ML070190148
| ML070190148 | |
| Person / Time | |
|---|---|
| Site: | Salem  |
| Issue date: | 11/24/2006 |
| From: | Kafantaris M Public Service Enterprise Group |
| To: | D'Antonio J Operations Branch I |
| Sykes, Marvin D. | |
| References | |
| 50-272/06-301, 50-311/06-301 50-272/06-301, 50-311/06-301 | |
| Download: ML070190148 (124) | |
Text
U S . Nuclear Regulatory Cornrnisjs-ion /
Site-SpecifE c /
Written Examination
- I - __
l a t e : 12/18/2006 i Facility: Salem 1 & 2 I
k e n s e Level: RO Start Time:
J s e the answer s h e e t s provided to document your answers. Staple this cover s h e e t I n top of the answer sheets. T h e passing grade requires a final grade of a t least 30.00 percent. Examination papers will b e collected EIGHT hours after t h e examinatior Applicant's Signature ixamination Value Points
,p plican t's S c o r e Points
,pplicant's G r a d e , Percent
1 Friday, December 15,2006 11:29:38AM I
- The crew has diagnosed a Pressurizer (PZR) Vapor Space Accident.
The following is the procedural flowpath followed:
-EOP-LOCA-1, LOSS OF REACTOR COOLANT
-EOP-LOCA-2, POST LOCA COOLDOWN AND - DEPRESSURIZATION - - .
- 1 minutes after the rea I Friday, December 15,2006 11
- 29:38 1 I ~age2of91 1
- Unit 2 is operating at 100% power. .
- RCS Tavg is 573 degrees.
- The unit experiences a SBLOCA.
- RCS Dressure has dropped from NOP to 1825 psig.
I- Using trended data, thehighest CET has dropped from 614 degrees to 560 ctagrees.
- Salem Unit 2 is operating-at 100% power.
- 22 RHR pp is C/T.
- A catastrophic failure of RCS loop 21 cold leg piping occurs.
- RCS pressure is 35 psig.
- Initial RWST level was 41.I feet.
Given the RWST tank m S2.OP-TM.ZZ-0002 TANK CAPACITY DATA, including: (Licensed Operator & STA only)
The Control Room location of Emergency Core Cooling System control bezels and indications.
The function of each Emergency Core Cooling System Control Room control and indication.
i The effect each Emergency Core Cooling System control has upon Containment Spray System components and operation.
1I The
. . plant conditions or permissives required for Emergency Core Cooling System Control Room controls to perfom their
, z __'.__
- Unit 2 is operating at
- All 22 loop RC flows are 85% and dropping.
- The red START bezel for 22 RCP is illuminated. __ _- I -
ed for Reactor Coolant Pump Control Room controls to perform their intended 1 Friday, December 15,2006 11:29:38 1 I Page5of91 ]
- Unit 2 is operating at 40% steady state power.
- 23 CVCS Pp I/S
- 21,23 CC PPSI/S
- 21,24 SW PPSI/S
- 22 SW Pp in AUTO
/Containmentconditions 5. Radioactivity release control. 1 1-' \ cl VCT Isolation Valves, CV40 and CV41 Letdown Isolation Valves, CV2 and CV277 Letdown Orifice Isolation Valves, CV3, CV4 and CV5
Which of the following describes the situation in which the GREATEST amount o added during the first 5 minutes of boration while performing a Rapid Boration IA 0008, RAPID BORATIO than the BAST'S,which is the source of the other 3 methods. Using the REM figures, the differential boron worth is -6.325, -6.725, and -6.9 pcm/ppm respectiveley for a,b, and c. C is correct because it has Pressurizer Levei Control system RCS Temperature Control Main Turbine/Generator Reactor Coolant Pump seal injection flows Automatic Control Rod Control VCT Makeup Nuclear Instrumentation Emergency Core Cooling System Residual Heat Removal System Component Cooling Water System Pressurizer Pressure Control System Pressurizer including Pressure Relief Tank Waste Gas Waste Liquid Service Water 4 Kv Vital AC System 480 V Vital AC System 240 V Vital AC System 175 VDC Svsttnm I Friday, December 15,2006 11:29:38AM 1 V f 9 1 I
ldurina gubseauent cooldown and depressurization.
12.4, incorrect because ANY ECCS pump would include the RHR _ _ _ _It.the..KHK
. . pumps. .
pressure is less than 300 psig and the LOCA is Large, and the KLI-' trip criteria 1 Friday, December 15,200611:29:38 AM 1 I Page8of91 I
I-- Unit 2 is operating at 100%.
Reactor Trip Breaker "A" and Reactor Trip Bypass Breaker "B" are racked in and shut.
- Reactor Trip Breaker "B"is open.
- A feedwater problem has developed, and the CRS directs the RO to trip the reactor.
- The RO depresses the N pushbuttons for the Rx Trip Breakers, but the Rx does NOT trip.
Assuming no automatic trip demand has been generated, and the RO has NOT attempted a trip by lany other means, which of the following conditions prevented the Rx from tripping?
I I I
ldentifv and describe the Control Room contr includhg: (Licensed Operator and STA Only) a) The Control Room location of Rea_ctSr_Protgc$onSystem control bezels and indications b) The function of each Reactor Protection System Control Room control and indication c) The effect each Reactor Protection System control has upon Reactor Protection System components and operation d) The plant conditions or permissives required for Reactor Protection System Control Room controls to perform their intended function
- Unit 2 was tripped from power 20 minutes ago.
- 2N35 indicates 2.OE-9 amps.
- 2N36 indicates 5.OE-11 amps.
Which of the following choi dentifies the condition. present, and any action(s) performed as a result of this condition?
times -1/3 dpm'= 6.6 decades. 100% power is 5E-5amps, so in 20 minutes power should have dropped at least to 5E-11 amps. With the N35 channel reading 2E-9it is over 2 decades above where it should be. This points to under compensation as the problem, since more of the gamma pulses are being seen the detector which are not "screened out." Distracter B is incorrect because if the N36 were N35 wouldread normally. Distracters C and D are instrumentationSystem including the following:
Source Range High Flux Reactor Trip Intermediate Range High Flux Reactor Trip Power Ranae (Low) Hiah Flux Reactor Trip I I I I Fridav ner.mher 15 7 n n ~I1.79.38 AM ' I Page 10of91 1
- Unit 1 is performing a Rx startup.
- With Rx power at 1E-5 amps, IN35 fails low.
(Whichof the following, if any, is the Power Range NI reading which will confirm Rx power is lactually at 1E-5 amps? _.
Amps (IOP-3 PAGE 27). Also AV-1026R drawing shows PR overlap at 5E-6. Since power in stem IS
/givenas 1E-5 amps, the only answer is 20%. 1% would be 6E-6. 100% would be 5E-4. Power is 1 The effect each E I
I Friday, December 15,2006 11:29:38 AM I
Icondensate Polisher. - -1
\To Drevent backfeeding contamination from 21 S/G-to-anybtherS/G through the unaffected [
IS/G to secondary systems.
I 1 Friday, December 15,200611:29:58AM I
- F k power is rising slowly.
- RCS Tave is dropping slowly.
- Containment pressure is 0.1 psig and steady.
ause charging flow to it would rise along wi I Page 13of91 1
I t Which of the following ch describes how AFW flow will be controlled after the I Friday, December 15,2006 11:29:38 AM Page14of91
]
- Unit 2 has lost all off site power.
- 2A EDG failed to start.
- 2B EDG tripped on overcrank.
- 2C EDG started but its output breaker tripped on 2C Vital bus differential current.
- After isolating SW to the Turbine Building at Step I 9 of EOP-LOPA-I , Loss of All AC Power, 2A EDG is successfully started and its output breaker is shut.
I Friday, December 15,200611:29:38AM I Page 15 of 91 1
Unit 2 is operating normally at 100% power.
23 charging pump is in service.
21 and 24 SW pumps are in service.
A loss of the 500KV switchyard occurs.
IWhich of the following contains ONLY equipment that will be running as determined by the 2RP4 I
I
_ _ - ~
1 Page 160f 91 I
, 1A DIESEL GENERATOR UNIT TRIPS, fails and trips open.
lThe EDG will mechanically.. .
/start, but will NOT be capable of flashing its field, due to not having a PMG ~ on the shaft.
~ ~ -
Istart ONLY if the Fire Bypass Switches are placed-in BYPASS,-which-allowslocal starting of I
/normal and emergency'source, but the stem-states the emergency supply breaker has not been closed in I I Friday, December 15,200611:29:38 AM I I Page 17of E--]
- Unit 2 is in MODE 6, with core reload in progress.
- Containment Purge is in service.
- Water level over the Rx vessel flange is > 23'.
- The Spent Fuel Pool Gate Valve is open: . ,~ . .
I I explanation of major precaution and limitations in the Containment and Containment Support Systems procedures I Page8of91 I
plied to S2.OP-AB.RAD-0001 (a):
[ Friday, December 15,2006 11:2938*AM 1 ~ Z i T - ]
m at rate not to exceed I 0 0 degree I hr cooldown rate. This will prevent entry into FRTS-esponse To Imminent Thermal Shock, which would require an 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> soak and raise the ,
lcomponents.
1 I I I I Friday, December 15,2006 11:29:38 AM I
1-- Unit 2 is operating at 25% during a power ascension following a refueling outage.
1- 21 charging pump is in service.
An RCS leak is identified, and operators enter S2.OP-AB.RC-0001, Reactor Coolant System 1 indications are present:
- PZR level is dropping - 0.1 % every 45 seconds.
to raise VCT level.
A. Describe an Intersystem LOCA (ISLOCA)
B. Describe the conditions under which an ISLOCA is expe 1 Friday, December 15, 2006 11:29:38-AM 1 pPage210f91-I
- RCS Bleed and Feed
- CETs are STABLE.
- Containment pressure is 0.5 psig.
I Electricians have reported that a spare breaker of the same rating has been installed in 21 AFP cubicle and is ready to be shut. The SM concurs with starting 21 AFP.
When establishing flow t ilable SGs, which of the following describes the AFW feed strategy to restore SG levels?
llnitiate AFW flow.. .
- ---1-1.
lat maximum rate until WR level is greater than IC%, then'feea at desired rate to recover levels
/at 1.O - 5.0 E4 Ibm/hr until WR level is greater than I 1%, then feed at desired rate to recover
/Components,and functions of control and2safeffsqsEms: including instrumentation, signals,
. Distracter b is I I I -- I 1 Friday, December 15,2006 11:29:38 AM 1
Unit 2 was operating ower.
A small break LOCA oc The reactor has tripped I has been initiated.
Numerous ECCS components did not starVreposition as required.
- FRCC-2, "Response to Degraded Core Cooling", is entered.
You have been directed ce SI Valves in Safeguards position using Table A, Safeguards Valve Alignment.
Which ONE (I) of the following sets of valves should have automatically opened upon receipt of an
I Friday, December 15,2006 11:29:38'AM 1
/Giventhe following conditions:
- Unit 1 initiated a Rx trip due to a LBLOCA.
- 11 RHR pump is C/T. ~ _ I ~ __ - __ __-
- Operators have transitioned to EOP-LOCA-5, Loss of Emergency Recirculation, when the 12SJ44, RHR Pump Suction From Containment
/Sump, failed to open when required.
During the performance Cz2; ~ u l f i ~ l e - S t e aGenerator m Depressurization, the following plant condition exists:
- Cooldown rate of the is greater than IOOF/hour.
How is the control room creWdirected to cont -- -
I IGenerators: ____ I I Friday, December 15,2006 11:29:38 AM i
to a secondary system malfunction.
- Operators are pe
- The CRS elects t S-2, Steam Generator Overpressure, for a YELLOW PATH on the Heat Sink Status Tree.
Which of the following co
[psig.
I Friday, December 15,200611:29:38 AM ~
Page28of91 I
Unit One is in Mode 5,
- 11 CVCS HUT level is
- 13 CVCS HUT level is Using the attached tank
the target temperature.
The following indicated eters are present:
- Ruptured SG pressure
- Ruptured SG level is 4
- PZR level is 5% and
< - 17.2,21,25,and 27 - ______
I Friday, December 15,2006I I :29:38AM I I Page30of91 1
- 11 and 12 CCW pu
- 13 CCW pump is 0 1 Friday, December 15,200611:29:38 AM 1
- Unit 1 is operating at I
- Operators are transferring CVCS Letdown from 1CV4, LETDOWN ORIFICE ISOLATION VALVE, to 1CV3, LETDOWN ORIFICE ISOLATION VALVE, IAW S I .OP-SO.CVC-0001, CHARGING, LETDOWN, AND SEAL INJECTION.
- 1CV18, LETDOWN PRESSURE CONTROL VALVE, is in MANUAL.
and how the 1CC71, LTD Itemperature. I
[temperature.
/throttled CLOSED as pressure lowers, and the 1CC71 modulates closed in response to lower I Itemperature. I oressure and temoerature chanaes.
LetdownlCharging Letdown lsolaiton Valves, CV2, CV277 Regenerative Heat Exchanger Letdown Orifices Letdown Orifice Isolation Valves, CV3, CV4, CV5 Letdown Releif Valve, CV6 Letdown Line Containment Isolation Valve, CV7 RHR Flow Control Valve, CV8 Letdown Heat Exchanger Low Pressure Letdown Control Valve, CV18 Temperature Control Valve, CV21 Demineralizers (Mixed Bed, Cation, and Deborating Inlet Valve to Deborating Dernin, CV27 Reactor Coolant FiIGr Diversion Valve, CV35 CVCS Holdup Tanks I Friday, Dew1 3er 15.2006 11:2938AM I [ Paae 320f 91 -1
Volume Control Tank n_______I_c ---
VCT Isolation Valves, Chemical Mixing Tank Charging Pumps (Centrifugal and PD)
Miniflow Recirc. Valves, CV139, CV140 Seal pressure Control Valve, CV71 Chg. Line Containment Isol.Valves, CV68, CV69 Charging to Loop 3 Valve, CV77, Loop 4 Valve, CV79 PZR Auxiliary Spray Valve, CV75 CCP Flow Control Valve, CV55
- b. RCP Seal Water - . --_
Seal Water Injection Filters Seal Bypass Flow Valve, CV114 Seal Water Return Seal Return Cont. Ives, CV116, CV284 Seal Return Filter Seal Water Heat Exchanger
- c. Excess letdown Excess Letdown Is01 Ives, CV278, CV131 Excess Letdown Diversion Valve, CV134
- d. Makeup Primary Water Storage Tank Primary Water Makeup Pumps Boric Acid Batch Tank Boric Acid Tanks Boric Acid Transfer Pumps Boric Acid Filter Boric Acid Blender Primary Water Flow Control Valve, CV179 Boric Acid Flow Control Valve, CV172 Charging Pump Suction Valve, CV185 VCT Makeup Isolation Valve, CV181 I CVCSOOE008 System, including:
a) The Control Room location of Chemical and Volume Control System control bezels and indications (N/A NEO) b) The function of each Chemical and Volume Control System Control Room control and indication (N/A NEO) c) The effect each Chemical and Volume Control System control has upon Chemical and Volume Control System components and operation (N/A NEO) d) The plant conditions or permissives required for Chemical and Volume Control System Control Room controls to perform their intended function
- 11 RHR pp is C/T.
I I I I I 1
1- Salem Unit 2 has experienced a LBLOCA.
All equipment functioned properly EXCEPT 21 RHR pump, which seized 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> after SI was I
1-initiated. It will take 3 days to repair.
After consultation with the TSC, 21SJ45 RHR TO SI PMPS STOP VALVE was closed, and no other operational action related to 21 RHR pump trip has been taken. 1 i
Which of the following identifies the lineup which will be present AFTER the transfer to Hot Leg !
1
- Unit 2 has experienc
./_-
During normal power operations, which of the-following describes how Pressurizer Relief Tank (
PRT) temperature is reduced if required IAW S2.OP-S0.PZR-0003, Pressurizer Relief Tank 1 1
- Unit Iis operating at 100% power.
- Pressurizer level is dropping slowly.
- CCW Surge tank level is rising slowly.
- Radiation Monitor R I7A,'CCW Process Radiation Monitor is rising.
Which of the following identifies the component which is the source of in-leakage to the CCW system, and what action(s) will prevent the release of radiation to the atmosphere?
[RHR Heat Exchanger;-1R41D will swap Aux Bldg Exh ventilation to HEPA plus Charcoal in 1 lplus Charcoal in service. ~
Which of the following choices describes an evolution which will require the GREATEST magnitude (in percent from normal) of correction signal for the PZR-MasterP-ressure Controller to return PZR I ontrol System control bezels and indications.
stem Control Room control and indication.
control has upon Pressurizer Pressure and Level Control
- Unit 2 is in MODE 3, OP.
- The North 13KV bus 6 becomesdeen-ergized, and remains deenergized.
(WithNO operator action, which of the following identifies ONLY the Unit 2 PZR heaters which Iremain available for PZR pressure control?
-~ . ----- - --- - - I I _-,---
~ ~ -___-----
121 Backup heaters ONLY. -
122 Backup heaters ONLY. .. . -
leaves only the 22 B/U heaters powered frornE 4KV group bus (601397) available for pressure control.
21 B/U heaters does have a manually transferable power supply to a vital bus, but the question stem specifically says with no operator action. The distracters are wrong because they contain the incorrect
/heatergroups.
I Friday, December 15,200611:29:39AM
- SSPS testing is in progress IAW S I .IC-STSSP-009, Solid State Protection System Train B Functional Test.
- k Trip BYPASS breakeF-B is racked inand SH
- Rx Trip breaker B is racked in and SHUT.
- OHA A-42, SSPS TRN B TRBL is in alarm as expected.
The 48VDC power sup B Vital b ST binet bec Which of the following describes the impact of this power supply becoming deenergized while in lbecome deenergized. -~
. . ..... . .. ~ . . . .... - ._ -- .-. . - ... .
I Friday, December 15,2006 11:29:39 AM I
I I
I I
- Unit 2 is operating at 1
- The reactor does NOT trip.
Conversely, other are , causing Xenon burnout rate to lower. As iodine I up, reversal of the initial
/c 12/11/20061 Plant Svstems correct because Large thermal reactors with little flux coupling between regions may experience spatial power oscillations because of the non-uniform presence of xenon-I 35. The mechanism is described in the following four steps. (1) An initial lack of symmetry in the core power distribution (for example, individual control rod movement or misalignment) causes an imbalance in fission rates within the reactor core, and therefore, in the iodine135 buildup and the xenon-I35 absorption. (2) In the high-flux region, xenon-I35 burnout allows the flux to increase further, while in the Iow-flux region, the increase in xenon-eas high and tsii cay to xenon reverses the initial situation. Flux decreases in this area, and the former low-flux region increases in power. (4) Repetition of these patterns can lead to xenon oscillations moving about the core with periods on the order of about 15 hours1.736111e-4 days <br />0.00417 hours <br />2.480159e-5 weeks <br />5.7075e-6 months <br />. With little change in overall power level, these oscillations can change the local power levels by a factor of three or more. D is incorrect because it concerns radial flux tilts and lcoastdown factors.
I
- A small break LOCA h cu -.n Unit I.
- The RVLIS Summary Page is displaying D Y N A M l e - m N r
- During the subsequent cooldown and depressurization, DYNAMIC RANGE indication remained constanfat 80% with RCPs running.
Which of the following describes DYNAMIC RANGE response and reason fort
- _.L_1 1-- _ L . , ,
__- 1 _ _ -
- Unit Ihas experie e Break LOCA from 10 power operation.
- Before operators containment pressure rises to I O psig.
- Off-site power re Assuming ALL aut cur as-expected, which of the following describes CFCU
'operation BEFORE operators take any MANUAL actions?
I jfol lowing: __ ____-___
IK4.021!Correlation of fan speed and flowpath changes _-- with containment pressure -__ 1/31"1i3.4*/
fety Injectionwhen containment pressure reaches 4 psig,
- No. I& 2 Units Safeguards Emergency I
Given plant conditions, relate the Containment and Containment Support Systems with the following:
Containment Isolation/Containment Integrity i
Electrical Penetrations Personnel Access Hatch Service Water S
In addition to pressing the STOP PB on CCI, whichaNE-ofth%-Tollowing identifies ALL required hase A, ensure containment press t first be reset. SI can be reset p breakers have been cycled.
I 1
1 includhg:
The Control Room location of ContainmentSpray System control bezels and indications. (Licensed Operator 8 STA only)
I Friday, December 15,2006 11:29:%xM I
- A LBLOCA has occurre
- In response to a RED n the CORE COOLING C i t i 1, Response to Inadequate Core Cooling, is currency in p
- Containment hydrogen Which of the following sta hydrogen
- Unit 1 is operating at 100% power.
- Control room operators are preparing to perform a Containment Pressure Relief IAW S I .OP-SO.CBV-0002, CONTAIN PRESSURE-VACUUM-RELIEFSYSTEM OPERATION.'
1- Containment radiation I 1R12A - Containment Gas Effluent 1R41B - Plant Vent Noble Gas lntermed 1R41D - Plant Vent Noble Gas Release Rate I rises: 1R41B constant: 1R41D constant.
11R12A constant: IR41B rises; 1R41D const' 11R12A constant; IR41B constant; 1R41D rises.
during a pressure relief with d the R41D provides the (cclsec). It will rise when the pressure relief is initiated, and also provides automatic termination of 1 Friday, December 15,2006 11:29:%9~~-I
- Unit 2 is in MODE 6.
- Fuel movement is in p ss in both the containment and Fuel Handling buildings.
- Operators in containment report lo
- Due to a mis-communication, the Fu
- The Fuel Pool Gate val Which of the following choices identifie
Unit 2 is at 100% power.
Reactor Trip Breaker B A) fails to open, and is stuck in the shut position.
I Friday, December 15,2006 11:29:39 AM I I Page54of91 1
- 21 SGFP must be rem Which of the following is d is incorrect because it is the power Miscellaneous Condensate System Heater Drain System Gland SeallGland Ezhaust System Condenser Air Removal System Extraction Steam System Turbine Auxiliary Cooling Auxiliary Feedwater System Main Turbine Control Air System .
Bleed Steam Demineralized Water System Advance Digital Feedwater Control System Reactor Coolant System 1 Friday, December 15,2006 11:29:39 AM ! I Page55of91 1
I Friday, December 15,2006 11:29:39 AM I ._.
I
~
Page56of91 1 -
- Unit I is operating at 85
- 1I charging pump is i
- During a manual bus r to clearing and tagging a Station Power Transformer, the I A 4KV vital bus is inadvertently deenergized, and the SEC loads 1A bus in Mode 2*.
- All other electrical bus rs expected to occur from the loss of I A 4KV vital bus are successful.
lWith NO operator action, IPZR Backup heaters have cycled on due to l 0 w - W I iPlant Svstems Cnts and how their normaland abnormal operation affects the Auxiliary Feedwater System:
Motor-driven Auxiliary Feedwater Pumps Turbine-driven Auxiliary Feedwater Pump 1 Turbine-driven Auxiliary Feedwater Pump Start-Stop Valve (MS132)
Turbinedriven Auxiliary Feedwater Pump Trip Valve (MS52)
! Turbinedriven Auxiliary Feedwater Pump Speed Control Valve (GOV) (MS53)
I - -
1 Friday, December 15,2006 11:29:39Xvl I I Page58of91 1
- Unit Iwas tripped from 100% power due to a steam leak.
- A MSLl was successful in isolating the leak.
- The PO idles 23 AFW pp,-and throttles AFW flow in EOP-TRIP-2 to 6E4lbm/hr to each SG.
- 2C EDG is operating in ST.DG-O014,2C DIESEL
- Cumulative run times
- While operating at 252 speed control resulting in MW loading increasing to 2800 KW.
Which choice describes t for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, and 31 Found in the ST for 2C Endurance run, steps 5.1.4 and 5.1. ours, the EDG will exceed the limit of 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for operatio that the cumulative run time for ALL xperience, review th revent recurren
\FacilityExam Bank sl 1 birect From Source I
. . . . ......... .- ........ -.--I^-.. ~...~ ... .
- 2C EDG is operating i ST.DG-O014,2C DIESE
- Cumulative run times n 10% of rated. I
- While operating at 25 ot%iiI~iak&i~djES-2C EDG speed control resulting in MW loading increasing to 2800 KW.
Which choice describes the-consequences, if any, of continued EDG operation at this KW load?
Diesel Generator p I . . . ........ ........... . . . . .--I-_.-__._.-._L_ .. ._,..--~j_i_~_-_..-_---I-. . .
- Units Iand 2 are ope
- 4KV Vital buses 1A and I C are powered from 13 SPT. 1B is powered from 14 SPT.
- 4KV Vital buses 2A and 2B are powered from 24 SPT. 2C is powered from 2C EDG running in parallel with the grid.
- All other electric system lineups are normal for full power operation.
- A fault occurs which se a trip signal to the North 13KV ring bus breaker 1-6, but it does NOT open.
resistance-to-ground.
resistance. B is incorrect because of A above. C is.-=incorrect - - e-- -__-
because operation of the ground test PB doesn't interrupt th nd w o n m a t e the low voltage alarm. D is incorrec because there is no such AAT alarm. However, if the student does not know the correct answer, it is a ion of DC Electrical System control bezels and indications. (Licensed Operator & STA only)
' The function of each DC Electrical System Control Room control and indication. (Licensed Operator & STA only)
I The effect each DC Electrical System control has upon DC Electrical System components and operation. (Licensed Operator &
STA only) i I
The plant conditions or permissives required for DC Electrical System Control Room controls to perform their intended function.
(Licensed Operator & STA only)
I DCELECE007 I NCT Identify and describe the local controls and indications associated with the DC Electrical System, including:
The location of DC Electrical System local controls and indications. (Licensed Operator & Non-licensed Operator only) and indications. (Licensed Operator & Non-licensed Operator only) r DC Electrical System local controls to perform their intended function.
1 Friday, December 15,2006 11:29:39AM 1 pa-1
- Unit 1 is in MODE 4.
- An electrical fault cau 1 Friday, December 15,2006 11:29:39 AM 1
- Unit 1 is operating in 1.
- While performing rounds, an NE0 isolated the Air Compressor supply valves to 11A and 11B Diesel Generator Starting Air Receivers in order to perform a blowdown of the tanks for moisture IAW S I .OP-DL.ZZ-0006, PRIMARY PLANT LOGS.
- BOTH Air Receivers w Which of the following de Specifications?
I
I Fridav, December 15,2006 11:29:39 AM I
- The RWO mistakenly p IWMHUT in service ELEASE OF RA ced o n recirculation fo time and resampling".
se the recirculation tim
[ Friday, December 15,200611:29:39 AM 1 I Page67of91 I
including:
The Control Room location of Radiation Monitoring System control bezels and indications. (Licensed Operator & STA only)
The function of n Monikori_ngSystem Control Room control and indication. (Licensed Operator & STA only)
The effect each nitoring System control has upon Radiation Monitoring System components and operation.
(Licensed Operator The plant conditions or permissives required for Radiation Monitoring System Control Room controls to perform their intended I RMSOOOE003 RIA, Control Room Area Monitor R1B, Control Room Inlet Duct Monitor ~
R5, FHB 0 SFP Area Radiation Monitor R7, In-core Seal Table Area Radiation Monitor _ -
R9, FHB D New Fuel Storage Area Radiation Monitor RIOA, Personnel Hatch 0 Containment Elev IOOE Area Monitor -
RIOB, Personnel Hatch D Containment Elev 130lE&ea Monitor-? ,-/ -*-lI_L I __ . ",_- ~ ____
RIIA, R12A, R12B, Containment Particulate, Noble Gas, and Iodine 6lonitor R13A, B, C D & E CFCU Service Water Monitors R15, Condenser Air Ejector Process Monitor R17A and B, Component Cooling Liquid Monitor R18, Liquid Waste Disposal R19A, B, C, & D, Steam Generator Blowdown Liquid Monitors 1R31A, Letdown Gross Activity Process Monitor 2R31, Letdown Heat ExchangedFailed Fuel Process Monitor R32A, Fuel Handling Crane Area Radiation Monitor R36, Evaporator and Feed Preheaters Condensate Monitor .
2R37, Non-Radwaste Basin Process-MoNtoy . . - I_ __ - I - _ _ _ -~
r Process Filter Monitor R41A. B. C. & D. Plant Vent Radiation Monitor I Fridav. Dece
R45A, B, C, & D, Plant Vent High Range Radiation Monitor R46A-E, Main Steam Line Process Monitor -..- I- .
R47, Electrical PenetrationArea Monitor 2R52, Liquid PASS Room Area Radiation Monitor R53, N16 Main Steam Line Radiation Monitor __-. ___
I ~
NCT Outline the infedocks associated with the following Radiation Monitoring System components: --
R1B, Control Room Inlet Duct Monitor _. . - .
R5, FHB D SFP Area Radiation MonitoC - - - . ___ __ ___
R7, In-core Seal Table Area Radiation MonitG R9, FHB D New Fuel Storage Area Radiation Monitor RIOA, Personnel Hatch il Containment Elev 100A Area Monitor RIOB, Personnel Hatch D Containment Elev 130&-&5_M~n~to~_ .
R1IA, R12A, R12B, Containment Particulate, Noble Gas, and Iodine Monitor
_.-_^___.I_____ __ - - __
R13A, B, C D & E CFCU Service Water Monitors R17A and B, Component Cooling Liquid Monitor R18, Liquid Waste Disposal R19A, B, C, & D, Steam Generator Blowdown Liquid Monitors R32A, Fuel Handling Crane Area Radiation Monitor densate. Monitor- -
I Friday, December 15,2006 11:29:3!%m -1 I -
. .. . ... .. . .. . . . . ~
- Unit 2 is operating at 100% power.
- Unit 1 is in MODE 5.
- All Unit 1 circulators are secured.
- Unit 2 Waste Liquid release is in progress from 21 CVCS MT to UNIT 2 CW system via the cross connect to Unit 1.
2RI8 2 RAD MONIT LI STE DISPOSAL PRCS RAD MON is OPERABLE.
[ Friday, December 15,2006 11:34:45 AM 1 I Page70of91 I -I .
.- -~ .
1- All Unit 1 circulators are secured.
Unit 2 Waste Liquid release is in progress from 21 CVCS MT to UNIT 2 CW system via the cross 1 connect to Unit 1.
2R18 2 RAD MONIT LIQUID WASTE DISPOSAL PRCS RAD MON is OPERABLE.
II Hot Shower Tanks, and their respective pumps RCDT Discharge Isolation Valves WL12 and WL13, and PRT Drain Valve PR14 ment Sump level, and Containment Isolation Valves WL16 and WL17 Isolation Valve WL51 and Liquid Waste Discharge Radiation Monitor RA4335/R18 Radioactive Liquid Waste valves WL12 & WL13, WL16 & WL17, WL96 & WL 97, WL98 &
. . ... . .. .. . _ _ ~.-.~
. . .. . . __ ~ . ... .... .. . .. .
I Friday, December 15,2006 11:34:45 AM 1 pGPageofS1I
- OHAK-2,4KV actions are required I
I Friday, December 15,2006 11:34:45AM I
Unit 2 is operating at power.
A large earthquake 5 miles from the site ca power.
The reactor trips, and a MANUAL Safety Inj
- 2B EDG output breaker es NOT close.
With NO other operator action, which choice contains the syste t having vital loads to sequence,still Nuclear Header System components:
Containment Fan Coil Unit High and low Speed Breakers CFCU Sew'ce Water Inlet Pressure Control Valve CFCU Motor Cooling Flow Control Valve SW Accumulator Building Ventilation fans Chiller Service Water Inlet Valve SI Pump Lube Oil Coolers Service Water Inlet Valve I SWONUCE007 -
NCT Identify and describe the local controls, indiGfioEs, and alarms associated with the Service Water Nuclear Header System, including:
Water ii Nuclear Header System local controls and indications. (Licensed Operator & Non-licensed The function of Service Water D Nuclear Header System local controls and indications. (Licensed Operator & Non-licensed Operator only)
The olant conditions or Demissives required for Service Water i~Nuclear Header System local controls to perform their intended I I I Friday, December 15,2006 11:3445 AM I I Page-_ 74 of 9 1 1
- Unit 1 is operating at 100% power.
- 12 charging pump is in service.
- Normal letdown must be secured to troubleshoot a-control_problemwith 1CV18, LETDOWN PRESSURE CONTROL VALVE.
- Excess letdown has been pia
, and the minimum Letdown lsolaiton Valves, CV2, CV277 Letdown Orifices Letdown Orifice Isolation Valves, CV3, CV4, CV5 Letdown Releif Valve, CV6 Letdown Line Containment Isolation Valve, CV7 RHR Flow Control Valve, CV8 Letdown Heat Exchanger Low Pressure Letdown Control Valve, CV18 Temperature Control Valve, CV21 I
I Friday, December 15,2006 11:34:45 AM 1
Inlet Valve to Deborating Demin, CV27 Reactor Coolant Filter Diversion Valve, CV35 CVCS Holdup Tanks Volume Control Tank VCT Isolation Valves, CV40, CV41 Chemical Mixing Tank Charging Pumps (Centrifugal and PD)
MiniRow Recirc. Valves, CV139, CV140 Seal pressure ContrZilValve, CV71 Chg. Line Containment Isol. Valves, CV68, CV69 Charging to Loop 3 Valve, CV77, Loop 4 Valve, CV79 PZR Auxiliary Spray Valve, CV75 CCP Flow Control Valve, CV55
- b. RCP Seal Water Seal Water Injection Filters Seal Bypass Flow Valve, CV114 Seal Water Return Isolation Valve, CV104 Seal Return Filter Seal Water Heat Exchanger
- c. Excess letdown Excess Letdown lsoktion Valves, CV278, CV131 - - - . -
Excess Letdown HeatE-Excess letdown Flow C Excess Letdown Diversion Valve, CV134
- d. Makeup Primary Water Storage Tank Primary Water Makeup Pumps Boric Acid Batch Tank Boric Acid Tanks Boric Acid Transfer Pumps Boric Acid Filter Boric Acid Blender Primary Water Flow Control Valve, CV179 Boric Acid Flow Control Valve, CV172 Charging Pump Suction Valve, CV185 VCT Makeup Isolation Valve, CV181 I CVCSOOE013
~. . , - .... _-,-
-1 . ~ ...L 1 Friday, December 15,2006 11:34:45';4M I . _--I . '.__ ...... ~
.. .. ~ ...-. _ _.~. .. . . . -. . -
! I lKnowledae of new and sDent fuel movement Drocedures. I / 2.61 3.51 Distracter b is the complement of fans required to be running to have an OPERABLE FHB ventilation system. Distracter c is incorrect because the requirement for supervision of loads in the Spent Fuel Pool is a SRO OR a Qualified RE. D is correct because in S2.OP-S0.SF-0009, REFUELING OPERATIONS, P&L 3.12 specifically requires suspension pump becomes INOPERABLE. The loss of all oil
~-
i I I
1 limitations in the Refueling System procedures. (Licensed Operator & Non-licensed Operator only) I SDecification action. (License ODerator and STA onlv) I I Friday, December 15,2006 11:34:45 AM 1 rPage770f91j
- 1/30/06 U2 PO
- 2/2/06 U2 RO
- 3/10/06 U2 RO tus of your license in IActive. You must regain qualification as RO by standing one additional 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> shift in the RO I- . XI- . -- I A is incorrect because the WCC NCO is not a Licensed Positiony-IC .
only stood 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> of wat I
I I Standards Reactivity Management Industrial Safety Practices Radiation Worker Practices Conservative Decision Making Control Room BAt ntrols Areao - - __-. __ -- -_ -_ __ _- -
Communication Shift Relief and Tu A l a n Response Operator Appearance Self AssessmentlCorrective Action PlanVControl Board Awareness and Maintenance of Critical Parameters 1 Friday, December 15,2006 11:34:45 AM I Page78of91 I
Housekeeping/Cleanliness/FME Operator Rounds Briefs Human Error Reduction Techniques Log Keeping Training Supervisor Involvement Accessing Equipment Attachment 1, Shift Lnefing Format Attachment 2, Pre-Job Briefing Guidelines Attachment 3, Pre-Job Briefing Checklist Attachment 4, Pre-Job Briefing Attachment 5, Human Performance, Top Ten Human Error Traps
. . . . . _._-.I- .... ..... .......... .... -.. .
a-..- .... .... ........ ...... .-. ..... ...... .______ i____l^
. . - . .. ~ .... ~- __ . . . . . . . . . . . . . ~~
... ... ~. . . . . . . . . .
-- - . . ~. ~ . .
I Friday, December 15,2006 11:34:45-4M 1 -
I Page79of91 1
A. Permissives and Control Grade Interlocks . . -_
B. Reactor Trips C. Safety injection D. Containment Isolation E. AFW Pump Auto Starts F. SEC Mode Ops G. RMS Automatic Actuations H. Reactivity Coefficients L. Feedwater Isolations M. Feedwater Interlock 1 Friday, December 15,2006 11:34:4!%M I
er feature. C is correct
- s. D is incorrect 1 Friday, December 15,2006 11:34:45 AM 1
- Unit 2 Reactor Trip
,.",_.-_.-...-I_ ".._
^___.
_.I t,,V"""'- ........... hen the reactor pening the Rx trip breakers. Distracter c is incorrect because it is 168 hours0.00194 days <br />0.0467 hours <br />2.777778e-4 weeks <br />6.3924e-5 months <br /> is the minimum time rewired durina the months of May 15th-Oct 15th.
I Friday, December 15,2006 11:34:45 AM I 1 Page 83 of 91 7
'The worker is 45 years old with a total jifehm2TEDE dose of 17 REM, and-________ --__I-.-- has received any --
lextension necessary for him to reach his CURRENT Salem dose.
Which of the following cho AP.ZZ-0024 RADIATION PROTECTION PRO describes a situation-that is allowed for this worker IAW NC.NA-M,-in-regardaohis fiiture'TEDE dose received I1, aufhorized by the Radiation Protection Manager. An incremental limit of up to 4,750 mrem may be authorized by the Plant Manager under Emergency conditions. Salem admin Lmgs apply ONLY to dose received at Salem. However, each nuclear plant is required by 10.CFR.20.1201 (f) to reduce the allowable dose by that dose received by the worker anywhere else. In the instance described above, the worker has a total YTD exposure of 4,170 mrem. MOST authorizations provided which would allow an the worker to exceed 5 REM/ yr are illegal. HOWEVER, 10.CFR.20.1206, Planned special exposures, directs that this dose shall&e maintainecdceparate from the yearly occupational dose, as long as the special exposure dose plus the occupational dose does not EXCEED the occupational dose numbers found in 1201(a). This means that the 5 REM/yr TEDE dose cannot be exceeded by more than 5REMTEDE. D correct because even ugh the Planned special exposure dose will NOT be added to his occupational dose, and as a result, his occupational dose will not rise above 5 REM for the current year. Distracters a, b, and c are both wrong because it would raise the workers-doselimit above 5 REM lfor the year, which is illegal.
' A. 10CFk20 dose limits for external, internal, and total whole body, skin, extremities, and eyes, as well as extension limits and requirements I 1
B. Administrative dose control levels for Category 1 and 2 Workers, as well as extension limits and requirements C. Reg. Guide 8.13 limits and administrajiyedose-cgntrol levels for Declared Pregnant Women D. 10 r-members of-m66%l public and minors E. Ca Radiation Worke I
1 Friday, December 15,2006 11:3445Nvl !
Unit 2 is operating at r.
Unit 1 is operating at 100% power.
A MANUAL Rx trip and SI are initiaed on UNIT 2 due to a LOCA.
NORMAL Mode.
.i ,... :
,d. .- .. . ...
- Unit 2 is operating at 10
- A release of 21 WGDT ss, 2WG41 is OPEN.
- Containment pressure Which choice states wh not a C ?
AR9.4rl .I .6fo-FeVenif exceeding the release can be automatically
. .that istracter - . said.
. you Zuldnt peEh- theXriase-6ecause-the procedure prohibits it, to the one i I Friday, December 15,2006 11:34:45 AM 1
- . I- ___
- Unit 2 is operating at
- A release of 21 WGD progress, 2WG41 is OPEN.
ay be performed, and why?
Rad Monitor to isolate its specific release path.
CANNOT be performed with a WGDT release in progress because the 2R41D does NOT isolate both releases on a high radiation signal from either release path.
e and the shortest decay time of the GDT prior to release VCI-6 on a high radiation signal. The dose is monitored as per FSAR 9.4.1.I .6 to prevent exceeding IOCFWO. The postulated activity has no consequence as long as the release can be automatically I
'Discharae of 21 Gas Decav Tanklo Plant Vent 1I
/ContainmentPressure-Vacuum Relief System Operation I
I I I major precaution and limitations in the Radioactive Waste Gas System procedures I Friday, December 15,2006 11:34:45AM
- Unit 2 is in MODE 5.
- A large fire is reported i be performed IAW S2.0P-RHR cooling must be terminated in order to transfer shutdown cooling to 22 RHR pump.
Initiate S2.OP-AB.RHR-001. Loss of RHR.
khe RCS to containment. I 12.4 jlEmergency Procedures / Plan 12.4.271 /Knowledgeof fire in the plant procedure.
Distracter c is incorrect because PORVs are isolated if the fire is in the relay room or control area.
Distracter a is incorrect because Fire Inside Control Room is not required, fire OUTSIDE control room is. Distracter b is incorrect because RHR cooling cannot be transferred to the other pump for the same reason.
The correct answeris d because S2.0P-AB.FIRE-1 directs the isolation of the RCS-RHR from the containment sump because the cablina for the SJ44s and the RH4s runs in the room. and sDurious hot I
l
- a. Determine the'appropriate abnormal procedure.
- b. Describe the plant response to actions taken in the abnormal procedure.
- c. Describe the final plant condition that is established by the abnormal procedure.
1 1 Friday, December 15,2006 1 1 : 3 4 : 4 5 ~ ~ [ Page89of91 I I
- Unit 2 is operating at 1
~OHAE-48, ROD BOTTOM.
__ - .-. ~
~OHAE-24, ROD DEV OR SEQ.
lRod Control NON-URGENT FAILURE 2CC2 Bezel Alarm. 1 A is incorrect because the P-250 computer wifi alarm for boththe deviation and rod bottom alarms. 'd is I Roo6 location of Rod Control and Position Indication Systems control bezels and indications (Licensed Operator &
n of each Rod Control and Position Indication Systems Control Room control and indication (Licensed Operator &
s control has upon Rod Control and Position Indication Systems I and Position Indication Systems Control Room controls to perform I Friday, December 15,2006 11:34:45 AM 1 I Pagegoof91 1
- Unit 2 is operating at I O
- ~ _-
The plant conditions or permissives required for Chemical and Volume Control System Control Room controls to perform j d) their intended function
[ Friday, December 15,2006 11:34:45 AM I pPageSlofS11
I U.S. Nuclear Regulatory Com Site-S peeific Written Examination I
Applicant Information Name: Region: I Date: I' 2/18/2006 Facility: Salem 1 & 2 License Level: SRO Reactor Type: W f
t Start Time:
I 1 Finish Time:
Instructions Use the answerkheets provided td document your answers. Staple this cover sheet On top of the answer sheets. The passing grade requires a final grade of at least 70.00 percent on the SRO section of the examination, 80.00 percent on the RO section, and a combined grade of at least 80.00 percent. Examination papers will I be collected EIGHT hours after the examination starts.
Applicant Certification All work done on this examination is my own. I have neither given nor received aid.
Examination Va I ue I
I Points qpplicant's Score I Points Spplicant's Grade ; Percent SROlRO Combined Score Points
~~
SROlRO Combined Grade Percen I ~ ---* --__x_. \-..-- - --
lem Unit 1 has exper a LBLO
- A majority of CETs have exceeded 1200 deg. F.
- 1-EOP-LOCA-1 was in progress when a transition to 1-FRCC-1, RESPONSE TO INADEQUATE
-CORE COOLING was made I-FRCC-1 has been i e at lo CET te ature
- The TSC is activated.
ransition is made to SAM I Friday, December 15,2006 11:35:34 A w l I Page1 of31 I
. . . .. . .. - - .... ., ... ... . .. . . .. . -- .- ... . . . . .... ~ .
- Unit 2 is operating at 100% power.
- 21 charging pump is in service.
- At 0200, an automatic VCT makeup occurs.
- At 0400, another auto makeup occurs.
- PZR level and charging flow are stable andhave re~m~ined,con,stantl_-_ __
auto makeup would leak on the dischar
power when 12 SGFP trip.
- The Main Turbine runs back as expected.
- The RO is unable to initiate a normal borafion.
- Operators receive OHA E-16,ROD INSERT LMT LO-LO
- Control Bank D position is 75 steps.
- Reactor power is stable at 64%.
- RCS boron concentration is 650 ppm.
Using the attached REM figures, determine the LEAST amount of time a rapid boration through 1CV175 is required IAW S I .OP-SO.CVC-0008, RAPID BORATION, in order to clear OHA"E-16?
18 minutes.
123 minutes.
130 minutes. 1 100 pcmk6.9 pcm.ppm = 14.49, rounded up to 15 ppm. A is incorrect because it is the time on the chart for a I O ppm boration. B is correct because IAW chart on page 3 of procedure 5 minutes are required for 10 ppm change. Therefore, a 15 ppm change would require 7.5 minutes. So 8 minutes would be the least amount of time of the.choices presented to inject enough boron. C is incorrect because it is the amount of boron added if there were 15 steps of control bank misalignment. D is incorrect because it is the'time reauired if iniection was from the RWST.
'Reactor Enaineerina Manual
- Rapid Boration I
1 CVCSOOE012 Describe the procedures which govern the operation of the Chemical and Volume Control System, including significant prerequisites and precautions associated with each operating procedure which are required to be considered by either Licensed or Non-Licensed Operators.
I Page3of31 I -- -
- Unit 2 has experienced
- While performing Faulted SG Evaluationa t Step 1 of 2-EOP-LOCA-1, LOSS OF REACTOR COOLANT, ALL off-site power is lost.
- 2C EDG reenergizes 2C 4KV Vital bus.
- 2A and 2B EDGs sta Which of the following identifies the correct procedure flowpath, starting from when off-site power
- ._-~ ___ -
ILOCA-3, and perform all action up until starting of RHR pumps is required. GO TO LOCA-5, I I Friday, December 15,2006 11:35:34AM 1
- A radiation protection technician reports the latest RCS sample indicates that specific activity has jumped to 70 uCi/gram.
- Prior to any action being taken, a 300 gpm tube rupture occurs on 22 SG
- A MANUAL Rx trip and a MANUAL Safety Injection were initiated successfully.
- IMMEDIATELY following the reactor trip, 22MS10, SG Atmospheric Relief Valve failed open.
- Operators cannot enter the affected penetration area to manually isolate the malfunctioning may be exposed to more than an acceptable portion of the 25 Rem cI_ -. -- - - -.__.__.-_
A person located at any point of the Exclusion Area boundary for the 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> immedStTv- -
following the fission product release may receive more than the 10CFR100 limit of 50 Rem to
/the thyroid from iodine exposure.
I A. IOCFkO dose limits for external, internal, and total whole body, skin, extremities, and eyes, as well as ehension 1
limits and requirements Friday, December 15,2006 11:35:34 AM
' r- -
Page 5 OfJ -13
I_--. ..... ... ..... - . . ... . . . . . -. ..... ... ..___.
II Fridav.
- . December 15,2006 11:35:34-AM I ...
II -
Paae6of31 1
.1 I ............... ..
- Unit 1 is operating at 100% power.
- A steam leak is identified-and the CRS-ordeE-ihe reactor tripped.
L-LY initiated after
If pressure rises above t IPORVs are not necessary for plant control. - "
- - - IL .__-____ __W_I_I-IM2. :IAbilityto determine and interpret the following as they apply to Loss of Off-Site Pou I
- edification Method:
I Friday, December 15,2006 11:35:34 AM 1 Page8of31 I
- Operators have transitioned out of EOP-TRIP-I .
- The PO is attempting to open 21-24SS94s, SG B/D Sample Valves, but they will not open.
- SGBD sample isolation bypass has been RESET.
/amendments. J en reset, the 94s can not be reopened. D is incorrect LOSC-i minimize the potentla1for a release I
] Friday, December 15,2006 11:35:54AM I I ~agegof31
] . _ . - _.
/Responseto Saturate1 7 -
-I L_-Page 10of31 I 1 Friday, December 15,2006 1I: 3 5 : m
- - x - _ - - I ~ ~ . ^ _ _ - -
Rx is tripped from 100% power, IR SUR i 22%. J 1230 deg. RCS pressure is 1200 psig. - I
&2 1!E ii arnDa@&j DOWE08A201 12/11/2006 7 1 [PressurizedThermal Shock ecause it is a PURPLE Path CFST. D is correct because it is the only RED path Thermal Shock Limit Curve shows that-ant cold leg temperature of 230 deg with the left of Limit A. The combination of > 100 deg/hr cooldown rate, and pressure
-c : . . _. . . . . . . . , . --.-_ .... . . I I FRTSOOEOOI State the RED paths for the Thermal Shock Status Tree I I . ~ . ~ ~
I I Friday, December 15,2006 11:35:34 AM 1 /Pagellor1
_ I _- - -_
- With SSPS testing and troubleshooting in progress a Phase B Containment Isolation signal was generated and all related valves closed.
- Before operators could re-open any of the Phase B valves, the operating Charging Pump breaker tripped on an electrical fault.
correct because the actions are correct per AB.RCP, and the cooldown will have to be performed I Friday, December 15,2006 11:35:34AM g e 12 of 31 I P a________
1
- PZR pressure is 35 psig.
- 1 CET is reading 9OO"F, ALL other CET's are reading -550°F.
- RVLIS Full Range is reading 74%.
- Containment pressure is 33 psig.
- Containment sump level is 62%.
- R44A radiation monitor is. indicating 50 Whr.
I Fridav. December 15,2006 11:35:34 AM 1 P
[I-
- The RO reports that P
- NO Overhead Annunc ICONCENTRATION CONTROL.
___ 1005000A204 I correct action to close the CV8. B not physically located at an elevation which could provide flow i a k e pressurei5ontrol is provided by the RHR pump discharge, and p would just cause it to become gas
- Unit 2 is operating at 100% power.
- ALL station Air Compressors trip.
- BOTH Units Emergency Control Air Compressors start.
- 2CC71 LTDWN HX CC NT VALVE, sensed a low header pressure on its primary air supply, and transferred to its back upply. When it transferred, the valve diaphragm failed, and the valve moved to its failed position.
- NO other air operated valves have been adversely affected by the air system perturbation.
Which of the following describes the effect this will have on the CVCS system, and what actions are
a) CCW Surge Tank b) CCWPumps c) CCW Heat Exchangers d) IsolationlControlValves i) CC-190, RCP Thermal Bar Disch Valve ii) CC-117 & 118, RCP Cooling Water Inlet Valves iii) CC-136 & 187, RCP Bearing Cooing Outlet Valves iv) CC-215 & 113, Excess Letdown Hx CCW Inlet & Outlet Valves v) C C - I ~ SRHR
, Hx Outlet Isolation Valves vi) CC-17 & 18, CCW Pump Suction X-connect Valves vii) CC-~S,CCP Outtet Valves viii) CC-30 & 31, CCHX Outlet to Aux. Header (Non-safety Related Header Isolation Valves) ix) CC-71, Letdown Temperature Control Valve x) CC-149, Surge Tank Vent Valve xi) CC-131, RCP Thermal Barrier Discharge Flow Control Valve I CVCSOOEOOL Letdown/Chataina i) Letdown Ishaiion Valves, CV2, CV277 ii) Regenerative Heat Exchanger iii) Letdown Orifices iv) Letdown Orifice IsolationValves, CV3, CV4, CV5 v) Letdown Releif Valve, CV6 vi) Letdown Line Containment Isolation Valve, CV7 vii) RHR Flow Control Valve, CV8 viii) Letdown Heat Exchanger ix) Low Pressure Letdown Control Valve, CV18 x) Temperature Control Valve, CV21 xi) Demineralizers(Mixed Bed, Cation, and Deborating xii) Inlet Valve to Deborating Demin, CV27 xiii) Reactor Coolant Filter xiv) Diversion Valve, CV35 xv) CVCS Holdup Tanks xvi) Volume Control Tank xvii) VCT Isolation Valves, CV40, CV41 xviii) Chemical Mixing Tank xix) Charging Pumps (Centrifugal and PD) xx) Miniflow Recirc. Valves, CV139, CV140 xxi) Seal pressure Control Valve, CV7l xxii) Chg. Line Containment Isol. Valves, CV68, CV69 xxiii) Charging to Loop 3 Valve, CV77, Loop 4 Valve, CV79 xxiv) PZR Auxiliary Spray Valve, CV75 m)CCP Flow Control Valve, CV55 RCP Seal Water i) Seal Water Injection Filters ii) Seal Bypass Flow Valve, CV114 iii) Seal Water Return Isolation Valve, CV104 iv) Seal Water Return Relief Valve, CV115 v) Seal Return Cont. Isol. Valves, CV116, CV284 vi) Seal Return Filter vii) Seal Water Heat Exchanger Excess letdown i) Excess Letdown Isolation Valves, CV278, CV131 ii) Excess Letdown Heat Exchanger iii) Excess letdown Flow Cotrol Valve, CV132 iv) Excess Letdown Diversion Valve, CV134 Makeup i) Primary Water Storage Tank ii) Primary Water Makeup Pumps iii) Boric Acid Batch Tank iv) Boric Acid Tanks v) Boric Acid Transfer Pumps vi) Boric Acid Filter vii) Boric Acid Blender viii) Primary Water Flow Control Valve, CV179 ix) Boric Acid Flow Control Valve, CV172 x) Charging Pump Suction Valve, CV185 xi) VCT Makeuo Isolation Valve. CV181
-Borate Stop Valve, CV175 xi;) Rapid Describethein a) VCT kola b) Letdown IsolationValves, CV2 and CV277 c) Letdown Orifice IsolationValves, CV3, CV4 and CV5 d, Centrifugal Charging Pumps -- -__ ~ ~ - - I __
I Friday, December 15,2006 11:35:34AM I I I Page16of31
~-
I -- -- ._ .
[ Friday, December 15,200611:35:34 AM I - -- L- I+&--%- ___ ~ - - -----_.--
~
- Unit 1 is in Mode 6.
- Rx power is 100 cps on-both SR channels.
- The Rx vessel upper internals are being put in place following core reload.
- Audible count rate in -.-.----.---
- Containment audible te is NOT lost. -
- BOTH SR channels e to indicate-I00 cps.
PRIOR to taking any act S2.OP-AB .NIS-0001, NUCLEAR INSTRUMENTATlON SYSTEM MALFUNCTION, which llowing identifies the required action, if any, to be taken IAW Tech j2.2.26TKnowledge of refueling administrative requirements. 11 2.511 3.7, 155.43/7) TSAS 3.9.2states that BOTH SR channels shall be operating EACH with continuous visual IindicGion in the control room, and ONE with audible indication in the containment and control room. The a) T6e Limiting Condition(s)for Operation b) The Bases for the LCO(s) c) The applicability of the LCO(s) d) The LCO Action Staternent(s) (N/A NEO)
I I 1 7 - 1
/Facility Exam Bank ~ mw P d x e d VISION Q69728 to make a distracter the correct answer and the correct answer into a distracter.
- _~. . _ i I Friday, December 15,2006 11:35:34 AM ]
- Unit 2 is in MODE 5.
- OHA C-35SFP LO Alarms.
- The NE0 dispatched to investigate reports SFP level just below the alarm setpoint, and appears to be stable.
- No leak identification action has been initiated.
ing to AB.FUEL-2 is
. C is incorrect since the emin water and PWST. D is edure which are required to be co
Ability to (a) predict the impacts of the following on the Steam Generator System and (b)3a%Z&n-thFse predictions, use__procedures to correct,
- control, or mitigate
__ the consequences of those abnormal operation:
ause 21 SG NR level to rise due to swell.
I I r- I
- orially Modified I 1 Friday, December 15,2006 11:35:35 AM 1 1 Page20of31 I
- 14BFI9 fails full close a period of 1 minute IWith NO oDerator action, which of the following responses will be apparent FIRST to the operators, I s associated with the Condensate and Feedwater System, including:
a) The Control Room location of Condensate and Feedwater System control bezels and indications b) The function of each Condensate and Feedwater System Control Room control and indication c) The effea each Condensate and Feedwater System control has upon Condensate and Feedwater System components and operation d) The plant conditions or petmissives required for Condensate and Feedwater System Control Room controls to perform their intended function e) The setpoints associated with the Condensate and Feedwater System control room alarms rL - 4 c ~
Condenser Hotwell Makeup and Rejection
' E] Condensate Pump Low Flow Recirculation
1 Friday, December 15,2006 11:35:35-AM'^ I
\Which ONE of the following is correct c o n ~ e ~ i ~ g ^ S Z - ~ ~ CONTROL ROOM--
~ ~ ~ ~ - R ~ O ~- - ~ ~ - ,
I I I ... . .... . - -. - . . __ .-.. -...
I .
- Unit 2 is operating nor t 100% power when 21 SGFP trips.
- The Main Turbine runs to 60% as expected.
- All systems respond a ed to the- runback.
- 2 minutes after the runback, the PO announces that condenser backpressure is 2.6"Hg and rising at I.Of' every Iminute.
- The CRS directs entry into AB-LOAD, and commences a 1%/minute load reduction, then directs the unloading rate raised to 3%/min when vacuum continues to degrade.
- With the reactor at 52% power, the Secondary NE0 reports that there is a 2" diameter hole in the SGFP exhaust line to 21 condenser, he can hear a loud whistling noise around the hole.
14 is using wrong procedure.
I
.^ ._ -.-.--.--_._"_--I - _-
Direct From Source I Friday, December 15,200611:35:35 AM I
_- ~~ ~ - ~ ----
-,------ . -. __ ._- ~
AND EVOLUTIONS PL from service or tagged. Could result in an unexpected load reduction, a plant tra or a reportable event. Should NOT result in a reactor, turbine, I l l . Equipment is NOT removed from service or tagged. Could have an effect on plant equipment but shall NOT present a risk of causing an unexpected load reduction, plant transient or reportable event. (Medium Risk) r testing activities
/Iand II only.
11, II, and Ill only.
11, II, Ill and IV.
12.2.201:Knowledgeof the process for managing troubleshootingactivities. 1122113.31
/55.43(5) A is incorrect because both High Risk and VERY High Risk must be evaluated. C is incorrect lbecause Medium-Risk does NOT need to be evaluated. D is incorrect because Medium Risk and Low I
/Risk do NOT need to be evaluated.
/OPERATIONS TROUBLESHOOTING AND EVOLUTIONS PLAN DEVELOPMENT r
I Nuclear Procedure System: SELECT the purpose of the fchwing &es of procedures in accordance with NC.NA-AP.221 "
OOOl(Q), Nuclear Procedure System:
- a. Abnormal Operating Procedures
- b. Administrative Procedures
- e. Emergency Operating Procedures
- f. Integrated Operating Procedures
- g. In-service Test Procedures I Friday, December 15,2006 11:35:35 AM 1 Page25of31 I
I Friday, December 15,200611:35:33-AM 1 wrecf and is action time for several < 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />
- es. D is the action time if in MODES 1-2.
]Direct From Source I
- -- - I _ _ -
iewinn and aoorovina release Dermits.
' lEditoriallv Modified I
2-EOP-TRIP-I, REACTOR TRIP-OR SAFETY INJECTION, to respond to the Rx trip-caused I
by SG lo-lo level.
- I IS2.OP-AB.CN-0001, MAIN FEEDWATER / CONDENSATE SYSTEM ABNORMALITY, to laddress the imminent loss of 21 SGFP.
turbine runback failure. D is inc because the control console alarm response would only take time away from
IOVERHEAD ANNUCIATORS WINDOW G I
- USE OF PRO EDURES Nuclear Procedure System: SELECT the purpose of the foilowing types of procedures in accordance with NC.NA-AP.ZZ- '
OOOl(Q), Nuclear Procedure System:
- a. Abnormal Operating Procedures
- b. Administrative Procedures
- c. Alarm Response Procedures
- e. Emergency Operating Procedures
- f. Integrated Operating Procedures
- g. In-service Test Procedures
- h. Operating Procedures
- i. MMlS Work Standards I ABCNOlE004 Given a set of initial plant conditions:
a) Determine the appropriate abnormal procedure.
b) Describe the plant response to actions taken in the abnormal procedure.
c) Describe the final plant condition that is established by the abnormal procedure.
I - , - - -.-
jer 15,2006 11:35:35 AM I I
(page I
29 of 31 I - ..
[ Page30of31 I
- Hope Creek is operating at 100% power.
- Fire Brigade manning consists of 6 qualified personnel, which includes one Fire Brigade Leader.
- A Fire Brigade member falls ill, and is transported off-site by Medical Department personnel.
I