annunciator panel.

1 1.2 Loss of any control room annunciator panel alarm capability.

2.0 IMMEDIATE ACTIONS 2.1 None. ,

. . . 1 3.0 FOLLOW-UP ACTIONS 3.1 Notify Shift Superintendent to implement Emergency Action Level  ;

Classification (OP 1903.010). j 3.2 At the descretion of the CRS, based on which alarm capability is lost, perform the applicable following steps.

3.2.1 Check and attempt to reset associated AC and DC power supplies (Y01-24 and D11-30).

3.2.2 Make the following announcement over the plant page system:

" Attention all personnel, attention all personnel. Unit One has experienced a loss of control room annunciators. All personnel stop any activity in progress that could impact the plant or cause any unnoticed alarm. (Repeat).

3.2.3 Utilize Plant Computer alarm and display screens.

3.2.4 Increase control board walk downs and plant tours.

3.2.5 11 necessary, dedicate individuals to monitor remote alarm panels.

3.2.6 Increase monitoring of parameters associated with known plant problem areas. (i.e., Degraded RCP Seal) 3.2.7 Initiate priority one Job Order for corrective maintenance.

3.2.8 11 necessary, call out additional manpower for additional monitoring.

3.2.9 Contact System Engineering for technical support as the situation warrants.

3.2.10 Refer to Attachment A for electrical supplies to various t components inputing to Control Room annunciators.

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ADMINISTRATIVE SECTION TEST 02 RO

• ADMINISTRATIVE OUESTION ,

Page 10 of 12 EXAMINEES COPY Operating Test 1 (Open Reference) i

,, QUESTION A4-1:

How can you as an operator in the Control Room know when an annunciator panel has lost AC or DC power?

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i ADMINISTRATIVE SECTION TEST #2 RO I ADMINISTRATIVE OUESTION I Page 11 of12 l Operating Test 2 RO Subject A4 (Closed Reference) j QUEST 10N A4-2:

Reference:

KAA 2.4.39 3.3/3.1 j

! During a trip of the "A" MFW pump from 100% power, RCS pressure reached a maximum of 2400 psig. All immediate actions for a reactor trip have been perforrred with normal post trip response. During walk down of the control room panels you discover that only RPS Channel B indicates tripped on RIS K1633 on Cl3.

Checking the RPS cabinets you discover the Trip Modules in RPS channels A, C, and D are not tripped. Is this significant? Why?

! ANSWER:

It is sigmficant in that RPS channels A, C, and D failed to trip on a valid trip signal. (RCSpmssure >2355 psig)

This constitutes a failure of RPS to complete an automatic trip but a manual trip was a-eful. This is Alert l

criteria per Emergency Action level Classification (1903.010) Rev 34 PC 1 Attachment 3, EAL 6.2.

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REFERENCE:

Emergency Action Imel Classification (1903.010) Rev 34 PC 1 Attachment 3, EAL 6.2. page 12 and 43.

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PR0C.lWORF. 7 TAN NO. PROCEDURE / WORK PLAN TITLE: PAGE: 12 Cf 124 1903.010 EMERGENCY ACTION LEVEL CLASSIFICATION REV: 34 l CHANGE:

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l l ATTACHMENT 1 UNIT 1  !

INDEX OF EALS "0. SAFETY SYSTEM FUNCTION 6.1 Deviation from T.S. action statements when required to shutdown or l cooldown or deviations pursuant to 10CFR50.54(x)...................NUE l 6.2 RPS Failure to Complete an Automatic Trip.......................... ALERT 6.3 RPS Failure to Complete a Manual Trip..............................SAE 6.4 Loss of Dose Assessment Capabilities...............................NUE .

[ 6.5 Lo s s o f Communi ca ti ons . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . NU E '

6.6 Los s o f Control Room Annunciators . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ALERT 6.7 Loss of Control Room Annunciators with Transient in Progress.......SAE 6.8 Control Room Evacuation............................................ ALERT 6.9 Control Room Evacuation and control of shutdown systems not established in 15 minutes..........................................SAE 6.10 -Loss of Decay Heat Removal. Systems................................. ALERT 6.11 Degraded Hot' Shutdown Capability...................................SAE

.0 HAZARDS TO STATION OPERATION 7.1 Security Threat or Attempted Entry or Attempted Sabotage...........NUE 7.2 Ongoing Security Threat within Protected Area Security Fence....... ALERT 7.3 Ongoing Security Threat Within Plant Building......................SAE 7.4 Ongoing Security Threat Within CR or Vit-al Area. . . . . . . . . . . . . . . . . . . .GE 7.5 Fi re o r Expl o s ion Ons i t e . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . NU E 7.6 Fire or Explosion Onsite Affecting One Train of ANY ES Systems..... ALERT 7.7 Fire or Explosion Onsite Af fecting Both Trains oTXNY ES Systems. . .SAE 7.8 Aircraft Crash, Unusual Aircraft Activity, Train Derailment, Turbine Failure, Toxic or Flammable Gas Release....................NUE 7.9 Aircraft Crash, Missiles, Toxic or Flammable Gas Affecting One T r ain o f ANY ES S ys t ems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ALERT 7.10 Aircraft Crash, Missiles, Toxic or Flammable Gas Affecting Both T r a i n s o f ANY ES S ys t ems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . S AE

.0 NATURAL EVENTS 9.1 Tornado, Flood, Loss of Dardanelle Reservoir, Earthquake...........NUE 8.2 Tornado, High Winds, Flood, Loss of Dardanelle Reservoir, l_ Earthquake......................................................... ALERT i 8.3 Tornado, High Winds, Flood, Loss of Dardanelle Reservoir,

-Earthquake.........................................................SAE

.0 MISCELLANEOUS EVENTS I

9.1 Plant Conditions Exist Which Require an Increased Awareness by l Operations Staff and State and/or Local Authorities................NUE f 9.2 Plant Conditions Exist that Warrant Activation of the TSC.......... ALERT 9.3 Plant Conditions Exist that Warrant Activation of the Emergency Response Facilities................................................SAE 9.4 Plant Conditions Exist That Make Release of Large Amount of Ra di o a ctivi t y P o s s i bl e . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . GE e

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, PROO.tWORK PLAN NO. PROCEDURE / WORK PLAN TITLE: PAGE: 43 Cf 124 1903.010 EMERGENCY ACTION LEVEL CLASalFICATION REV: 34 CHANGE:

ATTACHMENT 3 UNIT 1 SAFETY SYSTEM FUNCTION

. . , 6.2 ,

CONDITION:

! Rtactor Protection System Failure to complete an Automatic Trip I

' MERGENCY CLASSIFICATION:

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! '.lert MODES Hot Stdy-Pwr Ops

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iRITERIA:

1. A valid RPS trip setpoint is exceeded on ANY TWO RPS channels and the RPS fails to initiate and complete an automatic trip that brings the reactor suberitical.

AND Subsequent efforts to manually trip the Reactor from the Control Room and

!. bring it suberitical are successful.

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AELATED EALS: TAB ir'.73 Failure to Complete a Manual Trip 6 gCore Melt 1 jCore Damage Indicated with an ICC Condition 1 Loss of or Challenge to 3 Fission Product Barriers 1 i

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l l ADMINISTRATIVE SECTION TEST #2 RO ADMINISTRATIVE OUESTION l Page I2 of12 l l EXAMINEES COPY l Operating Test 1 (Closed Reference)

QUESTION A4 2:

During a trip of the "A" MFW pump from 100% power, RCS pressure reached a maximum of 2400 psig. All immediate actions for a reactor trip have been perfonned with normal post trip response. During u2ik down of the control room panels you discover that only RPS Channel B indicates tripped on RIS K1633 on C13.

Checking the RPS cabinets you discover the Trip Modules in RPS channels A. C, and D are not tripped. Is this significant? Why?

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l ADMINISTRATIVE SECTION TEST #2 RO ADMINISTRATIVE JPM i Page 1 of 2 Operating Test 2 RO Al (JPM-1) l-i

Reference:

KAA 2.1.3 3.0/3.4 Initiating cue:

You are the on coming CBO Reactor. You are ready to review the Plant / Safety System Status Board Using the facsimile provi 'ew the information.

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Reference:

Conduct of Operations (1015.001) Rev 50 PC 3 page 37.

Conduct of Operations (1015.001) Rev 50 PC 3 page 40.

l Unit 1 Operations Forms (1015.015) ShiA Relief Sheet - 200*F (1015.015A) page 4.

Unit One Technical Specifications 3.7.2C Standard:

1. Review the pmvided Plant / Safety System Status Board facsimile for completeness.

2. Determine that the #2 EDG is out of service for maintenance and no LCO is listed as required by procedure. (7 day time clock per LCO 3.7.2C)

COMMENTS 1

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BORON PPM Date Time SAFETY SYSTEM STATUS PLANT SYSTEM STATUS RCS 1314 TRAIN "A* TRAIN *B" RCS, RCP's, PZR MS/Rit1DCT Steam PZR ' 13M HPI HPI BAAT 12808 F BWST 2437 MAP "A" CFT 2749 )

"B' CFT 2749 LPI' & CF LPI & CF SFP 2453 COND & FW .

RCS LEAKRATE ACW/ICW L Umdebfied 3 Day AVG Time Deee t 4.07 0.68 G G * '

ans ans KNOWN LEAKAGE SW GW COMPRESSED AIRSYSTEMS FIRE SUPPRESION Quench Tank fib Race 0.012 gym RB Sump fill rose 00.105spm REDUCED INVENTORY RB Cooling & Isol. RB Cooling & Isol CIRC WIR, SCRN WASH, WBV .

n wn nw um I ses aus amuse ons She hugueur rage husW ragst EFW EFW 1 URB GEN & AUX '

RADWASTE/SF oue=* Ao rae=r I WCO rueur

• I ras u resar

• FIRE BRIGADE Electncal Electrical U-l lander ICS/NNI ,

Member VENT, GEN, AC

. U-2 Leader i Member Train "A" LCO's Train 'B" ILO's Memeber #2 EDO 005 due to oilleek. ESF 7/17/98 @ >

Member l Emergency Response r368 A3 ^4 NOTES  !

F4B A3 A4 BSS/BS6 BS B6 C Actl3P! CEEditions Will be lifted 88 appfDptile at time Of ewsminmeinn_

@This date and time will be adjustal based on date administerect j k

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PROCAWORK PUW NO. PROCEDURPJWORK PLAN TITLE: PAGE: 37 of 55 CONDUCT OF OPERATIONS REV: 50 1915.001 CHANGE:

I 10.9 During shift turnover, the oncoming Control Room Operators should review the items listed on the Shift Relief Sheet (1015.015A or 1015.016A as applicable). After completing these reviews, the operators shall initial the following:

e Appropriate blanks signifying their understanding of the plant status ,

o Receipt of the keys 10.10 The oncoming Shift Superintendent shall review the Station Log for the preceding seven days or until he was last on shift, whichever is shorter.

10.11 Upon completion of the data transmittal to the satisfaction of the on-coming shift personnel, they will assume shift responsibilities.

e The completed Shift Relief Sheet should be placed in a loose leaf binder in the control Room and maintained in the binders for at least three days.

10.12 Upon assuming operational responsibility, Control Room Operators shall complete applicable Shift Turnover Checklists, Form 1015.015B or 1015.016B.

I e The Shift Turnover Checklist should be maintained in the Control l

' Room for at least three days.  !

10.13 Periodically, the following forms should be forwarded to Records Management for retention:

e Shift Relief Sheet - 200*F and Above (Unit 1) (Form 1015.015A)

• Shift Turnover Checklist - Above 280'T (Unit 1) (Form 1015.015B) l e Shift Turnover Checklist (Unit 2) Modes 1, 2, 3, & 4 )

i (form 1015.016B) 10.14 Upon assuming operational responsicility, the Waste Control Operator j and Auxiliary Operator shall make a tour of their assigned areas as soon as practical.

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PnocJuuonK PUWI800. AmWonK PLAN TmJh PAGE: 40 of 55 1915.001 CONDUCT OF OPERATIONS m: 50 CHANGE:

12.5 Status boards for Waste Control Operators and Auxiliary Operators may serve the function of a Shift Relief Sheet for these positions.

12.6 Status boards should have entries made whenever special operating consideration must be given a specific system or component related to the watch station.

12.7 Entries on Plant / Safety System Status Board should be brief, but contain all of the following:

• Component name/ number NOTE Exceeding LCO time clocks requires the initiation of a Condition Report which will address any actions necessary at end of time clock.

• Component status (isolated, bypassed, etc.) and associated LCO time

. clock ,1f, applicable

• Date and Time of occurrence e Initials of person making the entry 12.8 When a failed, bypassed, or misaligned component shown on a status board or listed in the Component Out of Position Log is restored to its normal condition, the status board entry shall be removed or the Component Out of Position Log entry shall.be updated.

13.0 ANNUNCIATOR MONITORING AND RESPONSE 13.1 When conditions result in actuation of the annunciator system, the alarm should be promptly investigated and corrective action taken to clear the alarm.

e When available, ralated instrument readouts and status lamps located on the control panels may be used to facilitate a quick check of the alarming condition e Some alarms require local investigation and subsequent corrective action 13.2 Conditions or alarms which repeatedly occur-or which cannot be cleared shall be brought.to the attention of the Shift Superintendent.

13.3 Lf,an f alarming condition is considered to be significant from the standpoint of plant safety or continued unit operation, it shall be logged in the respective unit's Station Log along with a description of the corrective action taken.

, Prge 4 of 50 Page 1 of 4  !

DATE SHIFT CREW (ON-COMING) (ON-COMING) (ON-COMING) l

1. The on-coming crew shall document review of the following items during shift '

turnover by initialing the appropriate spaces below. Review may be performed in any order. (N/A CRS Admin if watchstation not manned.)

CRS CBOT CBOR S/S SE CRS Admin Control Room Annunciators (All Alarms)

Hold Card Log Caution Card Log Temporary Alteration Log xCW3M;?.~;7=MMvmw;";W9*M~a;;puA ;r1*,2f:?r:Nawms5.:.%.V ?* m r : M m w :s w zx9n rk N c? x xn Plant Status Board Safety System Status Board Category "E" Valve Log .

Inoperable Equip / Tech Spec LCO Log sv.ww vwum4Mrsuur s nrMAn m+- +G;sst%Myp%W2T:1 2 :f M + WM?3 M TARM9lVF 4 W M Component Out of Position Log Operator Logs (for respective position) gg gg g Y"

S& l ll&

Station Log g g l ll g g g g ww :ww.mt:: em;;,,axxcomyukyas gru,11 ram m Iw m naggggnus Key Log and Key Cabinet Key g g g ,

l Weekly Surveillance Schedule gg 1 g g gyy Past Due Surveillance Basket *geg+y 9WighM*gg gg gj Daily Surveillance Checklist pgg gh*J4ggfg ggj ggg

2. All following items are to be filled out by the off-going shift, additional pages may be attached. M no items exist for a section, enter "None".

EVOLUTIONS IN PROGRESS (I_f, additional pages are used, enter "See Attached".)

FORM TITLE. FORM NO. REV.

SHIFT REUEF SHEET - 200*F AND ABOVE (UNIT 1) 1015.015A 24 l

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3.7.2 A. Tha specifications in 3.7.1 may be modified to allow ons of j the following conditions to exist after the reactor has been l heated above 200F. Except as indicated in the following i conditions, if any of these conditions are not met, a hot shutdown shall be initiated within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. If the condition is not cleared within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, the reactor shall be brought to cold shutdown within an additional 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

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B. In the event that one of the offsite power sources specified in 3.7.1.A (1 or 2) is inoperable, reactor operation may I

l continue for up to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> if the availability of the diesel I generators is immediately verified.

C. Either one of the two diesel generators may be inoperable for up to 7 days in any month provided that during such 7 days the operability of the remaining diesel generator is demonstrated immediately and daily thereafter, there are no inoperable ESF components associated with the operable diesel generator, and l provided that the two sources of off-site power specified in

3. 7.1. A (1) or 3.7.1.A(2) are available.

D. Any (160V, 480V, or 120V switchgear, load center, motor control center, or distribution panel in one of the two ESF distribution systems may be inoperable for up to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, provided that the operability of the diesel generator associated with the operable ESF distribution system is I

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demonstrated immediately and all of the components of the  !

operable distribution system are operable. If the ESF distribution system is not returned to service at the end of the 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period, Specification 3.7.2.A shall apply.

E. With no operable battery charger associated with one station

' battery, operation is allowed to continue for a period of 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> provided at least one battery charger is operable on the opposite train, after which Specification 3.7.2.A shall apply.

F. One of the two station batteries and the associated distribution system may be inoperable for 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> provided that there are no inoperable safety related components  !

associated with the remaining station battery which are f redundant to the inoperable station battery and the l

operability of the diesel generator is verified immediately.

If the battery is not returned to service at the end of the 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period, Specification 3.7.2.A shall apply.

G. Two control power sources from the plant to the switchyard and the attendant distribution system may be inoperable for 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, after which Specification 3.7.2.A shall apply, i H. If the requirements of Specification 3.7.1.G cannot be met, l- either:

(1) place all Startup Transformer No. 2 feeder breakers in

" pull-to-lock" within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, restore the inoperable interlocks to operable status within 30 days, or submit within 30 days a Special Report pursuant to specification 6.12.5 outlining the cause of the failure, proposed corrective action and schedule for implementations or (2) apply the action reqcirements of Table 3.5.1-1, Note 14.

l Amenoment *b. n,4M,H4.176 -57

ADMINISTRATIVE SECTION TEST #2 RO ADMINISTRATIVE JPM Page 2 of 2 Operating Test 2 RO A2 (JPM 2)

Reference:

KAA 2.2.13 3.6/3.8

. Initiatine cue:

Given the provided Hold Card Authorization Form you are directed to hang the Hold Card.

Reference:

Hold and Caution Card Control (1000.027) Rev 24 PC 2 page 40.

Standard.

Determine that the Hold Card Authorization Form has not been signed by an Operations Supervisor.

' COMMENTS:

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PAGE 40 56 l

HOLD CARD AUTHORIZATION FORM PAGE 1 OF 2 ENTERGY OPERATIONS INCORPORATED

. Arkansas Nuclear One Page 1 of 2

Title:

HOLD CARD AUTHORIZATION FORM l Form No. 1000.027A Revised 11/10/97 i

Date: UNIT 1: 1) UNIT 2: O BOTH: O HOLD CARD-SERIAL NUMBER: ,

I Affected System: Reason / Scope of Tagout:

Special Conditions Required / Remarks:

i PROCEDURE COMPONENT PREPARED VERIFIED ADEQ ISSUED . ACCEPTED AND pgggASgp gy OR WORK BEING BY BY VER TO - SPEC COND mp INIT EXTN REVIEWED BY DATE DATE ACTIVITY WORKED CRAFTSMAN NUMBER (PRINT) CRAFTSMAN (SIGNATURE)

(SIGNATURE) W TAGOUT AUTHORIZATION TAGOUT REMOVAL

• Verify all Released By signatures obtained.

• Designate removal position and sequence.

• If required, then verify 1000.027N complete.

• Is Restoration Verification required? Yes No If No, then N/A Verification blanks.

Operator Date APPROVED REMOVAL ~

TO INSTALL Operations Supervisor Date APPROVAL Operations Supervisor Date form title: form no. rev.

Hold Card Authorization Form 1000.027 A 24

. /

1 ENTERGY OPERATIONS INCORPORATED COPY COPY Arkansas Nuclear One

Title:

HOLD CARD AUTHORIZATION FORM Form No. 1000.027A Revised 11/10/97 Dato: 05/10/98 UNIT 1: X UNIT 2: BOTH: HOLD CARD SERIAL NUMBER: 98-1-0992 Affected System: C8 Reason / Scope of Tagout: REPAIR P2A PUMP / MOTOR.

Spacial Conditions Required / Remarks: POMP / MOTOR CATASTROPHICALLY FAILED, CP??T TAKE NEE DED PRECAUTIONS.

E306-1 ISSUED ACCEPTED AND RELEASED PROCEDURE TO BY LEAD OR WORK COMPONENT PREPARED VERIFIED ADEQ SPEC Coe REVIEWED CRAFTSMAN DATE BEING BY BY VER EXT / BY LEAD CRAFTSMAN DATE ACTIVITY INIT (SIGN TURE)

NUMBER WORKED (PRINT) (stomaiuRE) 00978414 P-2A DAVID BICE ((kY 00970416 P-2A DAVID BICE 00970419 P-2A DAVID BICE {V TAGOUT AUTHORIZATION TAGOUT REMOVAL l

- Verify all Released by Signatures obtained.

- Designate removal sequence and position.

- If required, verify 1000.027N complete.

- Is Restoration Verif: cation Required? [ ]Yes [ ]No ,

If NO, then N/A Ver:.fication tilanks.

Operator:

Da e APPRLVED REMOVAL a4 TO N (

IIT; TALL: APPROVAL:

Operations Supervisor Date b Op erNions Supervisor Date

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( R AO 1 TN

JOB PERPGs3NCE MEASURE l

Page 1 of 6

' UNIT 2,: X REV # 7 DATE:

d NUMBER: ANO-1-JPM-RO-AOP03 I l

l SYSTEM: Emergency and Abnormal Operations i TASK: RO2 alternate shutdown fellow-up actions immediate evacuation.

JTA 13035210401 KA VALUE RO: 4.3 SRO: 4.5 KA

REFERENCE:

A06 AA1.02 APPROVED FCR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR OUTSIDE CR: X BOTH:

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE): l PLANT SITE: Simulate SIMULATOR: LAB POSITION EVALUATED: RO: SRO:

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB TESTING METHOD: SIMULATE: PERFORM: 4 l

APPROXIMATE COMPLETION TIME IN MINUTES: 9 minutes D"*ERENCE(S): AOP 1203.002, Rev. 13 PC-4(Section 1D)

EXAMINEE'S NAME: SSN: - -

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EVALUATOR'S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN I THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

Start Time Stop Time Total Time

' SIGNED DATE:

r SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED l

INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

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JOB PERFORMANCE MEASURE Page 2 of 6 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

. . excminer shall review the " Briefing Checklist - System Walkthrough" portion of OP1064.023 Attachment 6 with the examinee.

JPM INITIAL TASK CONDITIONS: A fire in the control room threatens immediate drmaga to a major portion of vital controls. Therefore, there has been an immediate control room evacuation. AOP 1203.002 Section ID complete through Step 3.3.

TASK STANDARD: Steps 3.4 through 3.9 Reactor Operator #2 followup actions of AOP 1203.002, (Section ID) completed.

TASK PERFORMANCE AIDS: Copy of AOP 1203.002, Rev 13 (Section 1D) Reactor Operator #2 fallewup duties.

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JOB PERFORMANCE MEASURE Page 3 of 6 IntTIATING CUE:

'4 - . SS/CRS directs you to complete RO #2 followup duties through step 3.9.

CRITICAL ELEMENTS (C): 1, 6 (C) l PERFORMANCE CHECKLIST l STANDARDS l N/A l SAT l UNSAT TRANSITION NOTE: The examinee should transit to the Upper North Piping Penetration Room. i

1. Close the RCP Seal Closed RCP Seal Bleedoff Return ISOL Bleedoff Return ISOL (CV-1274) and the (CV-1274) and the 1 (C) Letdown Coolers outlet Letdown Coolers outlet I (CV-1221). (CV-1221) by engaging  !

the manual handwheel POSITIVE CUE: with the clutch lever CV-1274 and CV-1221 are and turning the closed. handwheel.

2. Verify EFW P-7A to SG- Verified EFW P-7A to A ISOL (CV-2627),open. SG-A ISOL open (CV-2627) by observing the POSITIVE CUE: valve stem of valve or CV-2627 is open. position indicator.

TRANSITION NOTE: The examinee should proceed to the EFW pump room.

3. In the EFW room, CV-2800 & 2002 verify P-7B & P-7A verified open by suctions (CV-2800 and observing valve stems CV-2802) open. UP on both valves.

POSITIVE CUE:

Valve stems UP.

TRANSITION NOTE: The examinee should transit to the Lower South Piping Penetration Room.

4. Verify P-7A to SG B Verified EFW P-7A to ISOL (CV-2620) open. SG-A ISOL open (CV-2627) by observing the POSITIVE CUE: valve stem of valve or CV-2627 is open, position indicator.

TRANSITION NOTE: The examinee should transit to the EFW Pump Room.

5. Verify P-7A test Verified CV-2870 recire isolation CV- closed by observing 2870 closed. valve stem in down position.

POSITIVE CUE:

Valve stem DOWN.

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JOB PERFORMANCE MEASURE i

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PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT l

6. Throttle P-7A Closed trip / throttle trip / throttle valve valve (CV-6601A) until (CV-6601A) until gov gov valve full open

(C) valve is full open and and discharge pressure P-7A discharge decreased slightly, pressure drops slightly.

I POSITIVE CUE:

Governor valve FULL OPEN.

Pump discharge (PI-2811A) pressure - 1400 psig.

7. Notify TSC of Used radio or completion of steps telephone and notified

'EFW 1.B, 1.C, 1. D, TSC of completion of 1.G. steps.

POSITIVE CUE:

TSC notified of completi'dn of steps.

NOTE:

Provide cueing as applicable '

for the steps which were missed.

. 1 NEGATIVE CUE:

(1) SS reports pressurizer level is decreasing.

(6) SS reports OTSG A/B level decreasing.

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l JOB PERFORMANCE MEASURE Page 5 of 6 !

061 A1.02 3.3/3.6

)

Qu3stion:

How is OTSG pressure controlled during an alternate  ;

. . shutdown? l

'Answ0rs Initially the OTSG pressure is controlled by the Main Steam Safety Valves. As additional operators become available ,

l manual control of the Atmospheric Dump Valves is l established. J Refsrence' Alternate Shutdown AOP (1203.002)Rev 13 PC4 Attachemnt 9 page 78.

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MIOCJWORK PLAN NO. mm4MORK M.AN TITLE: PAGE: 78 Of 84  ;

1203.002 ALTERNATE SN REV: 13~

CHANGE:

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l ATTACHMENT 9 '

Page 1 of 4 DISCUSSION CONTINUATION l

1.0 DESCRIPTION

1 Alternate Shutdown capability is being provided to comply with 10 CER 50, '

Appendix R, and to mitigate consequences of significant fire in either the I Control Room or the Cable Spread Room because fires in these areas can result I in loss of controls and instrumentation required for safe shutdown. Following are some of the more significant assumptions considered in development of this procedure:

NOTE This procedure will be used even if a coincident loss of off-site power has not occurred.

A. A co.:ncident loss of off-site electrical power has occurred.

B. No coin'cident design basis accident occurs, only accidents that are a direct result of the fire.

C. Control circuits (for valves, motors, etc.) located in the fire area are assumed to cause activation of the component to the least desirable condition unless preventative action is taken.

2.0 SYSTEMS The following are the safe shutdown system components utilized by the Alternate Shutdown procedure and a brief. description of how they are used.

2.1 Emergency Feedwater Local control of steam-driven EFW Pump-(P-7A) is established with the EFW Turb K3 Trip /THROT VLV (CV-6601A). EFW P-7A to SG-B ISOL (CV-2620) is manually controlled to control SG-B level. These actions are accomplished by RO #2.

RO #1 will manually control EFW P-7A to SG-A ISOL (CV-2627) to control l i

the SG-A level.

Steam release will be initially controlled by the mechanical steam relief valves and, as additional operators become available, by nanual control of the ADVs.

The EFW CST (T-41B) will provide the initial source of water to the EFW system with the CST (T-41) and service water, the backup sources, if necessary.

As time permits, the P-7B train of EFW will be nede available for backup purposes.

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JOB PERFORMANCE MEASURE I i

Page 6 of 6

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I i 061 K5.05 2.7/3.2 K&A Guastions l' If the EEW Pump (P7A) is found tripped, what discharge pressure is maintained after the pump is relatched?

An:wers l 1400# as indicated in local pressure indicator (PI-2811A). l l

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- Reference Alternate Shutdown AOP (1203.002) Rev 13 PC 4 Section 1D l page 25.

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PROCJWORK PLAN NO. W" WORK PLAN ELE: PAGE: 25 of 84 1203A02 ALTERNATE SHLfTDOWN REV: 13 CHANGE:.

SECTION 1D Page 2 of 2 REACTOR OPERATOR #2 FOLLOW-UP ACTIONS 3.6 In LSPPR, verify E N P-7A to SG-B ISOL (CV-2620) open.

3.7 Close of verify closed P-7A Test Recire Isolation (CV-2870).

NOTE EW pump P-7A discharge pressure may be read locally at PI-2811A.

3.8 Slowly throttle E N TURB K3 Trip / Throttle valve (CV-6601A) until EFW TURB K3 GOV Servo (CV-6601B) is full open and P-7A discharge pressure drops slightly.

3.8.1 g P-7A has tripped, close CV-6601A, relatch trip mechanism and slowly open CV-6601A until pump discharge pressure is -1400 psi 9 as read on PI-2811A.

3.9 Notify TSC (by radio or telephone Ext. 6601, 6602, 6603) of the following alignment completions from Attachment 1. For any alignment that could not be completed, refer to Attachment 1 to provide details of specific item number to TSC.

System Attachment 1 Item l l

EN 1.B 1.C i 1.D l 1.G 3.10 Throttle EW P-7A to SG-B ISOL (CV-2620) as directed by TSC.

3.11 Throttle CV-6601A as necessary to maintain pump discharge pressure at

-1400 psig as indicated on PI-2811A.

3.12 Open EW P-7B to SG-B ISOL (CV-2626).

3.13 In LSPPR, open RB Coolers VCC-2A & 2B PI-3812A ISOL (SW-3812A).

3.13.1 Verify service water header pressura >40 psig on RB SW CLR VCC 2A/B IN PRESS (PI-3812A).

3.14 Close g verify closed P-7B Test Recirc Isolation (CV-2869).

3.15 Notify TSC of the following alignment completions from Attachment 1.

! For any alignment that could not be completed, refer to Attachment 1 to provide details of specific item number to TSC.

System Attachment 1 Item l

! EFW 2.A

, 2.D SW 7.A l

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JOB PERFORMANCE MEASURE Page 1 of 7 UNIT 1: X REV #: 15 DATE:

TUOI NUMBER: ANO-1-JPM-RO-EDG10 SYSTEM: Abnormal / Emergency Operations TASK: EDG-2 No DC Start JTA: 106451104A4 KA VALUE RO: 4.0 SRO: 4.3 KA

REFERENCE:

064-000-A4.01 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X TASK LOCATION: INSIDE CR: OUTSIDE CR: X BOTH:

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE):

PLANT SITE: Simulate SIMULATOR: LAB:

POSITION EVALUATED: RO: . SRO:

ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:

TESTING METHOD: SIMULATE: PERFORM:

APPROXIMATE COMPLETION TIME IN MINUTES: 18 REFERENCE (S): OP 1104.036, Rev. 37 PC 2 EXAMINEE'S NAME: SSN: - -

EXAMINEE'S SIGNATURE: DATE:

EVALUATOR'S NAME:

THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

l Start Time Stop Time Total Time SIGNED DATE:

SIGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

I

JOB PERFORMANCE MEASURE Page 2 of 7 THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

.hs examiner shall review the " Briefing Checklist - System Walkthrough" portion of -

OP1064.023 Attachment 6 with the examinee.

JPM INITIAL TASK CONDITIONS: Station Blackout is in progress and a fault in tht EDG DC control circuit is preventing EDG auto start.

TASK STANDARD: EDG-2 running, Breaker A408 closed, control room notified diesel is ready for loading.

TASK PERFORMhMCE AIDS: OP 1104.36, Section 11 i

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JOB PERFORMANCE MEASURE Page 3 of 7 INITIATING CUE:

SOS /CRS directs you to perform a No DC Start of EDG-2 to the point of starting an HPI pump, then call the control room CRITICAL ELEMENTS (C): 2, 4, 5, 6, 7,10 ,11 ,12 Start Time PERFORMANCE CHECKLIST: STANDARDS N/A SAT UNSAT

1. Place engine local Rotated engine control control selector switch to MAINT.

switch in MAINT. position.

POSITIVE CUE:

Selected to MAINT.

(C) 2. Place breakers D2114A Opened cabinet for

& D2116A in open to voltage regulator prevent engine S/D (E21)/ local engine when DC power,iq control cabinets (C108 restored, and opened breaker POSITIVE CUE: D2116A and D2114A Breaker (s) in open or off position.

NEGATIVE CUE:

Breaker D2114A not open.

NOTE: Travel to the control room should be avoided to save time on an action of minimal training value. When this step is reached inform the trainee that the breakers are open.

3.- De-energize ES Digital Breakers RS1-4 and Channels by opening RS2-4 are opened.

RS1-4 and RS2-4.

POSITIVE CUE:

Breakers RS1-4 and RS2-4 open.

Transition Note: The examinee should travel to the A4 switchgear room. I (C) 4. Open designated Opened breakers A409, breakers on A4. A410, A402, A403, A404, A405, A406, and POSITIVE CUE: A407 by pushing manual Breakers open. push-button on each breaker.

NEGATIVE CUE:

Breakers do not indicate open.

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I l PERFORMANCE CHECKLIST l STANDARDS l N/A l SAT l UNSAT Transition Note: The examinee should proceed from the A-4 switchgear room to DG2.

l (C) 5. Override Governor Pointed out red knob, run solenoid. locking pin, and l l

described installation i i POSITIVE CUE: method (lift knob, j Governor run solenoid is depress locking pin, overridden. lower knob while ,

insuring locking pin l

, remains "in"). '

6.

(C) Open SW cooling Opened SW cooling inlet valve. inlet CV3807 using the I manual handwheel.  !

POSITIVE CUE: I CV-3007 is open

( C ) 7. Start diesel by Located air start manually opening air solenoid on side of l start solenoid valve. diesel and depressed  !

override plunger until POSITIVE CUE: engine started.

Engine is running NEGATIVE CUE:

Engine turns over but will not start

8. Verify speed at Moved to C108 and approx.'900 rpm /60 Hz. observed tachometer at approx. 900 rpm. Hoved POSITIVE CUE: to voltage regulator Engine at 900 rpm /60 HZ. panel (Ell) and NEGATIVE CUE: verified 60 HZ.

Engine not at 900 rpm or not at 60 HZ.

9. Verify output voltage At voltage regulator is normal. panel (Ell), checked output voltage 3800-POSITIVE CUE: 4500 volts.

Voltage is 4160.

NEGATIVE CUE:

Voltage is 0 or outside required range.

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1 JOB PEPSORMANCE MEASURE Page 5 of 7 l PERFORIENCE CHECKLIST: l STANDARDS l N/A l SAT l UNSAT' Trrnsition Note: The examinee should proceed from DG2 to the A-4 switchgear room.

NOTE: Upon completion of next step (Step 10) inform trainee that auto loading of EDG-2 and cuto start of EDG-1 did NOT occur.

(C) 10. Move to A4 and At A4 switchgear, close A408. manually closed A408 by opening cabinet door and POSITIVE CUE: pushing manual close on A308 indicates closed, breaker.

Automatic loading of EDG did NOT occur.

NEGATIVE CUE:

A408 did not close, automatic loading of EDG did not occur. i (C) 11. Start SW pump for Moved to breaker cabinet, EDG-2. opened door and closed A402 by pushing manual POSITIVE CUE: close push-button.

Breaker closed.

NEGATIVE CUE:

Breaker indicates open.

(C) 12. Call CR and Called CRS on radio or reports EDG-2 phone to inform diesel ready for ready for loading.

loading.

Stop Time l

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{ . JOB PERFORMANCE MEASURE l

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Page 6 of 7 K&A 064 K1.04 3.6/3.9 Question: With DC control power off what safety devices are functional l l on the EDG7 l

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Answer: The mechanical over speed is the only functional protective device.

l - Rzference - Emergency Diesel Generator Operation (1104.036) Rev 37 PC 3 l

page 21.

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PROCJWORK PLAN NO. PROCEDURE / WORK PLAN TTTLE: PAGE: 21 cf 160 1104.036 EMERGENCY DIESEL GENERATOR OPERATION REV: 37 CHANGE:

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l CAUTION With loss of control power, the only functional DG protection is the mechanical overspeed device.

l 11.8 Start diesel generator by overriding one of the starter solenoid valves with the override plunger. Release solenoid when engine starts.

11.8.1 M DG does not start after ~5 seconds, repeat step 11.6.

11.8.2 g it becomes necessary to shut down the diesel:

A. Pull the EMERGENCY FUEL CUTOFF (FO-66A for DG1, FO-66B for DG2) valve handle, EE B. Release the governor solenoid by lifting the knurled knob, thus releasing the locking pin, and push the knurled knob down and ensure fuel rack lever returns to the shutdown position (black pointer moves to <1 on governor).

11.9 Verify governor maintains engine speed at ~900 RPM speed and ~60 Hz.

If necessary, adjust engine speed by turning speed setting knob on governor.

NOTE Loss of DC power to field flashing circuit will cause loss of automatic voltage regulator setpoint adjustment (loss of power to motor-operated rheostat). Automatic voltage regulation should still function.

11.10 Verify diesel generator output voltage is normal.

11.10.1 M voltage falls outside 3800-4500 volts, place Excitation control selector switch (on Ell for DG1, E21 for DG2) in MANUAL and adjust the manual voltage adjust dial as necessary.

7 CAUTION The next step will cause automatic loading of the diesel if 125V DC is restored through a battery charger. Be prepared to manually adjust the diesel voltage and frequency each time a load is started.

11.11 Manually close output breaker for diesel that was started (A-308 for DG1, A-408 for DG2).

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1 JOB PERFORMANCE MEASURE Page 7 of 7 l

1

..&A 064 K4.05 2.8/3.2 l

' Qutstion: If an EDG' fails to start, what is the time length from the~

time the start signal occurs until the EDG start sequence is terminated.- ))

l Answer 45 seconds. ]

l R3ference Annunciator Corrective Action (1203.012A) Rev 32 page 15.

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l MtOCJWORK PUW NO. AN PUhN TITLE: PAGE: 15 of 184 1203.012A ANNUNCIATOR K01 CORRECTWE ACTION REV: 32 CHANGE:

Location: C10 Device and Setpoint: EDG 1 OVERCRANK Alarm: K01-B2 1.0 OPERATOR ACTIONS  ;

l

1. Place DG1 lockout switch in LOCKOUT position. i

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2. Refer to Tech Spec section 3.7 for operability requirements. I

3. Initiate action to determine cause of over-crank.

4. Operate fuel oil priming pump and verify " return fuel" sight glass is full.

5. When cause of over-crank is corrected, prove DG1 operable using Emergency Diesel Generator Operation (1104.036), supplement 1.

6. Alarm may be cleared by any of the following methods:

• Place DG1 lockout switch in LOCKOUT position

• Depress local RESET button e Place Local /Maint/ Remote switch in MAINT

• Place DG1 0.stput (A-308) in PULL-TO-LOCK 2.0 PROBABLE CAUSES

1. DG1 did not reach minimum speed within 45 seconds

2. Loss of fuel oil pump prime

3.0 REFERENCES

1. Tech Spec 3.7

2. Schematic Diagram Annunciator K01 (E-451)

3. Schematic Diagram Diesel Generator Engine control (E-102)

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i JOB PERFORMANCE MEASURE '

f Page 1 of 6 i UNIT 1: X REV #: 0 DATE:

• I TUOI NUMBER: ANO-1-JPM-RO-AOP26  !

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SYSTEM: Emergency and Abnormal Operatons  !

TASK: Respond to loss of loadcenter B6 l.

JTA 106263904A4 ,.

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KA VALUE RO: . 3.4 SRO:. 3.9 KA

REFERENCE:

062 A2.01 l

APPROVED FOR ADMINISTRATION TO: RO: X SRO: X

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TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:  !

i SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFORM OR SIMULATE): )

PLANT SITE: SIMULATOR: PERFORM LAB:

POSITION EVALUATED:. RO: . SRO: i ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB: I TESTING METHOD: SIMULATE: _

PERFORM:

APPROXIMATE COMPLETION TIME IN MINUTES: 15 minutes t REFERENCE (S): AOP 1203.046, Rev. 1 PC3 I

i EXAMINEE'S NAME: SSN: - -

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1 EVALUATOR'S NAME: l J

s THE EXAMINEE'S PERFORMANCE WAS EVALUATED AGAINST THE STANDARDS CONTAINED IN I THIS JPM AND IS DETERMINED TO BE ,

J SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

I Start. Time Stop Time Total Time

' SIGNED DATE:

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. SICNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A QUALIFIED INDIVIDUAL (NOT THE EXAMINEE) . AND IS CURRENT WITH THAT REVISION. l i

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l JOB PERFORMANCE MEASURE i Page 2 of 6 ,

! THE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE: '

,.1... sximiner shall review the " Briefing Checklist - System Walkthrough" portion of f OP1064.023 Attachment 6 with the examinee.  !

JPM INITIAL TASK CONDITIONS: A breaker fault has resulted in the loss of loadcenter B6. -

, Unit is at 100% power. P-36B is the operating makeup pump.

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I l TASK STANDARD: AOP 1203.046, steps 3.6.1 through 3.6.7 completed.

i j TASK PERFORMANCE AIDS: Copy of AOP 1203.046, Rev 1, section 3.6 i

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JOB PERFORMANCE MEASURE I

Page 3 of 6 l

7*fITIATING CUE:

l l ...e SS directs you respond to loss of loadcenter 86 in the control room.

I l CRITICAL ELEMENTS (C): 2, 3, 4, 5, 6 l

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! (C) PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT l 1. Verify MCC BS5 and B56 On panel C09, I are selected to the  !

l energized bus.

POSITIVE CUE:

NEGATIVE CUE:

2. Isolate Letdown. On panel C09, closed valves CV-1214 and CV-L (C) POSITIVE CUE: . .. 1216.

CV-1214 and CV-1216 indicate GREEN.

NEGATIVE CUE:

CV-1214 and CV-1216 indicate RED.

3. Stop the Makeup pump. At C16, stopped P-36B. 1 i

POSITIVE CUE: I W) P-36B indicates GREEN. I

4. Close RCP Seal At C09, placed Injection Block valve. handswitch for CV-1206  !

to close.

l (C) POSITIVE CUE: l 1

CV-1206 indicates GREEN.

NEGATIVE CUE:

CV-1206 indicates RED.

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i I JOB PERFORMANCE MEASURE Page 4 of 6 I

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!, PERFORMANCE CHECKLIST STANDARDS N/A SAT UNSAT

5. Open T-G L.O. Coolers On panel C09, took CV-Temp cont valve. 4026 handswitch in (C)

MANUAL and opened. j l POSITIVE CUE: <

CV-4026 indicates RED. l l 6. Open T-G H2 Temp Cont on panel CO2, took CV-l valve. 4018 handswitch in (C) MANUAL and opened.

POSITIVE CUE:

( CV-4018 indicates RED.

7. Verify DG2 starts. On panel CO2, checked DG2 running (rpm)?.

POSITIVE CUE:

DG2 running.

! 8. Verify A2 feed to A4 On panel C04, checked is tripped. A-409 indicates GREEN.

POSITIVE CUE:

A-409 indicates GREEN.

9. Verify DG2 output on panel C04, checked breaker closes. A-409 indicates RED POSITIVE CUE:

A-408 indicates RED.

10. Verify SW pump on A4 On panel C04, checked i restarts. P-4B(C) indicates RED l POSITIVE CUE:

P-4B(C) on A4 indicates RED.

11. Verify feeder breaker on panel C04, checked to B6 closed. A-401 indicates RED.

i POSITIVE CUE: 1 A-401 indicates RED. I

11. Verify feeder breaker On panel C04, checked to B6 closed. B-612 indicates RED. '

POSITIVE CUE:

B-612 indicates RED.

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i JOB' PERFORMANCE MEASURE i Page 5 of 6 KAA 004 K3.02 3.7/4.1 I I

Question: Why is letdown isolated in this event? j Answer: . Loss of YO2 causes the Letdown Demin Inlet valves to fail closed. This will cause the Letdown Relief valve to lift and fill up the ABEDT ' (T-11) .

l Reference 1203.046 Rev. 1 PC 3 page 11  ;

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PROCJWORK PLAN NO. PROCEDURFJWORK PLAN TmE: PAGE: 11 Of 14 LOSS OF LOADCENTER REV: 1 1203c046 CHANGE:

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3.6 Loss of Loadeenter B6 3.6.1 Verify MCC B55 and B56 are selected to the energized bus.

NOTE Loss of YO2 causes Makeup Filter Inlet and Purification Demineralizer Inlet i valves to fail closed resulting in lifting Letdown Relief valve discharging to Aux Bldg Equipment Drain Tank (T-11).

3.6.2 Isolate Letdown by closing Letdown Cooler Outlets (CV-1214 and CV-1216).

NOTE

1. If the operating Makeup Pump is on bus A4, the Aux Lube oil pump will not .

start due to loss of power. In this case the Makeup Pump should be l tripped without starting the Aux Lube Oil pump.

2. With loss of YO2, RCP Seal Injection Block (CV-1206) will not autoclose on low flow.

3.6.3 Stop the Makeup Pump if running.

3.6.4 Close RCP Seal Injection Block (CV-1206).

NOTE Loss of YO2 causes T-G L.O. Coolers E-15A&B Temp Cont Viv CV-4026 and T-G H Temp control valve CV-4018 to close if in AUTO due to loss of temperature input.

3.6.5 Place T-G L.O. Coolers E-15A&B Temp Cont Viv CV-4026 in MANUAL and open.

3.6.6 Place T-G H Temp Control Valve CV-4018 in MANUAL and open.

1 3.6.7 Verify the follcwing:

A. DG2 starts.

B. A2 Feed to A4 (A-409) is tripped.

l C. DG2 Output (A-408) closes to re-energize bus A4.

D. Operating Service Water Pump on bus A4 restarts.

E. A4 Feed to B6 (A-401) is closed.

F. A4 Feed to B6 (B-612) is closed.

3.6.8 If A-401 or B-612 cannot be closed, and it is determined the fault is not on bus B6, consider powering bus B6 from B5 per " Bus B5 to B6 Crosstie to Energize Dead Bus" section

of ES Electrical System Operation (1107.002).

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l JOB PERFORMANCE MEASURE l-Page 6 of 6 I

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! ha.A 004 K4.03 2.8/2.9 Questi:n: What is the maximum dcmineralizer inlet temperature allowed?

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! Answer: 135'F Reference . Makeup and Purification System Operation (1104.002) Rev 50 PC 3 page 10 ,

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PROCJWORK PUW NO. PROCEDURENWORK PLAN TITLE: PAGE: 10 of 230 l REV: 50 1104.002 MAKEUP & PURIFICATION SYSTEM OPERATION CHANGE:

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5.6 Maximum flow through a Letdown cooler (E-29A & B) is 87.5 gpm per cooler.

5.7 Allowing flow through a primary Makeup Filter (F-3A or F-3B) in excess i of 80 gpm can lead to filter damage.

l 5.8 Allowing flow through a purification DI in excess of 123 gpm can compact the resin and restrict letdown flow.

5.9 Restricting flow through a Purification Demineralizer (T-36A or T-368) to <25 gpm can cause channeling of resin and reduce efficiency of demineralizer.

5.10 Maximum purification demineralizer inlet temperature is 135'F.

5.11 Placing a purification demineralizer in service that has not been i borated will result in a reduction in RCS boren concentration. l 5.12 Ensure clean ,wapte system is aligned to receive waste from letdown-system prior to positioning Letdown 3-Way Valve (CV-1248) to BLEED.

Otherwise letdown line will over-pressurize.

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, 5.13 When makeup pumps are subject to HPI actuation, maintain MU tank l l

pressure / level relationship within limit of Exhibit A. Exceeding the I limit reduces the time available for isolating the MU tank after FPI l actuation. l 1

l 5.14 When venting the makeup tank, the waste gas system shall be aligned to l 1

compress the gas for storage unless samples indicate negligible activity in the makeup tank.

.5.15 MU Tank T-4 Relief Valve (PSV-1249) is not designed to relieve water.

For uncontrollable high MU tank water level, open MUT Vent Valve (CV-1257).

5.16 Some operation and valve lineups will require exposure to possibly  !

high radiation levels. These should be conducted rapidly and accurately to ndnindze exposure.

l 5.17 Neither Makeup /HPI Pump P-36B MOD to Bus A3 nor MOD to Bus A4 should be operated under load. Verify both breakers (A-307 and A-407) for P-36B open before operating MOD'S.

5.18 The following limits and precautions apply to the high pressure

. auxiliary spray system.

, 5.18.1 The use of high pressure auxiliary spray can cause severe l l

thermal stresses in piping and components. Use high pressure auxiliary spray only when directed by Emergency Operating Procedure or Natural Circulation Cooldown (1203.013).

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JOB PERFORMANCE MEASURE UNIT: 1 REV # 1 DATE:

TUOI NUMBER: ANO-1-JPM-RO-RPS01 SYSTEM / DUTY AREA: REACTOR PROTECTION SYSTEM TASF PLACE A CHANNEL OF RPS IN MANUAL BYPASS JTA#: 10125020101 KA VALUE RO: 3.6 SRO: 3.6 KA

REFERENCE:

012 000 A4.03 1 APPROVED FOR ADMINISTRATION TO: RO: X SRO: X l

TASK LOCATION: INSIDE CR: X OUTSIDE CR: BOTH:

SUGGESTED TESTING ENVIRONMENT AND METHOD (PERFOFM OR SIMULATE) :

PLANT SITE: SIMULATOR: PERFORM LAB:

POSITION EVALUATED: RO: SRO:

1 ACTUAL TESTING ENVIRONMENT: SIMULATOR: PLANT SITE: LAB:

TESTING METHOD: SIMUIATE: PERFORM:

! PROXIMATE COMPLETION TIME IN MINUTES: 5 MINUTES REFERENCE (S): 1105.001 REV. 16 PC 1 EXAMINEE'S NAME: SSN - -

DIALUATOR'S NAME:

THE EXAMINEE'S PERFOPNANCE WAS EVALUATED AGAINST THE STANDAP.DS CONTAINED IN THIS JPM AND IS DETERMINED TO BE:

SATISFACTORY: UNSATISFACTORY:

PERFORMANCE CHECKLIST COMMENTS:

l Start Time Stop Time Total Time 9IGNED DATE:

lGNATURE INDICATES THIS JPM HAS BEEN COMPARED TO ITS APPLICABLE PROCEDURE BY A adALIFIED INDIVIDUAL (NOT THE EXAMINEE) AND IS CURRENT WITH THAT REVISION.

Page 2 of 6

( TUOI NUMBER: ANO-1-JPM-RO-RPS01 dE EXAMINER SHALL REVIEW THE FOLLOWING WITH THE EXAMINEE:

The Examiner shal review the." Briefing Checklist - System Walkthrough" portion of OP 1064.023 Attachment 6 with the examinee.

l I~ JPM INITIAL TAKS CONDITIONS: