Text

Forwards Facility Outlined & Initial Exam Submittal & as Given Operating Exam for Test Administered on 971117-21
	ML20203L940
Person / Time
Site:	Calvert Cliffs
Issue date:	03/03/1998
From:	Curley V; NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION I)
To:	; NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
	NUDOCS 9803060321
	Download: ML20203L940 (482)
	v • d • e

,

liarch 3,1998 NOTE T0: NRC Document Control De!,k Mail St(p 0-S-D-24 FRON: dotI boalen . Lic nsing Assistant OperCingLicensi{ Branch, R

SUBJECT:

OPERATORLICENSINGEXAMINATIONADMINISTEREDON Noum h e R l14/J1_ff, AT 6 a lie a t~ 6 h ina .

DOCKET #50 .J.17

sad 60 -atY I!

l On en,$en /7-J/ /rP70perator Licensing Examinations were administered at the referenced facility. Attached, you will find the following information for processing through NUDOCS ar.d distribution to the NRC staff, including the NRC POR:

Item #1 - a) Facility submitted outline and initial exam submittal.

designated for distribution under RIDS Code A070.

b) As given operating examination. designated for distribution under RIDS Code A070.

Itt. #2 - Examination Report with the as given written exuination attached, designated for distribution ~ under RIOS Code IE42.

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11/97 NRC EXAM DEVELOPMENT Initial Training Unit l

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l TO: L. D. Briggs, Chief Examiner FROM: R. E. Niedzielski, Supervisor, ITU SUIU: 11/97 Initial Exam Outlines DATE: September 17,1997 I have a~ ached the required outlines for the 11/97 NRC Initial license Exams at Calvert Cliffs Nucleer Power Plant per Nareg 1021 Interim Revision 8, ES 201, in accordance with Attachment I of ES 201, the enclosed materials "shall be withheld from public disclosure until the examinations are complete" I have included form ES 201-2 with the test outlines, if you need any additional information ,

please don't hesitate to call me at:

(410)495-6542 (410)495:694. fax 2270 l

Sincerelv,

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Simulation Facility Calvert Cliff s Scenario No.: 1 Op Test No.: 1 Examir. cts: Operators:

., SRQ EQ

- 110f To evaluate the applicants' ability to initiate a norr .al plant power increase, to implement the ALMS Ols, Objectives- AOPs, as appropriate, for a Feedwater Regulating Valve erratic operation, failure of a second Power Range Safety channel, failure of the second stage seal on a RCP, and to execute the EOPs for an Excess Steam Demand event outside containment complicated by a SGTR on the same Steam Generator.

Initial Conditions: The plant is at 13 % Power, BOC (IC-19)

Power Range Safety Channel B Failed and Bypassed.

Turnover: Present plant conditions: Unit 1 is at 13% power BOC. All applicable control systems are in automatic.

Powcr history: Startup after short maintenance outage following 15 days of operation.

Equipment out of senicc: Power Range Safety Channel B is OOS and bypassed until the next Cold Shutdown.

Abnormal Conditions: Nonc Surveillances due. None Instructions for shift: Increase power to 100% at 10% per hour per OP 3.

SCENAR-4. DOC 1 09/15/97 4:17 PM

Event Malf. Event Event No No Typc* Description

,, Preload Nonc j i N/A R RO Continue raising plar.1 power to 100%

N BOP 2 173,0,5 1 DOP 2 minutes after commencing po .. increase (and after 5% power increase) Feed (ifwo07_01) Regulating Valve LIC 1111 begins operating erratically. The candidate is expected to recognize that a control problem exists with the feed regulating valve controller output and therefore direct that the valve be pinned. S/G level control will be on the bvp ss valve.

3 010,0 1 RO 1 minute aner the Feed Regulating Valve LIC 1111 is pinned and S/G level (IniO10_01) control established on the bypass valve, Power Range Safety Channel A fails high. Upon receipt of the subchannel deviation alarms the candidate is expected to diagnose the cause of the problem and take appropriate response as dictated by the Tech Specs. The candidate is expected to recognize that this is the second failure of a Power Range Safety Channel therefore requiring one channel

, to be placed in trip 4 049,4, 75 % C RO 5 minutes after Tech Spec requirements are implemented for Pcwcr Range (vrcs012_02) Safety Channel A, llB RCP second stage seal fails. The candidate is expected to recognize that a seal problem exists The severity for the malfunction will be such that the candidate should increase monitoring of the RCP and may discuss removing the RCP from senice for repairs The cant idate is expected to i

determine which seal has failed 5 102,O C DOP Approumately 15 minutes following the RCP seal failure, the MSIV on 11 (Ims008_01) Steam Generator begins to slow close. The candidate is expected to recognite dual indications, increasing steam pressure and lowering steam flow. Crew should realize that ASGT trip will occur and should manually trip the reactor-6 113,20 M ALL Following closure of MSIV for the 11 Steam Generator, Safety Valve 1 RV-(vms017,06) 3997, on 11 S/G, fails open. ~1 he candidate is expened to recognize that there is an uncontrolled steam leak in progress. The candidate is expected to trip the Reactorfrurbine, isolate the steam header and then determine the location of the leak. An audible sound effect simulating a steam release will be heard in the Control Room. The candidate is expected to implement EOP-4.

7 092,0,1 M ALL 2 minutes after implementing S/G isolation guidance contained in EOP-4, a (vms002 01) Steam Generator Tube Rupture occurs on 11 Steam Ocrerator. The candidate is expected to diagnose that a tube rupture has occurred and to transition to EOP-8 (Safety Function Status RLEC 2 a NOT satisfied).

Scenario shot 1d at first pass through APPENDIX (6) RADI ATION LEVELS EXTtIRNAL TO CONTAINMENT. RLEC 2: CONTAINMENT ISOLATED with de'ermination that safety function CANNOT be satisfied without closure of S/G Safety Relief

(N)ormal, (R)cactivity (I)nstrument, (C)omponent, (M)ajor Transient SCENAR-4. DOC 2 09/15/97 4:17 PM

l SCENARIO l-1 OVERVIEW From 13% pouct, a normal power increase at 10%'hr should be established in accordance with OP 2, step M. and

OP 3. Power will be raised to at least 15% and the feed system aligned to !!!GH POWER Mode.

i During the power increase, Fced Regulating Valve LIC llli begins operating erratically. The candidate is expected to recognize that a control problem exists with the feed regulating valve controller output and therefore direct that the valve be pinned. S/G level control will be on the bypass valve. -

After the Feed Regulating Valve LIC-l'111 is pinned and S/G level control re-established, Power Range Safety Channel A fails high. Upon receipt of the subchannel deviation alarms the candidate is expected to diagnose the i cause of the problem and take appropriate response as dictated by the Tech Specs. The candidate is expected to

. recognize ' hat this is the second failure of a Power Range Safety Channel therefore requiring one channel to be placed in trip, as addressed u Technical Specification 3.3.1.1.

After Tech Spec requirements are implemented for Power Range Safety Channel A, llB RCP second stage scal fails The candidate is expected to recognize that a seat problem exists. The severity for the malfunction will bc such that the candidate should increase monitoring of the RCP and may discuss removing the RCP from ser ice for repairs. The candidate is expected to determine which seal has failed based on indications-Approximately 15 minutes following the RCP scal failure, the MSIV on 11 Steam Generator begins to slow close.

The candidate is expected to recognize dual indications, increasing etcam pressure and lowering steam flow. Crew should realize that ASGT trip will occur and should manually trip' e reactor. Following closure of MSIV for the 11 Steam Generator, Safety Valve 1 RV 3997, on 11 S/G, fails open. The candidate is expected to recognize that there is an uncontrolled steam leak in progress. The candidate is expected to trip the Reactor / Turbine, isolate the i steam header and then determine the location of the leak. An audible sound efTect simulating a steam release will

. be heard in the Control Room. The candidate is expceted to implement EOP 4 and initiate isolatien of the 11 S/G.

After implementing S/G isolation guidance contained in EOP 4, a Steam Generator Tube Rupture occurs on 11 4

Steam Generator. The candidate is evoccted to diagnose that a tube mpture has occurred and to transition to EOP-Rf it will te determined that the Safety Function Status "RLEC 2 a." is NOT satisfied and actions will be taken in accordance with APPENDIX (6) RADI ATION LEVELS EXTERNAL TO CONTAINMENT. RLEC 2:

! CONTAINMENT ISOLATED. The scenario shou'd ind at first pass through RLEC-2 with determination that

safety function CANNOT be satisfied without closure e f S/G Safety Relief and actions to address the problem.

4 i

I l

SCENAR-4 DOC 3

{

! 09/15/97 4:17 PM l

Simulation Facihty Cah'crt Citfh Scenario No : 2 Op Test No.: 1 Examincts- Operators:

SED PD IKLP l

To evaluate the applicants' ability to initiate a normal plant power increase; to implement the ALM,AOPs, Ols, Objectn es' as appropnate, for a failure of a Steam Oenerator pressure channel, a loss of CVCS letdown, a loss of position indication for one CEA, and a loss of turbine generator load due to partial closure on a Control Valve; and to execute the EOPs for a large Steam Ocnerator tube leak w hich degrades to a multiple tube SGTR and the failure of a liPSI pump to start Ini : onditions: The plant s at 50% Power; MOC (1C.11)

Powct Range Safety Channel B Failed and Bypassed.

Turnover. Present plant conditions: Unit 150% power MOC. All applicable control systems are in automatic.

Power history: Return to power following short downpower from 75% due to oil leak on 12 SGFP.12 SGFP is now in standby per OI 12A.

Equipment out of service: Powcr Range Safety Channel B is OOS and bypassed until next Cold Shutdo*n.

Abnarmal conditions: CEAs are NOT ARO due to power reduction 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago.

Surveillances due: O-0978-0 D CONTROL ROOM HVAC BIMONTHLY TEST scheduled to be performed within next 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Instructions for shift: Continue plant startup at 12% per hour IAW OP 3, step E and place 12 SGFP in parallel operation with iI SGFP per Ol 12A NOTE: 11 & 12 FW Heaters are in service. Continue raising plant power to 100%

SCENAR-2. DOC 1 09/15/97 4:18 PM

Event Malf. Event Event No No Typc* Description

, Preload l N/A R RO Continue raising plant power to 100% and place 12 SGFP in parallel operation N BOP 1

2 252,2,1 I BOP 2 minutes after commencing powcr increase,12 S/G Pressure PT 1023B fails !

(Ims021_02) low resulting in a 1 out of 4 RPS tnp and an ESFAS SGIS. The candidate is expected to recognize that a Steam Generator Pressure transmitter has failed and is expected to comply with all applicable Tech Specs 3 073 C RO 2 minutes after the Tech Spec requirements are implemented for the failed S/G (leves006) Pressure transmitter, a loss of normal letdowa occurs when valve CVC 516 fails closed. The candidate is alerted to conditions by indications and alarms, and is expected to secure the charging system and initiate troubleshooting activities 4 033, CEA 35 i RO 2 minutes after the charging system is secured and troubleshooting activities arc (Iceds013.36) initiated, CEA 35 reed switch position indicatt Sls. The candidate is expected to recognize the loss of position indi.e and take the appropriate action as defined in the Tech Specs 5 138,0, 10 % C BOP 5 minutes after the Tech Spec requirements are implemented for the failed CEA (ugo24_01) position indication, a load rejection occurs (10% closure of CV 1, no trip desired). The candidate is expected to recognize that turWne load has decreased and that a mismatch exists between the turbine and reactor power levels. The candidate should attempt to reduce reactor powcr to the corresponding turbine pow er.

6 091,4,100 M ALL 2 minutes after attempts are made to reduce reactor power to compensate for the (vms001_02) load rejection, or after the reactor trip if one should occur, a major tube leak occurs in 12 Steam Generator. The candidate is expected perform actions of EOP-0, to diagnose the event and should implement EOP-6.

7 188,O C ALL The 11 HPSI Pump inps u hen started (fails to start) on SI AS. The candidate is (Isi002_01) expected to recognize that the selected HPSI Pump has failed to start and should take action to insure that the backup pump is operating. The candidate is expected to attempt to manually start the pump.

8 092,4,5 M ALL When the Post Trip immediate Actions are complete in EOP-0, the S/G tube (vms002_02) leak worsens to become a multiple tube rupture. The operator actions for the SGTR are still addressed in EOP-6. Scenario should end following step J of EOP4 with evaluation of the need for HPSI/LPSI throtthng/ termination

(N)ormal, (R)cactivity (1)nstrument, (C)omponent, (M)ajor Transient SCENAR-2 DOC 2 09/15/97 4:18 PM

KENARIO 1-2 OVERVIEW From 50% power, a normal power increase et 12Whr should be established The 12 Steam Generator Feed Pump (SGFP) will be started and placed in parallel operation with running i1 SGFP During the power increase, the 12 S/G Pressure PT 1023B fails low resulting in a 1 out of 4 RPS trip and an ESFAS SGIS The candidate is expected to recogniic that a Steam Generator Pressure transmitter has failed by indications and alarms. The crew is expected to comply with actions directed by Technical Specifications 3 3.1.1 (RPS),3 3.2.1 (ESFAS),3.3 3,5 (Remote Shutdown),3.3.3 6 (Pest Accident).

Following determination of Technical Specification ACTION (s) concerning the failed S/G Pressure transmitter, a loss of normal letdown occurs u hen valve CVC 516, Letdown CNTMT isolation, fails closed Tlw candidate is alerted to conditions by indications and alarms, and is expected to secure the charging and letdown system and initiate troubleshooting activities (See IC07 ALM window F 24).

After the charging system is secured and troubleshooting activitics are initiatad, CEA 35 reed switch position indication fails The candidate is expected to recognize the loss of position indication (flashing) and alarm, and to take the appropriate action as defined in the Technical Specification 31.3.3.

After the Tech Spec requirements arc implemented for the failed CEA position indication, a load rejection occurs (10% closure of CV a, no trip desired). The candidate is expected to recogniic that turbine load has decreased and that a mismatch exists between the turbine and reactor power levels. The candidate should attempt to reduce reactor power to the corresponding turbine power. Actions are expected to be taken IAW AOP 7F LOSS OF LOAD and'or AOP-7E MAIN TURBINE MALFUNCTION Section X111.

2 minutes after attempts are made to reduce reactor power to compensate for the load rejection, or after the reactor trip if one should occur, a major tube leak occurs in 12 Steam Generator. The candidate is expected perform actions of EOP-0, and to diagnose the event. During performance of the post-trip actions, the candidate is expected to recognize that the i1 HPSI Pump has failed to start and should take action to insure that the backup pump is operating The candidate is expected to attempt to manually start the pump.

When the Post Trip immediate Actions are complete in EOP-0, the S/G tube leak worsens to become a multiple tube rupture. The operator actions for the SGTR are still addressed in FCP-6.

SCENAR-2. DOC 3 09/15/97 4:18 PM

9 Simulition Facihty Cah ert Cliffs Scenario No.: 3 Op Test No.: 1 Examiners: Operators: Sgg

. 80 DDP To evaluate the applia .s' ability to initiate a normal plant power increase; to implement the ALMS, AOPs, Objectives- Ols, as appropriate, for a malfunctioning control system on Steam Generator Feed Pump (SGFP), trip of running Boric Acid Pump, failure of VCT level transmitter with swap of charFing pump suction to RWT, trip of second SGFP, and turbine trip due to EHC power fault; and to execute the FOPS for an ATWS condition following the turbine trip and subsequent pressurizer steam space LOCA due to failed open Safety valve, Initial Conditions: The plant is at 80% Power, MOC (IC-68)

Danger tag 11 AFW Pp IMS 3988 "TIUPPED DO NOT RESET" Bypass Channel "C" TM/LP with key 7 12 BAST aligned for DIRECT RECIRCULATION IAW 012C,6.3 with Boric Acid Pp 12 running

1) HS-210 in MANUAL

2) HS-2512 in CLOSE

3) FIC-210Y in MANUAL set to 0%

4) 12 BAST recirculation valve CVC-511-CV open I

Turnover: Prescat plant conditions: 80% power, MOC; Unit 2 is in MODE 6 for refueling Power history: Decreasing pow; at 10%/ hour to comply with ACTION statement of Technical Specification 3.7.1.2.

Equipment out of senice:

1) 1I AFW Pp has failed turbine blades and is under repair. The pump has bees unavailaHe for 6f"r days and may possibly be returned to senice within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Operations Management nad decided to initiate a plant shutdown about 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago, to ensure compliance with the Technical Specification ACTION statement.

2) Channel "C" TM/LP trip bypassed at 0235 for troubleshooting.

Suneillances due: 12 DAST is currently on recirculation IAW OI-2C, section 6.3 for 30 minutes for planned sampling Instructions for shift:

l' Continue with downpower to HOT STANDBY cot ditions. A decision will then be made concerning continuing cooldown to HOT SHUTDOWN.

2) 12 BAST may be restored from recirculation after 30 minutes.

SCENAR-3 DOC 1 09/15/97 4:18 PM

Event Malf. Event Event No No Typc* De',cription

i. Preload 018 Failure of automatic reactor trip (/.TWS)

(Irps005) MT ALL

019 Failurc of MANUAL reactor trip (ATWS) '

(IrpsN)6 i N/A R RO Continue normal plant shutdown to Hot Standby.

N BOP 2 182,4,5 % i BOP $ minutes after commencing the power decrease and with at least 5% load shed, i (vfM)l5_02) a malfunction in the hydraulic system of 12 Steam Generator Feed Pump I Governor System occurs causing pump speed to change with control available in MANUAL The candidate is expected to recognize that a problem exists with !

the selected SGFP. The candidate should attempt to gain manual cor, trol of the SGFP. The candida4 is expected to implement AOP-3G.

3 082,O C RO 2 minutes after completing the required actions of AOP 3G, the 12 Boric Acid (levcsol4,01) Pump trips. The candidate is expected to recognize that the Doric Acid Pump has failed, and should stop any eperations invobing use of boric acid Upon diagnosing the cause, the candidate may select the alternate Boric Acid Pump for operation. The candidate is expected to comply with Technical Specifications 31.2.8,31.2.2 and 3.1.2.6 I 077, LOW l RO 5 minutes after placing the alternate Bcric Acid Pump in operation, VCT level (leves009) transmitter 1 LT 227 fails low, resulting in an automatic realignment of Charging Pump suction to the RWT. The candidate is expected to recognize that a problem exists and that the Chr.rging Pump suction has realigned to the RWT. The candidate should either isolate Charging and Letdown and manually control Charging to boration flow, or force realignment of Charging Pump suction to the VCT with valve breakers left in open position, as appropriate.

5 170 C DOP Following decision on controlling boration with failed VCT level transmitter,11 Steam Generator Feed Pump trips. The candidate is expected to recognize that a Steam Generator Fecu Pump has tnpped, and should take immediate action to insure that sufficient feed capacity is available to maintain Steam Generator levels. The candidate is expected to implement AOP 3G.

6 127,O C ALL $ minutes after completing the required actions of AOP 3G, a Turbine trip (itg013.01) occurs due to an EHC Power Fault. The Reactor does not trip automatically or l018 manually. The candidate is expected to recognize that a Turbine trip has

) occurred and that the Roctor failed to trip. The candidate should attempt to l(Irps005) ] manually trip the Reactor and upon failure to trip, complete contingency actions l019 required to compensate for the ATWS.

]

[(trps006 1 7 06), 90 % MT ALL Subsequent operation of Pressunzer Safety Valves due to ATWS condition, (vres022) results in RV 200 failing open. The candidate should implement EOP 5 based on Pressurizer steam space LOCA. Scenario should end following attempts to maintain RCS Subcooling IAW EOP 5, Section M.

(N)ormal, (R)cactivity (1)nstrument, (C)omponent, (M)ajor Transient SCENAR-3. DOC 2 09/15/97 4:18 PM

SCENARIO l-3 OVERVIEW From 80% powct, a normal power decrease at 10%'hr should be established IAW OP 3, section 6 4.

During the power decrease, a malfunction in the hydraulic system of 12 Steam Generator Feed Pump Governor System occurs causing pump speed to change with control available in MANUAL. The candidate is expected to recognize that a problem exists with the selected SGFP. The candidate should attempt to gain manual control of the SGFP. The candidate is expected to implement AOP-3G.

After completing the required actions o'f AOP 3G, the 12 Boric Acid Pump trips The candidate is expected to recognize that the Boric Acid Pump has failed, and should stop any operations invohing use of boric acid Upon diagnosing the cause, the candidate may select the alternate Boric Acid Pump for operation. The candidate is expected to comply with Technical Specifications 3.1.2.8,31.2.2 and 3.1.2.6. NOTE that Tech Spec 3.1.2.8 may not be apphc ble if power is less than 80%

After placing the alternate Boric Acid Pump in opciation, VCT level transmitter 1 LT 227 fails low, resulting in an automatic realignment of Charging Pump suction tc, the RWT. The candidate is expected to recognize that a problem exists and that the Charging Pump suction has realigned to the RWT. The candidate should cither isolate Charging and Letdown and manually con rol Charging to boration flow, or force realignment of Charging Pump suction to the VCT with valve break:rs left in open position, as appropria'c.

Following decision on controlf og boration with failed VCT level transmitter,11 Steam Gene:ator Fced Pump trips The candidate is expected to recognize that a Steam Generator Fced Pump has tripp4 and should take immediate action to insure that sufficient feed capacity is available to maintain Steam Gr.nerator levels The candidate is expected to implement AOP 3G After corapleting the required actions of AOP 3G, a Turbine trip occurs due to an EHC Power Fault. The Reactor does not trip automatically or manually. The candidate is expected to recognize that a Turbine trip has occurred anct that the Reactor failed to trip The candidate should attempt to manually trip the Reactor and upon failure to trip, complete contingency actior.s required to compensate for the ATWS. Subsequent operation of Pressurizer Safety Valves due to ATWS condition, results in RV 200 failing open. The candidate should implement EOP 5 based on Pressurizer steam space LOCA. Scenario should end following attempts to maintain RCS Subcooling LAW EOP-5, Section M.

SCENAR-3 DOC 3 09/15/97 4:18PM

( Simulanon Fac.lity Calvert Clifl1 Scenario No.: 4 Op Test No : 1 i

! Examiners: Operators: SBQ I

RO R0f To evaluate the applicants' ability to initiate a plant power decrease; to implement the ALMS, AOPs, Ols, as Objectives; appropriate, trip of a running Containment Spray Pump with loss of ALL Containment Spray systems, a malfunction of automatic control for maintaining the Main Generator hydrogen cooling. failure of CVCS letdown back pressure controller, a trip of the ope.ating CVCS charging pump and a trip of a Circulating Water Pump, and, to execute the EOPs for a reactor trip with a loss of all feed flow to the Steam Generators.

Initial Conditions: The plant is at 100% Power, MOC (IC 13)

Danger tag 11 AFW Pp IMS 3988 " TRIPPED DO NOT RESET *'

Darger tag 12 Containment Spray Pp PTL Tuznover: Present plant conditions: 100% power, MOC; Power history: Operating at 100% power for the past 100 days.

Equipment out of senice:

1) i1 AFW Pp has an oil leak on the governor and is under repair. The pump has been unavailable since 0500 and may possibly be returned to senice within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

2) The 12 CS Pp has a bearing overheating proble.n since 1200 yesterday Surveillances due: 0473K 1 CONTAINMENT SPRAY PUMP OPERABII,lTY TESTjust completed, Pump is still running on recirculanon r Engineering direction. Should be ready to shutdown in about 5 rninutes.

Instructions for shift: Maintain 100% power.

SCENAR-1. DOC 1 09/15/97 4:I8 PM

Event Malf. Event Event No No. Typeo Description Preload 186,0 & I C ALL Both treins of AFAS fail to actuate.

(1afwo04_01 (lafwOO4,02) l 183,4 12 AFW Pump fails to start due to throttle /stop valve (vafwo01_02) l 1 190,O C BOP Running Containment Spray Pump 11 trips, resulting in DOTH CS Pumps out l (IsiOO4 01) of senice. Technical Specifications require placing the unit in HOT STANDBY within the next 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months .

l 2 N/A R RO Load reduction in accordance with Technical Specifications. (NOTE:

N BOP Operations Management will contact shift, when informed of Event 1, that immediate shutdown should be initiated at 20%/hr.

3 144,O I BOP 5 minutes after commencing the power decrease, Main Generator Ilydrogen (Itgo30_01) Temperature Controller ITIC 1608 fails in AUTO isolatiag Senice Water to the hydrogen cooler. The candidate is expected to recognize that the generator hydrogen controller is malfunctioning and is expected to take MANUAL control of the controller. The candidate is expected to maintain the generator within the operating limits specified by the pressure vs load cunes 4 072 1 RO 2 minutes after the Main Generator Temperature Controller is placed in manual (levcs005) and temperature stabilized, Letdown Back Pressure transmitter 1T 201 fails low causing the back pressure regulating valves to close. The candidate is expected to recognize that a problem exists with the back pressure controller and to take manual control of the controller. Operation in manual will be complica ed by the fact that there is no indication of back pressure available.

5 070,O C RO 5 minutes after Letdown Back Pressure controller is placed in manual and pressure stabilized, the 1I Charging Pump coupling breaks. The candidate is expected to recognize that a charging system abnormality exists and start another pump The candidate should diagnose charging pump problem and not charging line break. Candidate should verify Technical Specifications for required OPERABLE charging pumps.

6 220,3 C BOP 2 minutes after deterraination is made that the charging pump is not functiomng (lewO0l_04) properly and another charging pump is started, the 14 Circulating Water Pump trips. The candidate is expected to recognize that a Circulating Water Pump has tripped and should take immediate action to insure that Turbine limits are not being exceeded. If necessary, the turbine should be manually tripped 7 153,O M ALL Upon turbine inp OR if turbine limits are venfied to be within normal (14kv001_01 operating limits, then 5 minutes following stabilization, a loss of 4KV bus 11

) occurs, and SGIS "A" actuates This results in a Rea. tor trip. The candidate is 244 expected to recognize the loss of 4KV bus 11 and the spurious SGIS "A" (Icsfa013) actuation. The candidate should realize that with spurious SGIS, no S/G Differential Pressure will develop (no faulted S/G). Entry into EOP-0 is made and the loss of power to 4 KV bus 1I is addressed by actions of AOP-71.

8 [l86,0 & 1l 1 ALL Any attempts to manually initiate AFW flow to the S/G's fail (AFAS will not l183,4 ] C actuate,12 AFW Pump will not start,13 AFW Pump not powered due to loss of 4 KV bus 11). This results in a total loss oficed water flow (Unit 2 cross-tie unavailable) and the candidate is expected to implement EOP-3. Scenario should end when once through cooling verified in EOP 3. Section 1 0(N)ormal, (R)cactivity (I)nstrument, (C)omponent, (M)ajor Transient SCENAR-1. DOC 2 09/15/97 4:18 PM

SCENARIO 1-4 OVERVIEW The scenario begins at 10F/* powct, with directions to maintain current power level A surveillance has just been completed to test the 11 Containment Spray Pump. The System Engineer has requested the pump be left running for a few minutes following the test because he thought he heard some odd noises from a motor bearing toward the end of the test Subsequently, the Containment Spray Pump 11 trips, resulting in BOTH CS Pumps out of senice (the 12 CS pump was OOS at beginning of shill). Technical Specification 3 0 3 requires ACTION within ONE hour to place the unit in a MODE where the specification does not apply and to be in at least HOT STANDBY within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months With Operations Management guidance, w h n contacted, a unit shutdown at 20*Vhr is initiated IAW OP 3. Section 6 4.

After commencing the power decrease, Main Generator Ilydrogen Temperature Controller ITIC-1608 fails in AUTO, isolating Senice Water to the hydrogen cooler, The candidate is expected to recognize that th: generator hydrogen controller is malfunctioning and is expected to take MANUAL control of the controller. The candidate is expected to maintain the generator within the cocrating limits specified by the pressure vs. load curves.

Following actions to MANUALLY control the Main Generator Tc.nperature Controller and H: cooler temperatures are stabilued, the Letdown Back Pressure transmitter PT-201 fails low causing the back pressure regulating valves to close The candidate is expected to recognize that a problem exists with the back pressure controller and to take manual control of the controller. Operation in manual will be complicated by the fact that there is no indication of back pressure available.

After Letdown Back Pressure controller is placed in manual and pressure stabilized, the i1 Charging Pump coupling breaks The candidate is expected to recognize that a charging system abnormality exists and start another pump The candidate should d agnose charging pump problem and not charging line break. Candidate should verify Technical Specification 11.2 4 for required OPERABLE charging pumps.

Following determination is made that the 1I charging pump is not functioning properly and another charging pump is started,14 Circulating Water Pump trips The candidate is expected to recognize that a Circulaiing Water Pum,. nas tripped and should tah immediate action to insure that Turbine limits are not being exceeded. If necessary, the turbine should be manually tr'pped based on the following limitations.

If any of the following occur for longer than FIVE seconds:

. Condenser vacuum < 25 inches Hg AND Gross electrical load is < 270 MWE e Maximum differential pressure between adjacent hvods is > 2.0 inches Hg

Two stopped CIRC WATER Pumps are associated with the same Condenser Then with SS/CRS approval, the reactor should be tripped The timing for the next event are based on whether the reactor is tripped due to the Circ Water Pump trip. If the reactor is manually topped, then the loss of power and SGIS tnp and isolation occur immediately with the trip. If the reactor is NOT manually tripped, then the loss of power and SGIS tnp and isolation occur approximately FIVE minutes following stabilization of unit load following the loss of the Cire Water Pump. Actions taken are the same.

A loss of 4KV bus !I occurs, and SGIS "A" actuates. This results in a Reactor trip. The candidate is expected to recognize the loss of 4KV bus 11 and the spurious liGIS "A" actuation. The candidate should reali7e that with spunous SGIS, no S/G DtfTerential Pressure will develop (no faulted S/G). Entry into EOP-0 is made and the loss of power to 4 KV bus 11 is addressed by actions of AOP-71.

In addition, any attempts to manually initiate AFW flow to the S/G's fail (AFAS will not actuate,12 AFW Pump will not start,13 AFW Pump not powcred due to loss of 4 KV bus 11). This results in a total loss of feed water flow (Unit 2 cross-tie unavailable) and the candidate is expected to implement EOP-3. Scenario should end when once through cooling venfied in EOP-3, Section 1 SCENAR-1. DOC 3 09/15/97 4:I8PM

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ES.301 Indnidual Walk Through Test Outline Form-ES 3012 Facility: Calvert Clifts Units 1 & 2 Date of Examination: November 17,1,77 Exarnination Level: RO Operating Test Number: 1

, lystem / JPM Title / Type Codes

Safety Planned Followup Questions:

Function K/A/G-Importance Description 1 Control Element Drive I a 001000Al13 4.0/4.2 Evaluation of PDIL with changes in primary System / Recover a parameters Misaligned CEA

b. 001000A212 3.6/4.2 Evaluation of ECP N E

2. Electrical AC/ Transfer VI a 062000K102 4.1/4 4 loss of Offsite Power in MODE 5 - cvaluation of 11/17 4KV Dus Loads from sources I A DG to Offsite Power b 064000G112 2 9/4 0 Evalitation of DG OPERABILITY requirements M A S

3. Main Feedwater / Manually IV a 059000K405 2.5'/2.8* (LER 318 95-003) Start up of Main Feedwater Transfer FRVs/FBVs Pump

b. 059000A211 3.0*/3.3' Evaluation of FRV Display with Controller Output failure D S L

4. Containment Spray / CSAS V a- 026000G132 3.4/3 8 Reason for filhng containment emergency sump piping

, Verification

, b 026000G409 3 3/3.9 Use of Containment Spray Pumps for SDC N S 5, Process Radiation Vll a. 073000A403 3.1/3.2 Wide Range Noble Gas Monitor check source Monitormg / Verify That operation the Radiation Levels Evtcrnal h Containment l

Safety Function is Satisfied j b, 073000K401 4 0/4.3 Radiation monitors and automatic functions

6. Reactor Coolant / Respond 11 a. 002000K106 3.7/4.0 Leakage location determination to a Loss of RCS Inventory While SDC is in Use

b. 005000 A101 3.5/3.6 Determine allowed RCS cooldown rate D A S L i 7. Reactor Coolant / 111 a 000011 A111 4.2/4.2 Evaluation of methods providing corre flush Commence Core Flush b 006000A305 3.4/3 9 Post-RAS cavitiation prevention D A S 8- Main Steam / Manually IV a. Ol3000A202 4.3/4.5 Main Steam isolation signals Close A Main Steam isolanon Valve b 039000K408 3 3/4.0 Partial stroke testing of MSIVs N P

9. Safety injection and 11 a. 000068A205 4.2/4.3 Determine time limit for initiating SDC Containment Spray /

Manually Initiate LPSI Flow

b. 000068Gil2 2.9/4.0 Remote Shutdown required mstrumentation C P NUREG 1021 Interim Rev. 8, January 1997

ES 301 Indwidual Walk Through Test Outline Form.ES 3012

10. Chemical and Volume I a. 004000A110 3.7/3.9 Determination of dilution that would activate S/D Control / lsolate Dilution Monitor alarm Paths l

b. 010000G132 3.4/3.8 Limitations en use of Aut Spray T)pe Codes: (D) Direct from bank (M)odified from bank (N)cw, (A)lternate Path, (C)ontrol Room, (S)imulator, (P)lant, (L)ow Power. (R)CA i

NUREG 1021 Interim Rev. 8. January 1997

ES301 Indnidual Walk.Through Test Outime Form ES.3012 i

Facihty: Calvert Cliffs Units 1 & 2 Date of Examination: November 17,1977 Examination Level: SRO-U Operating Test Number: 1 P

S) stem / JPM Title / Type Codes

Safety Planned Followu? Questions-Function K/A/O-Importance Description

1. Control Element Drive I a 001000All3 4.0/4.2 Evaluation of PDIL with changes in primary System / Recover a parameters Misaligned CEA

b. 0010(X)A212 3.6/4.2 Evaluation of ECP N S

2. Containment Spray / CSAS V a. 026(X)0G132 3.4/3.8 Rewn for filling containment emergency surnp piping Verification b 026000G409 3.3/3.9 Use of Containment Sprav Pumps for SDC N S

3. Reactor Coolant / Respond 11 a. 002000K106 3.7/4.0 Leakage location determination to a Loss of RCS Inventory While SDC !s in Use b 00$000A101 3 5/3 6 L;,crmine allowed RCS cooldown rate D A S L

4. Safety injection and 11 a. (X)0068A205 4.2/4.3 Determine time limit for initiating SDC Containment Spray /

Manually initiate LPSI Flow b (XXX)68Gil2 2.9/4 0 Remote Shutdown required instrumentation D P 5 Chemical and Volume I a 004(XX) Allo 3.7/3.9 Determination of dilution that would activate S/D Control / Isolate Dilution Monitor alarm Paths

b. 010000G132 3.4/3.8 Limitations on use of Aux. Spray N P R Type Codes: (D) Direct from bank, (M)odified from bank, (N)cw, (A)lternate Path, (C)ontrol Room, (S)imulator, (P)lant, (Liow Powct, (R)CA I

l .

NUREG-1021 Interim Rev 8. January 1997 l

l

_~ .. _ _ . --

ES 301 Individual Walk Through Test Outline Form ES 3012

Facihty: Calvert Chifs Units I & 2 Date of Examination: November 17,1977 Examination Level: SROl Operating Test Number: 1

~

System / JPM Titic / Type Codes' Safety Planned Followup Questions:

Function K/A/G -Importana Description

1. Control Element Drive I a. 001(XX)All3 4.0/4.2 Evaluation of PDIL with changes in primary System / Recover a parameters Misaligned CEA ,

I

b. 001000A212 3.6/4.2 Evaluation of ECP N S

2. Electncal AC / Transfer VI a. 062000K102 4.1/4.4 less of OfIsite Power in MODE 5. cvaluation of i1/17 4KV Bus leads from sources 1 A DG to Offsite Power

b. 064000G112 2.9/4.0 Evaluation of DG OPERABILITY requirements M A S 1 Main Feedwater / Manually IV a. 059000K405 2.5'/2.8* (LER 318 95-003) b i up of Main Feedwater Trensfer FRVs/FBVs Pump b 059000A211 3.0*/3.3' Evaluation of FRV Di; play with Controller Output failurc l D S L

4. Contamment Spray / CSAS V a. 026000G132 3 4/3.8 Reason for filling containment emergency sump piping Verification b 026000G409 3 3/3 9 Use of Containment Sprav Pumps for SDC N S S Process Radiation Vll a. 073000A403 3.1/3.2 Wide Range Noble Gas Monitor check source Monitoring / Verify That operation the Radiation Levels External to Containment Safety Function is Satisfied

b. 073000K401 4 0/4 3 Radiation momtors and automatic functions D A S

6. Reactor Coolant / Respond 11 a. 002000K106 3.7/4.0 Leakage location determination to a Loss of RCS Inventory While SEC h in Use

b. 005(XX)A101 3.5/3 6 Determine allowed RCS cooldown rate D A S L

7. Reactor Coolant / 111 a. 00001l Al11 4.2/4.2 Evaluation of methods providing corre flush Commence Core Flush

b. 006(XX)A305 3.4/3.9 Post-RAS cavitiation prevention D A S

~

8. Main Steam / Manually IV a 013000A202 4.3/4.5 Main Steam Isolat;on signals Close A Main Steam Isolation Valve b 039000K408 3.3/4 0 Partial stroke testing of MSIVs N P

9. Safety injection and 11 a 000068A205 4.2/4.3 Determine time linut for initiating SDC Containment Spray /

Manually initiate LPSI Flow

b. (XX)o68G112 2.9/4 0 Remote Shutdown required instrumentation D P NUREG-1021 Interim Rev. 8. January 1997

- ES 301 Indwidual Walk Through Test Outline Form-ES 3012

10. ~ Chemical and Volume I a. 004000A110 3.7/3.9 Determination of dilution that woaid activate S/D Control / Isolate Dilution Monitor alarm Paths

b. 010000G132 3,4/3.8 Linutations on use of Aux Spray Type Codes: (D) Direct from bank, (M)odified from bank, (N)cw, (A)lternate Path, (C)ontrol Room, (S)imulator, (P)lant, (L)ow Power. (R)CA l

i l

4 l

NUREG-1021 Interim Rev. 8. January 1997 1

I*

ES 301 Administrative Topics Outline Form-ES 301 1 )

I Facility; Calvert Cliffs Date of Examination: 11/17/97 I

s. . Examination lecl: SRO-U Operating Test Number: 1 l Adm'aistrative Describe method of evaluation:

, Topic / Subject 1. ONE Administrative JPM, OR i Description 2. TWO Administrative Questions 4 Al Fuct llanding JPM K/A 2.2.26//R2.5:S 3.7// Boron Concentration durmg refueling ont of

, specification.

1 i

Shift Turnover JPM K/A 2.1.3//R3.0.S3.4// Shift Turnover Equipment availability A2 Troubling Shootmg - JPM K/A 2.20//R2.20:S3.3// - Administrative Procedurc " Trouble Shooting & Precedure Configuration Control Controlled Activities". MN l.110 A.3 Emergency Radiation Exposure K/A 2.3.4//R2.5:S3.1// Exposure limits - Emergency Work Permits ERPIP-832 limits K/A 2.3.7 //R2.0//S3.3// Authorization of radiation work permits.

A.4 Event Classification JPM K/A 2.4.41//R2.3: S4.1// - Emergency Response Plan implementation Procedures -

Declare event and make notification (s)-

1 NUREG-1021 Interim Rev. 8, January 1997

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

~

ES 301 Administrative Topics Outline Form ES 301 1 7 Facility: Calvert Cliffs Date of Examination: 1I/17/97

,. Examination Level: SRO-1 Operating Test Number: -1 1

Administrative Describe method of evaluation:

Topic / Subject 1. ONE Administrative JPM, OR 4 Description 2. TWO Administrative Questions AI Fuel Handing JPM K/A 2.2.26//R2.5:S 3.7// Boron Concentration during refueling out of j specification.

i l Shift Turnover JPM K/A 2.1.3//R3.0:S3.4// Shift Turnover Equipment availability 4

A3 Troubling Shooting - JPM K/A 2.20//R2.20.S3.3// Administiative Procedure "Troubic Shooting & Procedure Configuration Control Controlled Activitics". MN 1 110 i

(

A.3 Emergency Radiation Exposurc K/A 2.3.4//R2.5:S3.1// Exposure limits Emergency Work Permits ERPIP 832 limits K/A 2.3.7 //R2.0//S3.3// Authorization of radiation work permits.

A4 Event Classification JPM K/A 2.4.41//R2.3: S4.1// - Emergency Response Plan implementation Procedures -

l Declare event and make notification (s) i i

i l.

9 e

i a

1 NUREG-1021 Interim Rev. 8. January 1997

. . - e- - -,----,u.-,..,w.. , . - - - -. - ~ . , - . , - . , - , -

e

0 ES 301 AdministratiIe Topics Outline Form-ES.301 1 Fasility: Calvert Cliffs Date of Examination: 11/17/97

, Examination Level: RO Operating Test Number: 1 Administrative Describe method of evaluation:

Topic / Subject 1. ONE Administrative JPM, OR Description 2. TWO Admimstrative Questions AI Mode Change K/A 2.1.22//R2.8/S3.3// Mode change Low power operation K/A 2.1.22 //R2.8/S3.3// Definc/desenbc different

MODES" of operation Shift StafTin[ K/A 2.1.1//3.7/3 8// Arca of & responsibilities concerning "At the controls" K/A 2.1.1//3.7/3.8// Maximum hours employee can work A2 Tagging & Clearances K/A 2.2.13//R3 0/S3.4// Authonzed Safety Tagger K/A 2.2.13//R3.0/S3.4// Human Danger Tag A3 Radiation work permit K/A 2.3 4//R2.5/S.4.1/ Employee responsibilitics l

K/A 2.3.2//R2.5/S2 9// Calvert Cliffs ALAR A program & goals A4 Emergency Procedures K/A 2.4.1/R4.3/S4 6/ EOP Entry Conditions K/A 2.4.17//R3.1/S3.8// Command & Control Functions NUREG-1021 Interim Rev. 8, January 1997

[. d4 e

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ES-401 PWR SRO Examination Outline Form ES-4013 l

Facility: Calvert Cliffs 1 & 2 Date of Exam: November 17,1997 Exam Level: SRO K/A Category Points Tier Group Point Total K1 K2 K3 K4 K5 K6 Al A2 A3 A4 G 2 4 NN ipg! 8 6 it s?n 4 24

1. Ppp #w%

1 L A saw?Eidg . L ;431 Emergency & i) h sk;;

xp w ve hh. (4ggspyjIkkkh Abnormal Plant Mm w~ ar N3pif ? h^ A 1 +^ W i Evolutions si M@u, i &ai v u u%r'h<a w rag :. 3 We 2

4 1 4 . A d A 3 4 % a. 16

$$ik $$e$ frkk ND $Eir

3 *@

% '"4h'l "s' l

I I #E I"SE '*MM

~ I 3 Tier Totals M. M Elker 12 11 gp om jp 5 43 5 2 3 1 1 1 2 2 2 19 2.

Plant Systems 2 3 2 3 2 1 2 2 3 17 I I i 3 1 4 8 5 3 7 2 2 3 2 Tier Totals 1 3 4 40

3. Generic Knowledge and Abilities Cat 1 Cat 2 Cat 3 Cat 4 17 8 6 1 2 Note: u Attempt to distribute topics among all K/A categories; select at least one topic from every K/A category within eacii tier. .

e Actual point totals must match those specified in the table.

NUREG-1021 23 of 39 Interim Rev. 8 January 1997 A0l b

C

.v Select topics from many systems; avoid selecting more than two or three K/A topics from a given system unless they relate to plant specific priorities.

e Systems / evolutions within each group are identified on the associated outline.

ct.^ The shaded areas are not applicable to the category / tier.

I l

N(JREG-1021 23 of 39 Interim Rev. 8, January 1997

PWR SRO Examination Outline FaC;sity: Calvert Cliffs Exam Data: 11/17/97 Examination Level: SRO Section: Generic Knowledge and Ablibes

.SRO Croup 1 System / Evolution K/A SRO KA Statement Level tJuestion Topic Conduct of Operatons 2.1.1 38 Know! edge of conduct of operatons requerements- 8 Acbons for dscovery of valve out of positon as !isted on valve line up record 2.1.1 3.8 Knowledge of conduct of operations requirements. S Requirements / approval to change logs 2.1.3 34 Know! edge of shift turnover practices. B Short term watch relief 2.1.4 3.4 Knowledge of shift staffing requirements. S Fit for duty - call out i 2.1.10 3.9 Knowiedge of condtions and limitations in the fadhty B Condtons and authorization to depart from license license. condtions / Technical Specificabons 2.1.10 3.9 Knowledge of condtions and limitations in the fadhty S Action for Safety rdated equipment having been license. determined to be inoperable.

2.1.22 3.3 Ability to determine Mode of Operation. S Low power operations 2.1.29 3.3 Knowledge of how to conduct and verify valve lineups. B inJependent position check method for throttle" vrJves ;

Equipment Control 2.2.11 34* Knowledge of the process for controlling temporary S Controll review / approval of led 1 procedures changes.

2.2.11 3.4* Knowledge of the process for controlling temporary B Bypassing nuisance alarms changes. ;

2.2.12 3.4 r<nowledge of survei!!ance procedures. B Actions required when the eperability of safety related +

equipment is found to be questionable .

2.2.13 3.8 Knowledge of tagging and clearance procedures. S Safety tagging (N0-1-112) 2.2.32 3.3 Know1 edge of RO duties in the control room during B Direct Communications TS requirement.

fuel handing such as alarms from fuel handing area, '

communication with fuel storage facility, systems operated from the control room in support of fueling ;

operations, and supporting instrumentation.

~

2.2.32 3.3 Knowledge of RO duties in the control room during B Fuel Handing Suspension - Periodcrty for inverse fuel handmg such as alarms from fuel handing area, count rate monitoring l communicaticn with fuel storage facility, systems i operated from the control mm in suppre of fueling operations, ano supporting instrumentatim t

Radological Control 2.3.1 30 Knowledge of 10 CFR: 20 and related facihty radiaton B Locked rafation areas control requirements. ,

Saturday, September 13,199710:46:22 AM Page1 !

)

PWR SRO Examina6on Outline Facility: Crivert Cliffs Exam Datx 11/17/97 Examination Level: SRO ' !

i Section: Generic Knowledge and Atwisties

' SRO Group -1 System / Evolution K/A SRO KA Statemerd Level Question Topic l Err:ergency Plan 2.4.4 - 4.3 Atzfity to recognize abnormalindcations for systam S EAL dLormination - gnren plant condtsons and ERPIP ;

operating parameters wt0ch are entry-tevel condtions 3.0 for emergency and abnormal operating procedures. .

t 2.4 22 40 Krc t& of the bases for prioritizing safety B Safety Function Herarchy functions during abnormal / emergency operations. [

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Saturday, September 13,199710 46:22 AM Page 2 i

r PWR SRO Examination Outline Facility: C:lvert Cliffs Exam Dat]: 11/17/97 Examination Level: SRO Section: Plant Systems SRO Group 1 System / Evolution K/A SRO KA Statement Level Question Topic Control Rod Drive System 001000K103 36 CRDM S CEDMCS failed hft coil 001000K407 38 Rod stops B Rod Stops Chemical and Volume 004000K116 35 Boric acid storage tank B Chargmg pump response to SIAS wdh Low BAST level Control System 004000K617 4.6 Flow paths for emergency boration B Flow paths for maximum boration E9gineered Safety 013000A403 4.7 ESFAS initiation B ESFAS Logic Features Actuation Syrtem 013000K104 4.37 RPS injection B DSS vs RPS 013000K111 38 CVCS B Chg Pomp start on SIAS wfLOOP Nue! ear Instrumentation 015000A?"3 39 Verification of proper functioning / operability B Operation of Wide Range Log channel- cps /% power System (ATTAP)

Centainment Cooling 022000A401 36 CCS fans B Automatic start failure System 022000G132 3.8 Ability to explain and apply all system limits and B Required containment fans precautions.

Containment Spray System 026000A101 4.2 Containment pressure B Effect on Containment Spray pump flows 026000A301 4.5 Pump starts and correct MOV positioning S CSS Pump alignr ent 026000G409 3.9 Knowledge of low power / shutdown implications in S Results of too low of TSP volume accident (e g LOCA or loss of RHR mrtigation strategies).

Man Feedwater System 059000A203 3.1* Overfeeding event S S/G Overfeeding 059000K416 3.2* Automatic trips for MFW pumps B Trip of Main Feed Pump Auxili;;ry / Emergency 061000K103 3.9 Main steam system B Control of steam supply to AFW Pump turbines Feedwater System 061000K201 3.3 AFW system MOVs B AFW Pomp Trip / throttle operation D C. Electrical Distribution 063000K201 31* Major de loads B Source of control power to 4.16 Ky loads 063000K402 3.2* Breaker interlocks, permissives, bypasses and cross- B DC Bus interlocks ties.

Saturday, September 13,19d710:46 23 AM Page 3

PWR SRO Examination Outline Facility- Calvert Cliffs Exam Date: 11/17/97 E=.aniiG00 Levet SRO j Sechon Plant l/ stems

^

' SRO Gmup 2 I T

Systern!Evolutior K/A SRO KA Statement Level Questson Tcpic j I

Reactor Cooant Sys*em 002000G112 40 Atwlity to apply techtscal speoficabons for a system S Apply coofdown kmrts '

002000K107 37* Reactor vessel level indcabon system

B ' S trxhatrons Emergency Cc e Cootng 006000G112 40 Atnisty to apply te:hnical speo*icabons for a system S S&.y 1.W Tank Operdmisty Status ;

System j

000000K204 38 ESFAS-operated valves B SDC hot leg sucbon valve power fadure [

t 000000K506 3.9 Reisbonship between ECC$ flow and RCS pressure B ECC Row 4 RCS Pressure i Pressunzer Pressure 010000A107 3.7 RCS pressure B Ftep change on praesure controller :

Control System )

Presounzer Level Contrei 011000K303 37 PZR PCd S Level channel fadures effect on PZR PCS i System Reector Protection System 012000A101 34 Trip setpomt adrustment S VOPT

012000K201 37 RPS channels, components, ar.d b asconnecbcss B Faded Power Supply 012000K604 3.6 Bypees-tdock crcurts S Pressunzer Prrmure Tnpintutut t Contae ant lodne 027000K501 34* Purpose of charcoal fitters B ledme remowal method Remeval 5, f AC Esectr' cal Dt -N1 34 Motor system loods B Power to RTR Trip Bkrs

[

m 'YJ0K301 3.9 Major system loads B Presounzer besters avadable on LOOP I 0620TK410 3.5 Uninterru, able ac power sources B 120 VAC Inverter Opersbon I Eeergency Desel 0854000K105 39 S7Ttmg air system B '>esed Air Start System !

Ge. arators

i 064000K402 42 Tnps for ELK 3 wtwie operating (normal or emergency) B EDG Emerg Stop Push Buttons ;

i 064000K411 40 Automabcloadsequencer safeguards S EDG opersbon dunng survedlance and ESFAS segnal i occurs 4 t

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l Saturday. September 13.199710-46 23 AM Page 4 !

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PWR SRO Examination OutEne Facility- Calvert Cliffs Exam Date: 11/17/97 Examination Level: SRO Sechon Pfant Systems SRO Group 3 SystemEvolubon K/A SRO KAStatement Level QueshonTopic Residual Hest Removai 005000K111 36 RWST B LoSIknes System 005000K407 3.5 System protecton logics, indudng high-presseve D Auto doeure of SDC hat leg isolabon valves mtertock, remet controis, and .alve interlocks Steem Dump System and 041000A406 31* Steam dump valves B SBCS status feowmg reedor tnp Tuitine Bypeos Control Inntrument Air System 078000K301 34* Containment art system B Loss of instrument Asr protecton Saturdey, September 13,199710:46 24 AM Page5

_ . . __ _ . . =.- _. .-- - _ _ . -_ _ _._. .. ___ _

_ i PWR SRO Eman?ation Outline !

Facility- Calvert Cliffs Exam Date: 19/17/97 Examination Level: SRO Sectiort Emergency and Abnormal Plant Evolubons SRO Group 1 I System /Evolutxm K/A SRO KA Statement Level Queshon Topic Dropped Control Rod 000003A105 41 r(eactor power - turbne power B Metetwng Tave/ Tref following dropp=d CEA f 000003K304 41* Acbons contaned in EOP for dropped control rod B Reactor tnp on Drapped CEA Inoperable / Stuck Control 000005A101 34 CRDS B Indcabons of a stuck CEA i i Rod I large Break LOCA i

, 000011A113 4 2 , Safety in;ection components B Att Flow paths dunng LOCA j 000011A115 42 RCS temperahre and pressure S ESF mantenance !

000011A201 4.7 Actons

be taken, based on RCS temperature ar1 S Core Hest Removal Mantenance dunng Large Breek pressure saturated and superheated LOCA Reector Coolant Pump 000015G449 40 Abilty to perform wrthout reference to procedures B Required tnppng temperatures for RCPs

[

Malfunctions those ections that require immedate operation of -

system components and controm -

Emergency Borabon 000024A104 37 Manual borat;on valve B Arternate Flowpeth if the Emergency Borabon Valve does not open. .

Loos of Component 000026A107 30 Flow rates to the -npwwa= and systems that are B Loss of air to RCP mnpw,e coolmg water return Cooling Water serv-iced by the CCWS; interachons among the hne contenment isolabon volve !

components 000026K303 42 Guidance acbons contained in EOP for Loss of B Requirement to trip on Loos of CO npm,(.6t Coc*mg CCW/nucleer service water Water gg 6 Steem Line Rupture OGG040K106 38 High-energy steam ime breek considersbons S EOPp ESDE achons followmg dryout 000040K304 4.7 Actions contaned in EOPs for sieem Ime rupture S Isolabon of S/G on ESDE l

, Loos of Condenser 000051A202 4.1 Condtions requinng reactor and/or turbne tnp B Raquirement to trip turbne based on back presstae Vacuum and power >

Station Blackout 000055A202 4.6 RCS core coolmg through natural circulabon coolmg S EOP-7; Strategy j to S/G cochng -

000055A203 4.7 Actions necessary to restore power B 4160 V feeder breeker interlocks 4 !

j 000055A204 4.1 instruments and controls operable wwth only de battery B AFW Flow dunng SBO l power available Loos of Vital AC 000057A204 40 ESF system penei alarm annunciators and channel B Effed of a loss 120 VAC on PAS and CSAS I d

Instrument Bus status indcators i i

, Control Room Evacuabon 000068A101 45 S/G atmospheric relief valve B Method of pressure contrd when evacuabng the

! control room I Saturday, September 13,199710 46 24 AM Page 6

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m.7 _ .. 1 PWR SRO ExaminsWon Oudine i ! Facility . Calvett Cliffs Exam Date: 11/17/97 Emmination Level: SRO i Sectson Emergency and Abnormal Plant Evolubons l [

SRO Group 2 l

1 System /Evoluhon K/A SRO KA Statement Level Queshon Topic i ! ' Reactor Trip 000007K301 46 Achons contained in EOP for reedor top S EOP Achon on 14 CT. Rad-l j Pressunzer Vapor Space 000000K101 37 Thermodynamics and flow crieractensbcs of open or B Indcatons of a lookmg SRV 4-Acodent feelong valves . } Small Breek LOCA 000009A201 48 Acbons to be taken, booed on RCS temperature and S ESDE vs. SOLOCA pressure, saturated and st.y.,R:ed Loos of Residual Hest 000025A102 3.9 . RCSinventory S Reduced Level De6ntions } Removd System i i I 3 4 000025K101 4.3 Loss of RHF.S during aR modes of operaborg B Effect of a loss of air to SDC valves 'I L ) Presounzer Pressure 000027A101 3.9 PZR hesters, sprays, and PORVs B Spray valves stuck open 4 ' Control Melfuncbon Steem Generator Tube 000037K307 44 Acbons coritamed in EOP for SIG tube Icek B AFWl .Josebon ! i Leek ! Steem Generator Tube 000038K103 42 Natural circuisbon B StG Pressures dunng CJD follouang SGTR l Rupturs + 1 t Loos of DC Power 000058A203 3.9 DC loads lost impact on to operate and morutor plant S Loosof Annuncestors-schons systems l 1 t 000050K302 42 Acbons contamed in EOP for loss of de power B Espected cause of a inp on a Loos of a Sofety Reisted ! D.C. Bus

;       Acadental Geseous           000000K302         3.5*    leola%on of the sumhary buddng venblabon                 B            Reiseee from WG heeder en Aux 3ide                                        !

1 Redwoote Release ' 4 Loos of instrument Air 000065A201 32 Cause and effed of low-preneure instrument air alarm B Inshanent Air Response to 4 _ ., pressure ] 000065A208 3.3 Failure modes of air-operated equipment B Method of temperature amtrol foNouang a loss of , l : Loos of Feedwater 00CE06A101 3.9 Components, and fundsons of control and safety Required Loos of Feedseter acDons booed on lever ' B i systems. indudag instrumentabon. ognals and power ! interlocks, failure modes, and automatic and manuel 4 features. 3 I i 00CE00K102 .37 .Normal,

                                                                  . . abnormal and emergency operstmg                  B             Local opershon of FRVs                                                    l procedures sesoasted wwth (Loos of Feedseter).                                                                                                  '

00CE08K201 37 Components, and funchone of control and safety B When vues Aur Food Pump stort follousmg an systems,includmginstrumentaban ogness. overspeed tnp reset meerlocks, fadure modes, and automabc and manuet 4

                                                             . features.

Saturdey. September 13,199710.46 25 AM Page 8 j , i $ I a

t PWR 3RO Examination Outline I Facility- Calveft Cliffs Exam Date: 11/17/97 Emiw.ation Level: S9 R . Section: Emergency and Abnormal Plant Evolutions i. SRO Group 3 ! Systern/Evoluhort K/A SRO KAStatement Levet QueshonTopic 1 j Fuel Hending inadents 000036A101 38 Reector bunidng containment purge venh!ation system S Hazards assocated wrth new ft.el demage s Loos of Off-Sete Power 000056A251 3.4* DeltaT, (core, host enchanger, etc.) ' S NC Row estatmhment emng LOOP ! i Excess RCS Leekage 00CA16G133 4O Atzirty to recognize indcanons for system operating S Technecal Spooficanon RCS Leekage LCO Entry i i perarneters which are entry-level condtrons for l i technical speof'catons. i t t ! l f I i I i u ! t

!                                                                                                                                                                                                          A 1

i 4 ' i 4 I i 2 i ! Saturdey. September 13,199710 46 25 AM Page 9 i l

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ES-401 PWR RO Examination Outline Form ES-401-4 Facility: Calvert Cliffs 1 & 2 Date of Exam: November 17,1997 Exam Level: RO K/A Category Points Tier Group Point Total K1 K2 K3 K4 K5 K6 Al A2 A3 A4 G 1 1 7 5 2 16 t

1. I u Emergency &

l Abnormal Plant j Evolutions d yfy 2 h j ,h " K 3 3 3 E Tier *I.otals 5 1 11 11 TT 36

g. ;f k.1@

5 2 5 1 2 1 3 3 1 23 1 2. Plant Systems 4 4 1 4 1 4 1 1 20 2 3 l 11 6 2 11 2 1 7 2 4 4 1 51 Tiu Tds

3. Generic Knowledge and Abilities Cat 1 Cat 2 Cat 3 Cat 4 l 4 g 6 1 2 Note: e Attempt to distribute topics among all K/A categories; select at least one topic from every K/A category within each tier.

e Actual point totals must match those specified in the table. e Select topics from many systems; avoid selecting more than two or three K/A topics from a given

                                                                                                                                                           . . . . A

f system unless they relate to plant specific priorities. e Systems / evolutions within each grc,up are identified on the associated outline. e The shaded areas are not applicable to the category / tier. e 4 4 4

PWR RO Examination Outline Facility- Calvert Cliffs Exam Date: 11/97/97 Examination Level: RO Section

Title:

Genenc Krcetedge and AtzIrbes RO Group 1 System / Evolution K/A RO KA Statement Level Queshon Topic Conduct of Operabons 2.1.1 37 Krc;.i.& of conduct of operatons requirements B AcDons for escovery of valve out of pooroon as hsted on vetve one up record 2.1.3 30 Krc;.i;Jge of sh:ft tumover pracbees B Short term watch rehef 2.1.10 27 Krc..t;dge of condtons and limitabons en the facsitty B Condbons and authonzabon to depart from beense license condbons / Techrwcal Specficabons l 2.1 29 34 Krc;.t;& of how to conduct and venfy valve kneups B Independent possbon check method for'throtse" valves Equipment Control 2.26 23 Knowledge of the process for malung changes in R Procedure errors and regurred approval for change l procedures as desenbed in the safety analysts report.

2.2.11 2.5 Know' edge of the process for controlling temporary B Bypsesing nursance alarms changes 1212 3.0 Krc;. ;& of surverliance procedures B Actons required when the operatshty of safety related equipmentis found to be questonable 2 2.21 2.3 Krc;.t;Jyc of pre- and post-mamtenance operabihty R Identrficehon of equipment requenng post maintenance i requirements. tesbog j 2.2 32 3.5 Krc;.tdge of RO dubes in the control room dunng B Drect Communicabons TS requirement. I fuel handing such as alarms from fuel handing aree, !

communicatron with fuel storage facihty, systems . operated from the control room in supp st of fueling opersbons, and supporbng instrumentabon. [ [ 2.2 32 3.5 Krc;.t& of RO dubes in the control roote during B Fuel Handing Suspenseon - Penodedy for inverse , fuel handmg such as alarms from fuel handing aree, count rate morwtonng ! commurucahon veth fuel storage facility, systems ' operated from the control room in Npport of fueling j operabons, and supporbng instrumentabon. Radological Control 2.3.1 26 Krc;.tdwe of 10 CFR: 20 and related fachty radabon B Locked radabon arees control requirements. Emergency Plan 242 3. 9 Know4 edge of system set pomts, interlocks and R Color Code of SPDS alarms I automabc schons associated with EOP entry l condbons Note The issue of setpornts and automabc t safety feetures is not peut (rJiy covered in the I systems sechons. , 2422 30 Krc..tdye of the beses for priontrzmg safety B Safety Funcbon:L. ey funcbons durmg abnormai/ emergency operabons f j t Saturday, September 13,199710 45:55 AM Page 1 5 f i

i 1

PVWR RO Examinadon Oudine i Facility: Calvert Cliffs ,

Exam Date: 11/17/97 E-.,;6at.cn Level: RO t i Sechon Tith: Plant Systems -l 1 i ! . RO Group 1

_ System /Evoluhon K/A RO KA Statement Level QueshonTopic

] Control Rod Onve System 001000K202 36 One-hne degram of power supply to dip breekers R Power to tnp beookers 001000K407 37 Rod stops B Rod Stops ! l 001000K406 32* Prevention of eucceerve rod movement R CPP enatde command for rod mobon (CMI) i i j Reector Coolant Pump 003000A107 3.4* RCS temperature and pressure R RCS Pressure response when startng a RCP l ] System i 003000A404 3.1 RCP seal efferenbal pressure instrumentabon R RCP Seal Failure Indcahon 003000K103 33 RCP seal system R RCP Shaft Seal HX Tube leek Indeshon and Actons 1 Chemical and Volume 004000A309 3.3 VCTlesel R Response to VCTlevel failure f Control System j- 004000K116 3.3 Bonc aod storage tank B Chargmg pump response to SlAS with Low BAST level 1 1 004000K411 3.1 Temperature / pressure control in letdown ime prevent R leremum letdown beckpressure j bodmg. hftmg re6efs, hydrauhc shock, ppmg damage. WW 004000K617 44 Flow paths for emergency borshon B Flew paths for mammum borabon

Engineered Safety 013000A302 4.1 Operabon of actuated equipment R Auto somepower on RAS l Features Actuabon System 013000A403 4.5 ESFAS inrbabon B ESFAS Loge .

I, l 013000K104 3 97 RPS injecton B DSS vs RPS . , 013000K111 3.3 CVCS B Chg. Pomp start on SIAS wfLOOP i Nucieer instrumentabon 015000A107 3.3* Changes in boron concereranon R S/D Moretor alarm i System j j 015000A303 39 , Venficabon of proper funchonmgfoperatwirty B Operation of Wide Range Log channel - cpe/% power j (ATTAP) ! . Contamment Cochng 022000A401 3.6 CCS fans B Automate start fadure ! System I 022000G132 ':.4 Atukty to explam and apply all system hmsts and B Required contamment fans

precaubons Main Feedweter System 059000A211 30* Fadure of feedwater control system R FW Regulatmg system acson on dnfbng bypoos vahre 4

l . Saturday. September 13,199710 45.55 AM Page 2 1 m _ - - s -. , . - . _ . . - . , _ _ -- _ . _ _

PWR RO Examination Oudine Facility- Calvert Cliffs Exam Date: 11/17/97 Examinabon Level: RO Section Tdle: Plant Sfstems RO Group 1 SystemEvolution K/A RO KA Statement Level Queshon Topic Main Feedweter System 059000K416 ' 31* Att.omatre tops for MFW pumps B Tr+p of Man Feed Pump 059000K418 2.8* Automatic feedwater reducson on plant inp R FW Reguishng Valves acbon on turbme tnp Aumfiary / Emergency 061000K103 3.5 Mam steem system B Control of steem suppy to AFW Pump turtunes Feedwater System 061000K201 32* AFW system MOVs B AFW Pomp Tnpithrotne opershon Saturdey, September 13,199710:21.44 AM Page 3

j PWR RO Examination Oueine - Facility- Calvert Cliffs Exam Date: 11/17/97 Examination Level: RO r Sechon Tale: Plant Systems i RO Group 2 t SystevWEvolution K/A RO KA Statemerd Level QueshonTopic ! i Reector Coolant System 002000K107 35* Reector vessel level indcahon system t B RVUS Indcatons e 002000K410 42 Overpressure proPecton R Presounzer pressure control Emergency Core Cooling 000000K204 36 ESFAS-operated valves B SDC hot leg suction valve power fadure System i l 006000K506 3.5 Relabonstwp between ECCS flow and RCS n essure B ECC w vs. RCS Pressure - t j- Pressurizer Pressure 010000A107 3.7 RCS pressure R Operation of Pressunzer Pressure Control in Manual , Control System j 010000A107 3.7 RCS pressure B Step change on pressure controller i 010000A302 36 P2R pressure R Components supplied wwth sogness from pressure control system ,

Pressurizer Level Control 011000A205 3.3 Loss of PZR hesters R Presounzer Level Control f
System !

4: , ! 011000K101 3.6 ' CVCS R Presounzer Level Control and letdown esclahan ! $ i Reactor Protection System 012000K201 3.3 RPS channels, components, and interconnechons B Faded Power Supply ! Non-Nudeer 016000K102 3.4* PZR LCS R Presounzerlevel decresee Instr smentabon System Containment Spray 026000A101 3.9 Containment pressure B Effect on Containment Spray pump flows I i System i AC. Electrical Destribubon 062000K201 3.3 Major system loads B Power to RTR Tng Blus 062000K301 3.5 Major system loeds B Presounzer hosters avadable on LOOP 1 062000K410 3.1 Uninterruptable ac power sources B 120 VAC Inverter Operabon i i i O C. Electrical Destnbutton 063000K201 2.g* Major de loads B. Source of control power to 4.16 Kw loeds J t 063000K402 2.9* Brooker mteriocks, permissives, bypesses and croes- B DC Bus interlock 2 -

bes. I Emergency Deeel 064000A107 29 Mainteirung minimum lood on EDKi (to prevent R EDG opersbon dunng survellences Generators reverse pows.r, i

064000K105 3.4 Starting air system B Deeel Air Start System l 064000K402 3.9 Trips for ED/G whde operstmg (normal or emergency) B EDG Emerg Stop Push Buttons I $ ) j Saturday, September 13,199710:21:45 AM Page 4 i t

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.l PWR RO Examination Outline Facility- L Calvert Cli#s                                           Exam Data              11/17/97                                        Examination Level: RO Sedion Tdle: Plant Systems i _ RO Group         3 System / Evolution       K/A          RO          KA Staternent                                             Levei Queshon Topic Resedual Heat Removal- 005000A1J2      3.3        RHR flow rate                                              R     RCS coo 8cown en SDC System I

i 005000K111 3.5 RWST

B LPSI knes 005000K407 32 System protechon logias, indudng tughvessure B Auto doeura of SD.; het leg isolabon valves interlock, reset controls, and valve interlocks , i Component Cooling 008000K105 30 Gources of makeup water R Sources of Makeup to CCW Head Tar

Water System j 000000K401 3.1 Automabc start of standby pump R CCW pump alegnment .

Contenment ledne 02 300K501 31* Purpose of charcoal fitters B lodne removat method Removal System Steem Dump System 041000A408 30 Steem dump valves B SBCS status foRowmg reacter tnp and Turtune Bypees ' Centrol Instrument At System 078000K301 3.1

Containment att system B Loss ofInstrument At protechen I

i . I ! i i 5 i i i ! i

Saturday, September 13.199710.22.13 AM Page5 i

                                                                                                                                                                           . . i PWR RO Examination Oueine Facility- Calvert Cliffs                                             Exam Date:             11/17/97                                         Ewisonet;00 Level: RO             !

t Sedson

Title:

Emergency and Abnormal Plant Evolubons j no stoop 4 System /Evoluteon K/A RC KA Statement Level Queshon Topic i InoperstderStuck Control 000005A101 36 CRDS B Inscaeons of a stuck CEA I Rod [ Reector Coolant Pump 000015A122 40 RCP seel failure /malfuncbon R RCP Seel Failure Regurrements [ Malfunchor's ! 000015G449 40 Abriety to perform without reference to proccdures B Regurred tnppng ternperatures for RCPs those acbons that require immediate operabon of ) system components and controis. [ Emergency Boration 000024A104 36* Manual borsbon valve B Artemate Flowpeth of the Einergency Borabon Valve ! does not open. Loos of Component 000026A107 2.9 Flow rates to the components and systems that are B Loos of at to RCP -g~. e; coolmg water return Cooling Water serv-iced by the CCWS. interschens among the kne contammentisolabon valve components ; 000026K303 40 Guidance acbons contained in EOP for loss of B Requirement to tnp on Loos of Component Coolmg CCW/nucleer service water W ater i i Pressurizer Pressure 000027A101 4.0 PZR heaters, sprays, and PORVs B Spray valves stuck open Control Malfuncbon I 000027A211 a.1 RCS pressure R Pressure channel felure Loos of Condeneer 000051A202 39 Condtons requinng reactor and/or turbme trtp B Requirement to tnp turtune booed on bock preneure l Vacuum and power j Stabon Blackout 000055A203 3.9 Actons neccesary to restore power B 4100 V feeder breeker interlocks i 000055A204 3.7 Instruments and controis operable with only de bettery B AFW Flow durmg SBO power available ! Loos of Vital AC 000057A204 3.7 ESF system penei alarm annunciators and channel B Effect of a loss 120 VAC on RAS and CSAS Instrument Bus status indicators ' Control Room Evacuabon 000068A101 43 S/G atmospheric relief valve B Method of pressure contrei when evacustmg the control room 000068G132 3=4 ' Atnisty to ernten and apply all system hmits and B Tram of components used d fire in cable spreeomg i precautions room i Natural Circulation 00CA13A103 32 Deered operating results durmg abnormal and 13 Ar*alyes of Natural Carculebon Opmabens e ,- sttuabons. !

Saturday, September 13.199710 07.48 AM Page 6 j i f

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o . . PWR RO Examination Oueine i Facility- Calvert Cliffs Exam Date: 11/17/97 E-.;nson Level: RO Sechon

Title:

Emergency and Abnormal Plant Evo8ubons [

a .

;           RO Group        2 SystemEvoluhon             K/A             RO        KA Statement                                             Level Queshon Topic i

Dropped Control Rod 000003A105 4! Reector power - turtune power B Matetung TaverTref follovnng dropped CEA j 000003K304 38" Acbons contened ir EOP for dropped control rod B Reector tnp on Dropped CEA I' Pressunzer Vapor Space 000000K101 3.2 Thermodynamics and f!ow charactensbes of open or B trxbcabor's of a leeiung SRV Acodont leolong valves i j t

;'           Large Breek LOCA          000011A113      4.1*      Safety infecbon components                                B       Alt. Flow paths dunng LOCA I

i Loos of Reector Coolant 000022A201 '32 Whether chargmg kne leak exists R Letdown kne rupture

             =~uo i

)' J 000022K304 3.2 Isolahng letdown R AcBen on Hi letdown temp. I l L me of Resedual Heet 000025K101 3.9 Loos of RHRS dunng at modes of operabon B Effect of a loss of er to SDC valves 4 Removal System j Steem Generator Tube 000037A206 4.3 S/G tube falure R SGTL vs. SGTR

Leek 000037K307 4.2 Achons contamed in EOP for S/G tube leek B AFWPisolaron f

i Steem Generator Tube 000038K103 3.9 Natural circulabon B S/G Pressures durmg C/D followmg SGTR i Rupture I l j Loos of DC Power 000058K302 40 Actions contained in EOP for loss of de power B Expeded cause of a tnp on a Loos of a Safety Reisted [

D C Bus I

I ! Accidental Gaseous 000080K302 3.3* leolabon of the auxrliary budd ng venblatKwa B Release from WG beeder in Aum. Bldg l }

           ' Radweste Reicese                                                                                                                                                              t J

, Loos of Feedwater 00CE06A101 4.0 Components, and funeons of control and safety B Required Loos of FerMer acbons booed on levei l } systems, includng instrumentabon, ognals, and power I

!                                                               interlocks, falute modes, and automabc and manual

{ features. ~ 00CE06K102 32 Normal, abnormat and emergency operatrng B Local operabon of FRVs 4 procedures aseodated with (Loos of Feedwater). [

00CE06K201 -33 Components, and funsons of control and safety B When wdl Aux Feed Pump start fbliowmg an systems, including instrumentabon, egnels, overspeed tnp reset f

interlocks, falure modes, and automate and manual i l features. t 1 - I a

t

Saturder. September 13,199710.07.49 AM Page 8 j i

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PWR RO Examination Ouaine Facility Calvert Cliffs Exam Date: 11/17/97 Ea #.atkwi Level: RO Sechon Tdie: Emergency and Atmormal Plant Em RO Group 3 < System /Evoluhon K/A RO KA Statemert Leved QueshonTopic Pressurtzer Level Control OOOO28A201 3.4 PZR level mecators and alarms R Response to a failed Presounzer Level Instrument 4 Malfunchon i Loos of Instrument Air 000065A201 29 Cause and effect of low-pressure metrument er alarm B instrument Aer Response te decrocomg preneure

!-                            000065A206 2.9*  Falute modes of air-operated equ pment              B   Method of temperature control fonowmg a Ioes of

] snetrument er i 1 i i i j a t I' Saturday. September 13,199710E50 AM Page 10 i i

u - . ,.2 - < _.7. PWR RO Exa tion Outline Facility t,atvert Cliffs Exam Date. 11/17/97 Exammabon LO AO j Sechon Tdle Genenc Krc t& and Abilities RO Group 1 System /Evoluhon K/A RO KA Statement Lev Queshon Topic 4 Conduct of Operations 2.1.1 3.7 Knowledge of conduct of upoains 6 B Achons for Jimu,,;;.f of valve otA of posbon as requwements. listed on valve ti.w up record 2.13 3.0 Krc_";$ of shift tumover piads B Short term match rehef 2.1.10 2.7 Knowledge of conditions and limitahons in the B Condtons and auhonzahon to depart from facildy license hoer 1oe condibonsi Techncal Spevhb 6 2.1.29 3.4 Knowledge of how to conduct and venfy valve B Independent possbon check method for " throttle ~ 3 I; net.sps. valves j Equipment Contrt.1 2.2.6 2.3 Knowledge of the processfor malung J vesin R Procedure errors and requered approval for procedures as desenbed in the safety analysrs change report. 2.2.11 2.5 Krc tvof theprocessforcontrolling B Bypassng niissance alarms b>pui y Ji.vas. 2.2.12 3.0 Knowledgeof surveellance procedures. 8 Achons requred when the operatdity of safety j related equipment is found to be queshonable 2.2.21 2.3 L,1& of pre-and post-ir o6 (a R Identdicahon of equipment requenng pcst operabsidy requwements. mandenance teshng 2.2.32 3.5 B Dweet CcrnmunicahonsTS requwenent. KrcutM of RO dubesin the control room during fuel handhng such as alarms from fuel i .G y area, communcahon with fuel storage facihty, systems operated from the control room in support of fueling operabons, and stwviinv 1 B 2.2.32 3.5 Krc t& of RO dubesin the control room Fuel Handling Suspenson - Fa bicity for~ dunng fuel handhng such as alarms from fuel inverse court rate mondonng handhng area, communicahon with fuel storage facihty, systems operated from the control room in support of fueling operabons, and siwuito y instrumettabon. RadiologcalControl 2.3.1 2.6 Krcutv of 10 CFR- 20 and related fachty B Locked radiahon areas radia6on control requwements. Thursday October 23,1997152-35 PM Page1

__ i PWWR RO Ex7 h OutNne i 1 Facility wivert Cliffs Exam Date 11/17/97 Exammahon Le RO Secten Title Ganenc Knoudedge aW /bitties I !

      ' RO Group          1 f

4 S i A..Cvovtion K/A RO KA Statement Lev Questen Topic i Emergency Plan 2_4.2 3.9 Krc.c& of system set poents, wilerlocks and R Color Code of SPDS # arms [ automatic achons assocated witn EOP entry

cxrdtions. Note: The issue of setpoents and ! I automahc safety features is not spedTn.Jy i covered in the systems sedians. j 2.4.22 3.0 Krc' .& of the bases fcr p o.im,g safety B Safety Ft.ts+4vi '5eraW' l functions dunng .L. u n a c, r c. ye. .cy ope.h [ i l , 1 l 1 i I L i > i i i d

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i l 4 L t i Thursday. Odober 23,19971:52-35 PM Page 2

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PWR RO Ext itiion Outline Facility wivert Cliffs Exam Date. 11/17/97 Examinabon Lt. rRO Sechoq Title Plant Systems RO Group r System /Evolubon K/A RO KA Statemerd Lev QuestKm Topic Control Roo Drive 0010008C20 3.6 One-line dagram of power supply to trip breakers R Power to trip brechers System I 001000K40 3.7 Rod stops B. Rod S; ops 001000K40 3.2* Prevenbon of excessrve rod movement R CPP enable w.... .d for rod mobon (CM:) i Reactor Coolant Pump 003000A10 34* RCS temperature and pressure R RCS Pressure response when startmg a RCP j System ! t 003000A40 3.1 RCP sea! dfferenbal pressure mstrumentation R RCP SeelFadure Indicahon . 003000K10 _ 3.3 RCP seal system R RCP Shaft Seel HX Tube leek Indcahon and i Ac2xms ; Chemcaland Volume OG4000A30 3.3 VCTlevel R Response toVCTlevelfailure Control System 004000K11 3.3 Boric acid storage tank B Chargeg pump response to STAS with Low BAST 004000K41 3.1 Temperattre/ pressure control in letdown line: R Mmwnum letdown backpressure j prevent boiling, lifting reliefs. hydraulic shock, t piping W.and burst t 004000K61 4.4 Flow pathsfor emergency barahon B Flow palhsfor mannmum borahon ; i Eini.uM Safety 013000A30 4.1 Operabon of actuated equipment R Auto swapover on RAS j Features Actuabon l System 013000A40 4.5 ESFAS initiation S ESFAS Loge 013000K10 3.97 RPS inpechon B DSS vs RPS 013000K11 3.3 CVCS B Chg Pmp start on SIAS mLGOP Nuclear 015000A10 37 Changesin boron concentrabon R S/D Moretoralarm ! Instrumentation System ! t 015000A30 3.9 Verificahonof properfuncbonmg/operatsty B Opershon of Wide Range Log channel ! I Contamment Cooling 022000A40 3.6 CCS fans B CEDM Coolmg Fans automahc operahon. System I, Thursday. October 23,19971:52.36 PM Page 3 t

FWR RO Ext ition Outline i

Facility wivert Cliffs Exam Date. 11/17/97 Examinabon Lt. RO

;      Sechon Title Plant Oy A.6 RO Group       1                                                                                                                                        ,

System /Evolubon K/A RO KA Statement Lev Queston Topic i Contamment Cooling 022000G13 3.4 Abihty to explam and apply all system limits and B Requwed contamment fans [ System precaubora j i Main Feedwater System 059000A21 3.0* Failure of feedwater control system R FW Regulatmg system achon on dnfbng bypass [ , valve ; 059000K41 3.1* Automahc trips for MFW pumps B Trip of Main Feed Pump [ 4 059000K41 2.8* Automabc feedwater reduction on plant trip R FW Rey % Valvesachon on turbme trip Auxiliary / Emergency 061000K10 3.5 Main steam system B Control of steem supp'y to AFW Pump turtynes Feedwater System 4 061000K20 32* AFW system MOVs B AFW Pmp TripRhrottle ope.abon ! 4 i . i a d i I I I i i i Thursday. October 23,19971:52-36 PM Page 4 l i !'

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PVWR RO Ext Wion Oudine , Facility- _.,1 vert Cliffs Exam Datu. 11/17/97 Exarmnabon Lt RO i Sechon Title Plant Sy A..6 RO Gmup 2 System /Evolubon KfA RO KA Statement Lev Queshon Topic Reactor Coolant System 002000K10 3.S* Reactor vessel level irxhcahon system B RVIIS Indicahons

! 002000K41 42 Overpressure pvied;ca sR Pre 5sunzer pressure M i

Emergency Core 006000K20 3.6 ESFAS-operated valves B SDC hotlegsuchon vaive power fadure Coosing system ;

006000K50 3.5 Relahonship between ECCS flow and RCS B ECCFlowvs RCSPressure ;

P'*** ,e- -- Pressunzer Pressure 010000A10 3.7 RCS pressure / R Operabonof PressunzerPressureControlin N j Control System i Manual \ ; 010000A10 3.7 RCS pressure B Step change on pressure controIIer \? 010000A30 3.6 PZR pressure R Components supplied with sgnals from pressure / t controlsystem _y l Pressunzer Levei 011000A20 3.3 Loss of PZR heaters Pressunzer LevelContrti \ l Control System - 011000K10 3.6 CVCS R Pressunzer Level Control and letdown tsolabon , i Reactor Protechon 012000K20 3.3 RPS dia.. els, uurir ici s "s, and interconnechons F Suppy i System _A 7 Norm

dear 016000K10 3.4* PZR LCS R Pressenzerleveldecrease s .

thation System C - - - Contamment Spray 026000A10 3.9 Contamment pressure B Effect on Contamment Spray pump flows

System A.C. Electncal 062000K20 3.3 Mapor system loads B Power to RTRTrip Blas i Distribubon

! 062000K30 3.5 Major systemloads B Pressunzer heaters available on LOOP 062000K41 3.1 Urunterruptable ac power sources B D.C. Eledncal 063000K20 2.9* Major de loads B Source of cxmtrol power to 4.16 KV loads , Distribubon ! 063000K40 2 C* Breaker interlocks. permesssves, bypasses and B DC Businseriocks i cross-ties. 4

Thursday. October 23.19971: 52.36 PM Page5

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PWWR RO Ext ition Outline ~ Facility _, vert Cliffs Exam Date,. 11/17/97 Examinabon Lt. RO Sechon Title Ptent Oy A..6 RO Group 2 System /Evolubon K/A RO KA Statement Lev Queshon Topic E no yo.my Desel 064000A10 2.9 Maintaming nwwmum load on EDG (to prevent R EDG operabon dunng survandiances Generators reverse power) 064000K10 3.4 Startmg air system B Desel AirStart System 064000K40 3.9 Trips for EDIG while wai.ig (normal or B EDG Emerg. Stop Push Btitors emergency) i Thursday. October 23,1997152 37 PM Page 6

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PVWR RO Ext & OutHne Facility severt Cliffs Exam Date 11/17/97 Examinabon Lt RO Sechan Title Plant Systems RO Group 3 Sy Livolubon K/A RO KA Statement Lev Queshon Topic Reedual Heat Removal 005000A10 3.3 RHR fkwrate R RCS cooldown in SDC System

005000K11 3.5 RWST B LPSIlines 005000K40 32 System oratechon loges, including twgh-pressure B Auto doeure d SDC hot leg isolabon valves interlock, reset controis, and valve L%ka.kw , Component Cooling 000000K10 3.0 Sources or makeup water R Sources d Makeup to CCW Head Tank Water System 000000K40 3.1 Automabc start d standby pump R CCW pump alignment - , Contamment todine 027000K50 3.1* Purpose d charcoalfilters B lodine removal method Removal System Steam Dump System 041000A40 3.0 Steam dump valves B SBCS status followmg readortrip and TurtaneBypass [ Control i instrument Air System 078OOK30 3.0 Crostrbed units B Loss d instrument Air protecEon ! l 1 1 5 I L 4 Thursday. October 23,19971:52-37 PM Page 7

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i _. _ _ _ _ . PWR RO Ext 1 tion Outline Facility arvert Cli#s Exam Date. 11/17/97 Examination Lt RO Section Title Ewe > =,y and Attu nd Plant Evolutions RO Group 1 System / Evolution K/A RO KA Statement Lev Quesbon Topic fragmowe/ Stuck 000005A10 3.6 CRDS B Indk:atons of a stuck CEA Control Rod Reactor Coolant Pump 000015A12 4.0 RCP seal failure /malfuncbon R RCP Seal Failure Requirements Malfuncbons 000015G44 4.0 Abilvty to perform without reference to procedures B Required tnppmg ten wahres for RCPs those a,tions that require immediate Orm obc.ni of system components and controls. Eaewn,y Boration 000024A10 3.6* Manual boration va!ve B Artemate Flowpath if the Ewa p.cy Boration Valve does not open. Loss of Cunpciwd 000026A10 2.9 Flow rates to the u.= upu e ds and systems that B Loss of air to one RCP wiycie 4 coosing water Cooling Water are serv-i d by the CCWS; intr oclu o among retum line wd m sit isciation valves - the components Requirement to trip on Loss of Cu npu. erd 000026K30 4.0 Guxiance actions Joined in EOP for Loss of R CCW/nudear service wate- r Cooling Water Pressunzer Pressure 000027A10 4.0 PZR heaters, sprays, and r0RVs B Sprayvalvesstuckopen \ Control Malfunction I

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000027A21 4.0 RCS pressure Pressure channel failure j Lossof Condensar OOOO51A20 3.9 Conditions requiring reactor and/or turbine trip % Requrrement to trip turbine based on back Vacuum pressure and power Station Blackout 000055A20 3.9 Actions riecewoiy to restore power B 4160 V feeder breaker iniern.nh 000055A20 3.7 Instruments and controis operable with only de B AFW Flowdunng SBO battery power available Loss of Vital AC 000057A20 3.7 ESF system panel a: arm annunciators and B Effect of a loss 120 VAC. Instrument Bus channel statusindicators Control Room 000068A10 4.3 S/G atan.mpion rereef valve B Method of pressure control when evacuatmg the , Evacuation , cordrol room ! 000068G13 3.4 Ability to explain and apply all system limits and B Train of u.n vcsaas used if fire in cable precautions. = vin a3 room Natural Circulation 00CA13A10 3.2 Desired operating results during oivu nd and B Analysisof NaturalCircu'ation Operations cae p a y situations. Thursday. October 23.19971:52-38 PM Page 8 t

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PVWR RO Exs itiion Oudine ~ - Facility- act Cliffs Exam Datt 11/17/97 Examinaton Lt. RO Sechon T.Te Es=yo. y and Abnormal Plant Evolubons RO Group 1 System /EvohAion KIA RO KA Statement Lev QueshonTopic Natural Circulation 00CA13K10 32 Normal, &en-4 and eney .cy Opcies B Cooldown Iwrwtahons dunng natural crculabon Operabons procedures assocated wth (Natural Ci; Aabon Operations).- Thursday. October 23,19971238 PM Paoe 9

PWR RO Ext lition Outline Facility- _ tvert Cliffs Exam Dats.. 11/17/97 Exarrunation Lt. RO Sechon Title Emergency and Abriu.uJ Plant Evolutions RO Group 2 System / Evolution K/A RO KA Statement Lev Queshon Topic q Dropped Control Rod 000003A10 4.1 Reactor power- turbine power B I id-9 avefTrer T follounng Gvwcd CEA 000003K30 3.8* Actions mntamed in EOP for Gvwed control rod B Reactor trip on Dropped CEA Pressunzer Vaior 000008K10 32 Thermodynanwes and f'ow characteristics of B Indicahons of a lealung SRV Space Acodent open orleaking valves Large Break LOCA 000011A11 4.1

Safety injection umvenerfs B All Flow pat'is dunng LOCA Lossof Reactor 000022A20 32 Whether d pg line leak exists R Letdown kne rupture Coolant Makeup 000022K30 32 Isolating letdown R Achon on H letdown temp.

Loss of Resedual Heat 000025K10 3.9 Loss of RHRS danng a1 modes of operation B Back up pumps forloss of SDC Removal System Steam Generator Tube 000037A20 4.3 S/G tube failure R SGTLvs. SGTR j Leak 000037K30 4.2 Actions mntained in EOP for S/G habe leak 8 AFWPisolabon Steam Generator Tube 000038K10 3.9 Netural circulation B S/G Pressures dunng C/D followmg SGTR Rupture Loss of DC Power 000058K30 4.0 Actions corhoed in EOP for loss of de power B Expeded cause of a trip on a Loss of a Safety Related D.C. Bus Acodental Gaseous 000060K30 33* 1 solation of the auxifiary building venblabon B Release from WG header in Aux. Bidg Radwaste Release

Loss of Feedwater 00CEOSA10 4.0 Co. iip 4.cias, and funchons of control and safety B Response tolossof feedwater pumps systems. enchsding instnsnentahon, segnals, interlocks, failure modes, and automahc and manual features.

00CE06K10 32 Normal, abnormal and emergency operahng B Local operabon of FRVs procedures assocsated with (Loss of Feedwater). , 00CE06K20 3.3 Cu. . vene.42, and funcbons of control and safety B When vnli Aux Feed Pump start followmg an systems, including instrumentahon, signals, J cw4 tripreset i interlocks, failure modes, and automahc and manual features. Thursday. October 23,19971:52:39 PM Page 10

PVWR RO Ext ition Outline

Facility: -awert Cliffs Exam Date,. 11/17/97 Exarnnabon Lt. RO Section Title Emergency and AbruiiW Plant Evolutions ; 1 RO Group 2 System / Evolution K/A RO KA Statement Lev QuestionTopic Functional Recovery 00CE09A10 4.2 Cuirpanents, and functions of control and safety R Use of dessgnated instrumentahon during use of systems, including instrumentation, segnals, EOP-8 interlocks, failure modes, and auto.natic and manual features. 00CE09A20 3.2 Facility conditions and selection of Esfy.upi; ate R EOP-8 Entry procedures during E=bruiiw and emergency operations. l l Thursday, October 23,19971:52:39 PM Page 11

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PWR RO Exa tion Outline , Facility: t,alvert Cliffs Exam Date. 11/17/97 Examination Le' AO ; Section Title Energency and At(sn-4 Plant Evolutions t RO Group 3 System / Evolution K/A RO KA Statement Lev Queston Topic ' Pressurizer Level 000028A20 3.4 PZR levelindecators and alarms R Response to a failed Pressunzer Level Instrument Control MalfuncLon l l Lossofinstrument Air 000065A20 2.9 Cause and effect of low-pressure instrument air B instrument Air Response to decressmg pressure alarm 000065A20 2.9* Failure modes of air-operated equipment B Affect of loss of instrument air on feedwater N l t i 4 k Thursday, October 23,1997 tS2 39 PM Page 12 , r

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3 PWR SRO Examint Outline F.acility- Co..srt Cliffs Exam Datz 1/17/97 Examination Levet J , Section Title Generic Knowledge and Abilities SRO Group 1 System / Evolution K/A SRO KA Statement Lev Question Topic Conduct of Operations 2.1.1 3.8 . Knowledge of conduct of operations S Requirements / approval to change logs requirements. 2.1.1 3.8 Knowledge of conduct of operations B Actions for discovery of valve out of position as requirements. listed on valve line up record 2.1.3 3.4 Knowledge of shift tumover practices. B Short, term watch relief 2.1.4 3.4 Knowledge of shift staffing requirements. S Fit for duty - call out ; 2.1.10 3.9 Knowledge of conditions and limitations in the S Action for Safety related equiprnent having been faciliti license. determined to be inoperable.- 2.1.10 3.9 Knowledge of conditions and limitations in the B Conditions and authorization to depart from , facility license. license conditions / Technical Specifications 2.1.22 3.3 Ability to determine Mode of Operation. S Low power operations 2.1.29 3.3 Knowledge of how to conduct and verify valve B Independent position check method for " throttle" lineups. valves s Equipment Control 2.2.11 3.4* Knowledge of the process for controlling B Bypassing nuisance alarms temporary changes. 2.2.11 3.4* Knowledge of the process for controlling S Control / review / approval of level 1 procedures temporary changes. 2.2.12 3.4 Knowledge of surveillance procedures. B Actions required when the operability of safety related equipment is found to be questionable 2.2.13 3.8 Knowledge of tagging and clearance procedures. S Safety tagging (N0-1-112) 2.2.32 3.3 Knowledge of RO duties in the control room B Direct Communications TS requirement. during fuel handling such as alarms from fuel hamf!ing area, communication with fuel storage facility, systems operated from the control room l in support of fueling operations, and supporting instrumentation. i Thursday, October 23,19971:59:24 PM Page 1 i

PWR SRO Examine 7utline Facility- Ca.. art Cliffs Exam Data: .1/17/97 Examination Level. J Section Title Generic Knowledge and Abilities SRO Group 1 System / Evolution K/A SRO KA Statement Lev Question Topic Equipment Control 2.2.32 3.3 Knowledge of RO duties in the control room B Fuel Handling Suspension - Periodicity for during fuel handling such as alarms from fuel inverse count rate rnonitoring handling area, communication with fuel storage facility, systems operated from the control room in support of fueling operations, and supporting instrumentation. Radiological Control 2.3.1 3.0 Knowledge of 10 CFR: 20 and related facility B Locked radiation areas radiation control requirements. Emergency Plan 2.4.4 4.3 Ability to recognize abnormal indications for S EAL determination - given plant conditions and system operating parameters which are entry- ERPIP 3.0 level conditions for emergency and abnormal operating procedures. 2.4.22 4.0 Knowledge of the bases for prioritizing safety B Safety Function Hierarchy functions during abnormal /emerDency operations. } Thursday, October 20,19971:59:24 PM Page 2

PWR SRO Examins hstline Fccility: Ca.. ort Cliffs Exam Date: .1/17/97 Examination Leva J Sedion Title Plant Systems SRO Group 1 System / Evolution K/A SRO KA Statement Lev Question Topic Control Rod Drive 001000K10 3.6 CRDM S CEDMCS failed lift coil Syst:m 001000K40 3.8 Rod stops B Rod Stops Chemical and Volume 004000K11 3.5 Boric acid storage tank B Charging pump response to SIAS with Low BAST ; 1 Control System level 004000K61 4.6 Flow paths for emergency boration B Flow paths for maximum boration , I Engineered Safety 013000A40 4.7 ESFAS initiation B ESFAS Logic Features Actuation System 013000K10 4.3? RPS injedion B DSS vs RPS 013000K11 3.8 CVCS B Chg Pmp start on SIAS w/ LOOP f;ucl:ar Instrumentation 015000A30 3.9 Verification of proper functioning / operability B Operation of Wide Range Log channel System Contrinment Cooling 022000A40 3.6 CCS fans B CEDM Cooling Fans automatic operation. Systzm 022000G13 3.8 Ability to explain and apply all system limits and B Required containment fans precautions. Contrinment Spray 026000A10 4.2 Containment pressure B Effect on Containment Spray pump flows System 026000A30- 4.5 Pump starts and correct MOV positioning S CSS Pump alignment 026000G40 3.9 Knowledge of low power / shutdown implications S Results of too low of TSP Volume in accident (e.g. LOCA or loss of RHR mitigation strategies). Main Feedwater System 059000A20 3.1* Overfeeding event S S/G Overfeeding 059000K41' 3.2* Automatic trips for MFW pumps B Trip of Main Feed Pump Auxiliary / Emergency 061000K10 3.9 Ntain steam system B Control of steam supply to AFW Pump turbines Feedwater System 061000K20 3.3 AFW system MOVs B AFW Pmp Trip / throttle operation - Thursday, October 23,19971:59:25 PM Page 3 ;

PWR SRO Examww Outline Facility: . Co. art Cliffs Exam Datz . 1/17/97 Examination Levet 3 Section Title Plant Systems SRO Group 1 System / Evolution K/A - SRO KA Statement ' Lev _ Question Topic D.C. Electrical 063000K20 3.1* Majordeloads B Source of control power to 4.16 KV loads Distribu' ion 063000K40 3.2* Breaker interlocks, permissives, bypasses and B DC Businterlocks cross-ties. Thursday, October 23,19971:59:25 PM Page 4

PWR SRO Examin' Outline Facility- C._..ert Cliffs Exam Datz 11/17/97' Examination Leve. O Section Thie Plant Systems SRO Group 2 Syst:m/ Evolution K/A SRO KA Statement Lev Question Topic R: actor Coolant System 002000G11 4.0 Ability to apply tectenical specifications for a S Apply cooldown limits l system. 002000K10 3.7* Reactor vessel level indication system B RVLIS Indications Emergency Core 006000G11 4.0 Ability to apply technical specifications for a S Safety injection Tank Operability Status Cooling System system. 006000K20 3.8 ESFAS-operated valves B SDC hot leg suction valve power failure 006000K50 3.9 Relationship between ECCS flow and RCS B ECC Flowvs. RCS Pressure pressure Pressurizer Pressure 010000A10 3.7 RCS pressure B Step change on pressure controller Control System Pressurizer Level 011000K30 3.7 PZR PCS S Level channel failures effect on PZR PCS Control System Rsccior Protection 012000A10 3.4 Trip setpoint adjustment S VOPT System 012000K20 3.7 RPS channels, components, and interconnections B Failed Power Supply 012000K60 3.6 Bypass-block circuits S Pressurizer Pressure Trip inhibit Containment lodine 027000K50 3.4* Purpose of charcoal filters B lodine removal method Removal System A.C. Electrical 062000K20 3.4 Major system loads B Power to RTR Trip Bkrs Distribution 062000K30 3.9 Major system loads B Pressurizer heaters available on LOOP 062000K41 3.5 Uninterruptable ac power sources B Emergency Diesel 064000K10 3.9 Starting air system B Diesel Air Start System G:nerators 064000K40 4.2 Trips for ED/G while operating (normal or B EDG Emerg. Stop Push Buttons emergency) 064000K41 4.0 Automatic load sequencer safeguards S EDG Wa&in during surveillance and ESFAS signal occurs. Thursday, October 23,19971:59:25 PM Page5

e , , PWR SRO Exammt Mine Facility- Cu..srt Cliffs - Exam Date: 1/17/97 Examination Level J Sedion Title Plant Systems SRO Group 3 System / Evolution K/A SRO KA Statement Lev Question Topic Residual Heat Removal 005000K11 3.6 RWST . B LPSIlines System 005000K40 3.5 System protedion logics, including high-pressure B Auto closure of SDC hot leg isolation valves interlock, reset controls, and valve interiocks Stsem Dump System 041000A40 3.1* Steam dump valves B SBCS status following reador trip cnd Turbine Bypass Control . Instrument Air System 078000K30 3.4 Cross-tied units B Loss of instrument Air protection s l Thursday, October 23,19971:59:26 PM Page 6

PWR SRO Examint Mine j i' Facility- Ca..ert Cliffs Exam Data: : U17/97 Examination Level. J ' Section Title Emergency and Abnormal Plant Evolutions . + SRO Group ! 1 System / Evolution K/A SRO KA Statement Lev Question Topic - Dropped Control Rod 000003A10 4.1 Reactor power - turbine power B Matching Tave/ Tref following dropped CEA i l 000003K30 4.1* Actions contained in EOP for dropped control rod B Reactor trip on Dropped CEA l Inopertble/ Stuck 000005A10 3.4 CRDS B Indicatons of a stuck CEA Control Rod j Large Break LOCA '000011A11 4.2 Safety injection components B Alt. Flow paths during LOCA , f 000011A11 4.2 RCS temperature and pressure S ESF maintenance ! 000011A20 4.7 Actions to be taken, based on RCS temperature S Core Heat Removal Maintenance during Large and pressure saturated and superheated Dreak LOCA 3 R: actor Coolant Pump 000015G44 4.0 Ability to perform without reference to procedures B Required tripping temperatures for RCPs Milfunctions those actions that require immediate operation of system components and controls. Emergency Boration 000024A10 3.7 Manual boration valve B Altemate Flowpath if the Emergency Boration ! Valve does not open. j Loss of Component 000026A10 3.0 Flow rates to the components and systems that B Loss of air to one PCP ccspcnsent cooling water i Cooling Water are serv-iced by the CCWS; interactions among retum iine containment isolation valves l the components 000026K30 4.2 Guidance actions contained in EOP for Loss of B RequirNnent to trip on Loss of Component CCW/ nuclear service water Cooling Water Steam Line Rupture 000040K10 3.8 High-energy steam line break considerations S EOP 05 ESDE actions following dryout 000040K30 4.7 Actions contained in EOPs for steam line rupture S isolation of S/G on ESDE Loss of Condenser 000051A20 4.1 Conditions requiring reactor and/or turbine trip B Requirement to trip turbine based on back i Vacuum pressure and power Station Blackout 000055A20 4.6 . RCS core cooling through natural circulation S EOP-10; Strategy E cooling to S/G cooling i 00005c TO 4.7 Actions necessary to restore power B 4160 V feeder breakerinteriocks 000055A20 4.1 Instruments and controls operable with only de B AFW Flow during SBO battery power available Loss of Vital AC 000057A20 4.0 ESF system panel alarm annunciators and B Effect of a loss 120 VAC. l Instrument Bus channel status indicators Thursd:y, October 23,19971:59:26 PM Page 7

PWR SRO Examins htline Facility- Ca..ert Cliffs Exam Datz .1/17/97 Examination Level ) Section Title Emergency and Abnormal Plant Evolutions i SRO Group 1 Syst::m/ Evolution K/A SRO KA Statement Lev QuestionTopic ! Control Room 000068A10 4.5 S/G atmospheric relief valve B Method of pressure control when evacuating the

Evacuation control room 000068G13 3.8 Abihty to explain and apply all system limits and B Train of components used if fire in cable -

precautions. spreading room High Reactor Coolant 000076G13 2.9 Ability to maintain primary and secondary plan! S LCO for Specific Activity Activity chemistry within allowable limits. 000076K30 3.6 Corrective actions as a result of high fissinn- S Increased letdown flow on Hi RCS activity i product radioactivity levelin the RCS , N turalCirculation 00CA13A10 3.8 Desired operating results during abnormal and B Analysis of Natural Circulation Operations emergency situations. 00CA13K10 3.5 Normal, abnormal and emergency operating B Cooldown limitations during natural circulation procedures associated with (Natural Circulation Operations). Excess Steam Demand 00CE05G22 3.7 Knowledge of bases in technical specifications S Basis for SG TS leakage Limits for limiting conditions for operations and safety limits. ;

                     .                                                                                                                                             i I

r Thursday, October 23,19971:59:27 PM Page 8 I I

PWR CRO Examirr Outline Facility: Co..ert Cliffs Exam Data: 11/17/97 Examination Leve. O Section Title Emergency and Abnormal Plant Evolutions SRO Group 2 Syst:m/ Evolution K/A SRO KA Statement Lev Question Topic R: actor Trip 000007K30 4.6 Actions cor.lained in EOP for reactor trip S EOP Action on Hi Ct. Rad. Pressurizer Vapor 000008K10 3.7 Thermodynamics and flow characteristics of B Indications of a leaking SRV Space Accident open orleaking valves Smill Break LOCA 000009A20 4.8 Actions to be taken, based on RCS temperature S ESDE vs. SBLOCA and pressure, saturated and superheated Loss of Residual Heat 000025A10 3.9 RCS inventory S Reduced Level Definitions R:moval System 000025K10 4.3 Loss of RHRS during all modes of operation B Back up pumps forloss of SDC Pressurizer Pressure 000027A10 3.9 PZR heaters, sprays, and PORVs B Spray valves stuck open Control Malfunction Stsem Generator Tube 000037K30 4.4 Actions contained in EOP for S/G tube leak B AFWP isolation Leak Sts:m Generator Tube 000038K10 4.2 Natural circulation B S/G Pressures during C/D following SGTR Rupture Loss of DC Power 000058A20 3.9 DC loads lost; impact on to operate and monitor S Loss of Annunciators - actions plant systems 000058K30 4.2 : Actions contained in EOP for loss of de power B Expected cause of a trip on a Loss of a Safety Related D.C. Bus Accidental Gaseous 000060K30 3.5* Isolation of the auxiliary building ventilation B Release from WG headerin Aux. Bldg Radwaste Release Loss of Instrument Air 000065A20 3.2 Cause and effect of low-pressure instrument air B instrument Air Response to decreasing pressure alarm 000065A20 3.3 Failure modes of air-operated eq jipment B Af fect of loss of instrument air on feedwater Loss of Feedwater 00CE06A10 3.9 Components, and functions ol control and safety B Response to loss of feedwater pumps systems, including instrumentation, signals, interlocks, failure modes, and automatic and manual features. 00CE06K10 3.7 Normal, abnormal and emergency operating B Local operation of FRVs procedures associated with (Loss of Feedwater). Thursday, October 23,19971:59:27 PM Page 9

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            ~

PWR SRO Examint 7utline i Facility- Ca..ert Cliffs Exam Data: 1/17/97 Examination Level. J Section Title Emergency and Abnormal Plant Evolutions SRO Group 2 System / Evolution K!A SRO KA Statement Lev Question Topic Loss of Feedwater 00CE06K20 3.7 Components, and functions of control and safety B When will Aux Feed Pump start following an systems, including instrumentation, signals, overspeed trip reset interlocks, failure modes and automatic and ! manual features. b I I Thursday, October 23,19971:59:28 PM Pa i0 l m

PWR SRO Examint iutfine Exam Data: .1/17/97 Examination Level.' .) Facility- Cai.ert Cliffs Section Title Emergency and Abnormal Plant Evolutions SRO Group 3 K/A SRO KA Statement Lev QuestionTopic-System / Evolution 3.8 Reactor building containment purge ventilation S Hazards associated with new fuel damage Fust Handling incidents 000036A10 system 3.4* DeltaT, (core, heat exchanger, etc.) S NC Flow establishment during LOOP Loss of Off-Site Power 000056A25 00CA16G13 4.0 Ability to recognize indications for system S Technical Specification RCS Leakage LCO Entry Excess RCS Leakage I operating parameters which are entry-level ) conditions for technical specifications. k-Thursday, October 23,19071:59:28 PM Page 11

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                                                                                                                         ,2 T* '_. ,

beiiselon TMl hLtions for discovery of valve out of position as listed on valve line up_r; cord l lDuring the p;rform:nca of a routina vrivo fina up whil) tha unit is in MODE 5, a valvo list:d es OPEN lis discovered to be CLOSED. l . I iWhich one of the following describes the correct action to be taken for this valve line up condition? MlSince the unit is not in MODE 1 or 2, an entry in the CRO log is required. l MlThe valve position is noted in the " discrepancy section" of the coversheet, and evaluated by the ' l Senior Licensed Operator. M[With concurrence of the Control Room Operator, the valve is immediately retumed to the irecommended position.

    $[An abnormal valve position tag is attached to the valve and the step is signed off as completed.                                   l hower llb I E M i[B l M"GiiiilLMernory                                 IM catvert ciarr.           IWil                       11/17/9 l hAj[1940.01G101 r

l MValeil La_7) Whl f37 hanmoil(PWG l hP9fesiPl3 WIBessisi] ca "3g W 3I [ Knowledge of conduct of operations requirements. Answer gycemmew ge-~yngnemq g ggg g g pygmq gggj gg g,y 7 g (Nuclear Operations Procedure l[NO-1200 l[5.15 ![' lf ll _] ILesson Plan llSRO 204100 ll ll ll ll22 l L l! 11... ._ il Il ll l ewageng ;

                                                                                                   -~~~..~,.,

l- i t I tu A L $v 6mGT% MBD#E t D h"}U (

M [hort term watch rel'af -l Unit 1 is operrting ct 83% pow:r. Tha RO (operttor et th) pl:nt & rc:ctivity controls) is nt:d:d in th) Shift Supervisor's office to discuss a surveillance the RO performed previously. Th3 CRO is to relieve the RO for this meeting, tWhich of the following describes the action the RO is required to perform? MMerbally brief the CRO. l Ml Walkdown the panels with the CRO. l

    $ !!nform the CRS of the meeting subject, duration, and his/her location for the short meeting.                                                        l M{ Complete all turn over requirements listed in the NO-1-207, " Nuclear Operations Shift Turnover". l i

haiiiiiiirr~lla I hiiiiiiiGiiisi!B I MGiinI(Comoreheslon lM calvert ces lg i tt17/9 l MI194001G103 l WMnsd 3.0j INROWl 13.4! %iiIsiksiIcl!PWG l MGAsisll il M l il

xw~

l tmdiniiiiiitj Knowledge of sNft turnover practices. WiEnglissiik ww p3ycMMWiyWMY Q ^g eaSWypyNWlfpg' g M 'lg?W h ?%ylrg g ~ ggftgl (Nucle:r Operations Procedure

                                                          } dO-1200                                                      l((2 )I        l{' l [N.A'.       l l                                                        ll                                                            ll.   !!        Il    ll           l l                                                        H                                                               IL  ll        11    ll           I m % g m meg YSSW$?$

_____--___-_J

Miiplel [ Conditions and authorization to dipart frrm license conditions / Technical Specifications l r unit 1 is op;rcting in MODE 3. Tha Unit's shift compi;m:nt just mt:ts tha rcquir:m:nts listrd in NO-1-200, CONTROL OF SHIFT ACTIVITIES. An event develops which places the safety and health of

 -ths public at risk.

Which one of the following is the lowest level of authority that can authorize deviation from the Technical Specifications in the interest of providing immediate protection to the public? M y,uperintendent- Nuclear Operations [ Ml Shift Supervisor l M $ontrol Room Supervisor l M1: actor Operator l hiiisiE^l!c I WWILB lIDisilliisMlMemog l M calvert chtts lMi s itt7/9 l 0

                  . . I hM L2J WM M WI M l MI il WW I il 10
                 . me ] I i

, WAmiiiiiisti I [ Knowledge of conditions and hmnatens in the facihty heense. ! M p o w e m e g g p e m y m m e rg g g g g ~j pp e g m ggr g g g g p j [ Nuclear Operating Procedure l[NO-1 100 ][4.2.C i[ lf ' 'l [ l ILcsson Plan "SRO-204100-2" ll l[ j!4 ll ll2 l INucisar Operating Procedure llNO-1201 } {5.1 C II ll Il I wisinne g g % - a w w Nj[

hiiiiibl{afigg i

M [ Independent positiors ch ck method for " throttle" valves l

 % vciva on tha ind: pend:nt position check list is list:d ts "six tums OPEN" cnd has no local or
 !r mote position indication.

yVhich one of the following describes the method used to perform the independent verification? M!The valve is not checked by a second checker. The space for the second checker on the

       ! Locked Valve Deviation Sheet for the valve in question is marked "N/A" by the CRS.

MIThe second check is performed simultaneously with the initial positioning of the valve. l NRemove the locking device and operate the hand wheel in BOTH the open and closed position, noting number of turns, and returning the valve to the as found position. Then re-install the il ocking device.

   $ The valve is listed on the Valve Lineup Coversheet as a discrepancy until the use of system 1 parameters can be employed to verify the valve position.
 "Asimerl!b IM[B_ _) NMll Memory                                                                                        l'h] calvert chfts       lg,          11/17/g ]

l M[L94001G129 rg r.m gj; l EVME:1[3J Wielusl l3.3! iMEiEl!PWG J MN!l il M l il Knowledge of how to conduct and verify valve hneups. l [SOsanseleWW ' Answw p*mm"wm3mw g gmewmmpglpr g m g 'jppv g egl g g g grgsgj

                    ~
                                               ~

[Nucled Operation Procedure lf

l503205 ~ ' ' ~ ~l[5 5.6.2 .]{11~ T I [psson Plan l!SRO-204 205-2 l f- .jl ll ll1 l [ Nuclear Operation Procedure _ gg gg m-wq l[NO 1200 l[5.11.B.2 ll25 ll lE _J NElf4eQ3 1 __J

beseelesTepisl [ Bypassing nu"an_ce alarms i IS:l:ct th2 condition wh^n compens tory actions cro NOT requirco wh:n removing a nuisancs cnnunciator alarm trom service? M 5e system / plant conditions are out of their " normal" operating range. R M! Annunciator window already has a " magenta" dot. l S lThe annunciator has multiple inputs with one or more OUT OF SERVICE. l M The alarm is not pro iding usefulinformation and has been " intermittent"for greater than thirty minutes. Assimetj[aj 'Siiiissidiel[B lbegiMis @ bMemon Ig caivert cliffs lM! 11/17/9 l M[194001G211 l M [2.5j M l .4*] M [PWGJ M5Eim]l il M l il (n,3n 4; amaniisiiiiiiiid Knowledge of the process for controlkng temporary changes. Answer pymmmmnw g g 7tgram"mqqlpp g g " g -lppy g *wrgrg g g ggqql

[ Nuclear Opertion Proced' ure

                                                                                                         ~
                                                  ~ ~l[N61206                    ~l[SiF~       j[9 ~       ll~ ~    ~l(         'l l Lesson Plan                                          j!SRO 204 206               IL          _j!4             Il    I!5.1        1 I

I[ ll_ ll ll ll. _] u%wme q i x , . i J

M hetions required when the_opegbiity.g;f_ safety,related_e_quipment j _ isAund to be questionabla l 1

  ;M:intenance in progrcss on th) 4160 di:s:1 t'us:s pt:ces tho op;r:bility of a LPSI pump in
  !qu:stion.

The correct operator response for this condition is: M 5nform

         ;       the Manager - Nuclear Engineering Department to verify the engineering configuration is Within the governing bases.

M!an appropriate entry in the CRO's Shift Turnover Information Sheet. l

    $ ! inform the Shift Supervisor to determine operability.                                                                  l M!infoim the Maintenance Superintendent to have work order prerequisites reviewed.                                         l
 'anisiil[c__J MnmWaud[B-~l MaiW!dLW5d[Comprehesion                       lg cetvert chffs       lMi                   11/17/9 l dl193001G212J WWI LLO) WWI L33 MI hW_G_j MI ilIIRilitiiiiisIl il h
                  , Knowledge of surveulance procedures DelenulkiiiiR '

4 Answer pnmer yw=mgymmm""Tl UFMaessiiiiiiiiiiW"j REM"PTj f@MM g EEN/l ~ huclear Operating Prcedure l[NO 1200 ' } [5.12A _jI }[ }{ ' } 1 1 esson Plan l[SRO-204-100 2 JI ~l[5 ll ll19 l l Il If~ ll ll ll I mwg_w n , NENONId3 a

M] [ Direct _CommunicationslSgquirement. __ j

   'During rciueling op; rations, which ona of the following indicat:s the periodicity for d:monstrating dircct coc,munications between the Control Room personnel and the personnel st tho refueling                                                                 ;
   .st;tions?
                                                                                                                  ~ ~

5]S hours

_ ] l 1]l8 hours R Ml12 hours _ l

     $!24 hours                                                                                                                                              l bismisl[c lM[B                       l Nj LMemory                                       lJM calvert cliffs                 l@                    11/17/9 l Mi194001G232 l M [3.5J M 13j M IPWG l MI ij Mi 1l timmiiiiRWhteiiiMI i                                                                                                                                     l Miiiiiiiiiial                                                                                                                                              I Knowledge of RO dutiea in the control room dunng fuel handling such as alarms from fuel handling area, communcation vdth fuel stora' peility systems operated from the control room in support of fuehng operations, and supporting instrumentaten.                              l
                ~

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                   ~          ~ ~               ~ ~ ~                       ~ ~ ~ ~

puil Hhndling Procedure lIF5250~ ~l Attachment [40~ ~ ~ ~ ~l f~ ~ l I ~ ^l 191A.9 l Technical Specification 3.9.5 ll ll ll ll ll l [ Lesson Plan llCRO-113-6 ll Il ll l[2.0 l

 ' g g g m h m m mrl                                                                                                                                        l 4

j J e 4/4 f

bTaiskl het Handling Suspension P:nodicity for inverse count rate monttorina l

 ' Fuel handling h s be:n suspend;d at 0135 hours dua to m: chine probl:ms. As th;sa difficultics
 !centinue onto the day shift, which one of the following indicates theperiodicity for monitoring 1/M7 M}2 hours                                                                                                                                           l M!4 hours                                                                                                                                           l M[8 hours                                                                                                                                            l d(12 hours                                                                                                                                           l
 ' Answer 1O issisGis][B           l M "IGIeIl[Compreh_esion                           l'Fssittr.l calvert cliffs      j'eii^Ml:

e 11/17/9 l M[194001G232J % Wha *Il I3.5I WSessiil [.3.3j ' 85s81*sul IPVjGJ LY9sowl { il Wbumusll il

           - , 22 g 3dLNiematil                                                                                                                                             I Kno# edge of RO dutes in the control room dunng fuel handhng such as alarms from fuel handung area, communcation with fuel stors' w,,,..,.
               . pcMygystems operated from the control room in support of fueling operatens, and supporting instrumentation.                             l Amiswer pwenwpnmpgrggymwmy=mq j rygggg j pgg syj [gg >q gyprl                               '

[uil Handling Procedure l/H210 ' ~ l[5[5 ~l[~][12 _ )[ ' l[ ' l [Lcsson Plan l jCRO-113-6 ll _j l_ ll ll2.0 l

 }                                                                 ll                          lL                   il           II          ll          l
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1 1 4 l

M [ Locked radiation areas I "Any crea at CCNPP cccessibl3 to individuals, in which rcdir. tion lav;ls could r;sult in cn individu:1

   ;rcceiving an Effective Dose Equivalent (EDE) in excess of 10 rems (11mSv) in one hour at 30 cm (12
   ' inch;s) from the radiation source or from any surface that the radiation penetrates."

To which one of the following does this definition refer?

       $very high radiation area.

l. M!an exclusion high radiation area. l

      $[a radiation area.                                                                                                               l Mb radioactive contamination area.                                                                                               l MiiiiEFI)_Ja* isiiiMi[e              I imiimV fiMis i Leompanesion lM c.iveri entf.

IMr s iti7,9 i d[194001G301 l %IIMl[23! 5N6 Mis:l [3.Sj 'SeiiiiiisI[P.WJG M I il d l il hiiiiiiimiaMliinhel I l JmLadiEiisi I [Knowtedge of 10 CFR: 20 and related facility radiation control requirements

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ggg3gl , [ Radiation Protection ~ l[RP-M00 ~ ~ ~~ l 3.0 [1F~~~~l f ~lf 1 l pEFINITION , lG:ntric Orientation Training llModule 22 If' Rf ll l!N.A. l l }l ll ll Il Il I unensneewswWe Mv";l l 85N$h@IE$

M [ Safety Fulction H'crarehy c l The Saf:ty Function Hi:rcrchy is divided into six prioriti:s. Wh t is the third priority safety function? ! MCore & RCS Heat Removal l kRCS Pressure & Inventory l MR6diation Level External To Containment l MIContainment Environment l M [b _ J M [B l MM]! Memory lW carvert chffs lM! 11/17/9 } M[1.94001G422J M 10j M 10j M IPWG} M l 11 M l il MMl l l hamemal Knowledge of the bases for pr6ertttzing safety functions during abnormal / emergency operatene. M pram m yppe g g ymfrwyvverjgr g g r g ]p;gr g q1 g g grgygg

                                                                                    ~ll
                                                                                ~                ~

[Lcsson Plan SPDS l[CRO-69-5 2 ~ ~ll- lf l[LO#1) I 11 Il jl ll 11 I I il ll' lL ll Il I wswasiwamesses.se em?t l hk$

M [ Rod Stops l Giv:n tho following:

    - A Unit 1 reactor startup is in progress.
    - The Reactor Operator is withdrawing Regulating Group 1 CEAs in the MANUAL GROUP mode.
    - Regulating group 1 is at 120 inches.
    - No CEA deviations exist.

i WHICH ONE (1) of the following will be the FIRST to automatically stop CEA movement? Meghest CEA reaches the Upper Group Stop (UCS). l M! Lowest CEA reaches the Upper Group Stop (UCS). l M[ Highest CEA reaches the Upper Electrical Limit (UEL). l M{ Lowest CEA reaches the Upper Electrical Limit (UEL). l Ml[b_jM[B l NEids'MIuillComprehesion l@ calvert cltfts jg] 11/17/9 l M[001000K407 l'MjSil:][3] M 18j M[SYS I MMdll ilMi il

 'hfulpl l Control Rod Crive System I

(Knowledge of Control Rod Drive System design feature (s) and or intertock(s) which provide for the following-Rod stops kaplanteGi l an - y g mmm ermaw g g yymmmme*[gy g g-' g jpgpv g w rl[ g g g g ynyl

[ Control Element Drive Lesson Text l[CRO-60-1 10 ~l[ ~l[47 ~~ l[~ ~ l[11.2 l i Il Il 11 ll ll 1 l ll 11 ll ll a_w wwrn ll l I55$$E38$$$

M [RVLtS Indications ) ilf the Re:ctor V:ss:1 Lcv:1 Monitoring Syst:m (RVLMS) indicat:s s:nsors 1 through 5 are lit, which !one of the following_ conclusions can be made? M!The entire core is voided. l MRCS levelis at or below the Fuel Alignment Plate. l 3d! Sufficient inventory exists to support Shutdown Cooling flow. l M!The upper head region above the ccre is full. - l inusieur j[C] MMl[B l!8E5MIIWuWeij[Comprehesion 1Fieets:lCalvert Cliffs lM 11/17/9 l M[002000K107

    ,e-  n , g-l '90WIue:I L.5*J Wiiiilissl I .7*l M] (SYS I MJ L2j M L2j MMd [ Knowledge of the physical Connections and/or caute4ffect relationships between Reactor Coolant System and the following yactor vessel level endication system pmerwmwp g gwem m meselp g g g 'jpp g wl g g g ggyl
                      ~          ~~      ~
                                                                            ~~                                          ~~

[InCora Inst. Sys ~l[CRO641-7 'l[ ~~~ ~ ~ ~ ] I24,25~ ~] E~ ~ lI4.0b ~} !OP-7 }l ll Table 1 il ll ll l i !I ll ._j l ll ll l < m % gwww s j j M }IElR$2 i _ ------- J

hhilij LCharging pumplesponse to SlAS with Low BAST level _] Charging pumps ara running on Unit 1 cnd cn SIAS is pres:nt. (Assums no op;rctor action) l Wh:n the BASTS are emptied, the charging pumps will: M hip on low oil pressure. l M[ trip on low suction pressure.

M[:utomatically align to the RWT. j

   $! continue to run and become gas bound.

l

'Amenet lid l MidniMl[B                                                         ] WIGiiidlLApplication           lM calvert cliffs               l'h*:j           11/17/9 j d [004000K116                           l M l3.3 M M M [SYS I Mll ilMl il RNtiiniSiUIW0i4%j [ Chemical and Volume Control System l

M Knowledge of the physical connectons and/or cause-effect relatenships between Chemical and Volume Control System and the follo~ Boric acid storage tank gymmymmy g g;mmeer~glp'% g g>jpeg7 egg -

                                                                                                                                         ~
                                                                                                                                                        ,g gy:l

!cvcS Lesson Man ~ ~ 1[crio.10f 1T lF 'i[3s T ~ l[iT1.41 I il IL "lj 11 11 1 i ll IL ~ll 11 li I mwgarum 3 3 khkNMIN55

  'M Xow paths _for faaximum boration l

Which on3 of tha following d:scrib;s tha prop:r positioning of valves in th) CVCS systrm on SlAS

  .that will allow MAXIMUM boration flow?

Th3 flow path for maximum boration is created by flow from the Boric Acid Storage Tanks (BAST Tanks),: Mthrough the gravity feed valves, through the Boric Acid pumps, through the Boric Acid Strainer, shrough manual boration valve CVC-174, directly to the Charging Pump suction. dbypassing the gravity feed valves, through the Boric Acid Pumps, through the Boric Acid l Strainer, through CV-210Y, directly to the Charging Pump suction. Mif5iough th 'oric Acid pumps, through Emergency Borate Valve (CVC 514), directly to the Charging knp suction. dthrough the gravity feed valves, through the Boric Acid Pumps, Emergency Borate Valve (CVC-514), directiy to the Charging Pump suction. j$aeweric l enii&Gs4I% l'h.]bplication l#siesiip:lc.ivers chef. lM isn7g M004000K617 l MMIl4.4! IIn00elin:l 16' 4esteEl LSYS_j WiWiisiill 1l W95siisll 11 tyeesneftinhasseiMI ! Chemical and Volume Control System l l(&h:l Knowledge of the of the effect of a loss or malfunction on the following will have on the Chemical and Volume Control System: 1 Flow paths for emergency boration Esplanecien of Choices a,b,c offer varying incorrect flow paths. Apower i peggenepw gg> tm nw zJ pygg gggggwtj gggg gpgl [CVCS Lesson Text ~ }(CRO-107-16 ~~ ll l[OH34Ci ~)I~Rf2.0.3_] l ll IL B ll ll 1 I Il ll ll Il II l

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I M1@l863 i

                                                                                                                                         . _ _ _ _ _ _ _ . _ _ . . _ _ _ .         J

M [PSilines l l Low Pressuro Safety inj2ction pumps rceircul; tion valv:s SI-659 cnd SI-660 aro m:nutlly clos:d on

  ' RAS actuation.

iWhich one of the following is the rvason these valves are closed? 1lkecirculation flow is not required for pump protection since the LPSI pumps are tripped on RAS. _] 1l Prevent release to the environment of activated airborne particles from the containment sump hater via the RWT vent. MEnsure NPSH for LPSI pumps following RAS. l MEnsure maximum flow of water to the RCS. l M"[b j S M IB l MMl! Memory lg calvert chtts lM 11/17/9 l M[00J000K111 l MMI[33 WMI [3g %seWissi!SYS I Ml 3' WMJ l 3! h.M Knowledge of the physical cr.,nnections and/or causedffect relatonsNps between Residual Heat Removal System and the following-RWST _ W it m w-ypewtym*mygg,gii ,js;;wywww9wgl yggiijen,mg-l F56iiiiiiiiiiPT"l IMM M U5Mj ~~ [ECCS' Lesson pun l[CRO-7-5 8 ll l[38-~ }I R(31.5 ~l I Il Il ~!! ll ll l l ll lL ..11 11 Il I _mymwg .; hEEMEiMid

, MM huto cjosure_pf SDC hotfg isolation _yaly0s _

[UnT1ToiSDC wh:n RCS prcssuro in:dv:rtently drifts up to 350 psia. Wh:t cutom tic functions Rill rptectP the SDC system from overpressurizing? M SDC suction line relief between SDC return isolation valves,1 Sl451 MOV and 1 Sl452-MOV,7 hill lift toprotect the return header.

                                                                                                                                                                 ~
                                                                                                                                                                             ]

kOperator action is required to reduce RCD pressure and protect SDC system. j M I PS_I pump _s will trip _ and their discharge check valves will shut. j MSDC return isolation valves Sl451 MOV & Sl452 MOV shut and SDC suction line relief wil 30 protect the return header. l MDT_] W[B ~ l h!!aedNdedComM.chesion lg calven ces jhj ~ tin 7/91 M005000K407Zj M [32 WM:1 [3 fj l!!ge r j M S ] d 3 d L 3' I ..I .$ Y hesduaj_, Heat RemovdSy; tem j ! M M [ Knowledge of Rcodual Heat Removal System de61pn feature (s) and or inledock(s) which prove for the following l

                                      $l'!'_*I@3f_C3'ED $9$'; $')?.df9IO.h; pressure inledock, retet Lantrols, and valve intedocks
                                                                      ~

p,,- g; sg % g g % g., . g g.,, ,.g ECCS Lesson P_1.an _____ JCRO-718 ll 81 ll_ j(17 l 5A[$$$ rE $ $_-5 $ $ . [ --lI II II-- J L me- .>-1 _r ll C____tE_7E_,)J 1 4 6 b .i..c. , , .

           'BanHpDeltl [SDC hotleg. suction _yatye power failure l

Un a loss of the "11" 4 KV bus, which ONE of tha following occurs preventing cith:r trcin of Shutdown Cooling {SDC) from beingplaced in service on Unit 17 M[One SDC HAtle~g~5detion Valve is de-energized.

                                                                                                                                                                                                                  ~T~~ ]

i MfhTSDC Temperature Control Valve (CV 657)_is de-energized. l (One Low Pressure Safety _ Injection Headerisolation Valve in each train is de energized. j M[The SDC Heat Exchangor Bypass Valve (FCV-306) falls closed due to a loss of instrument Air. l d '.a_j h [BR bus 88 stiegg!j LApplication 1 lMi;ehert cins lM; 11/17/9 j d!006000K204 l hMR!l[3g d [3g M [SYSJ BR.9hildlL2j knahiinlL2; i

                                                        @ergencyftore_ Cool!ag_Systern                                                                                                                                    7

[KhoWlodge of electrical power suppies to the fol60 wing lESFAS4perated vetves

n. -

l e. ..d y mm .r%gn,-,,,,,q, , ECC_S..l.esson Plan _ l[CRO 718 ) [.. ... . ..._... }[8 2,8 3 l{ l[30.7 ] L__ ._ _ ___ ]f "g j = g y g ; f. mas,wn __ _g[ y = =q g y' -- J a, 1 l i

_ . - . __ _- - = -_~ . - - - - - . --- - --- -- .----- BlinqLeslefjde I,EC6Elow vs. RCS Pressure

[Following a LOC 4, RCS pressuro is at 1300 psia and dropping. I Which one of the following state _ments describes the expected status of Sl flow?

                                                                                                                       ~ ~ ~ ~ ~ ~

M HPS,1 figw exists with no LPSI flow. l d kH51 or LNIffow exists. l M increasing HPSI flow exists, no LPSI flow. l MConstant HPSI and LPSI flow exists. i l

  *IE]tussehlf lW[Comprehesion ]d CeNert Citfts                                                                 lM                             11/17/g]

M[000000K500___J M M M [3g M [SXs_,.j hiesialL2j 'nha.minnel L2' mergeDCy_Cofe Cooj!ng System l [ Knowledge of the operational 6mphcations of the following concepts as they opp 4 to the Emergency Core Cochng syste [ Relet,onship tjetween ECCS flow and RCS pressure Aftswet

g .y.. ~.:,- g wr m, . . 3p g ..- sw g,,y. gg

 .ECCS Lesson Plan __                                       }[CRO 718                ][.       _ ._ , .j [28                           ll   l[28.3 ]

b_.--. ._ _. _..- } _ _._.- _ _ . b. .. . . ib b II l m w ,e. % T- - I MWis2212

M bep_changelnpressure controller j fhe following plant conditions Cxist: i Steady state operation at 100% power. The PZR pressure Selected Controller setpoint is inadvertently changed to 2360 psia (step ch:nge).

     -Pressurizer pressure control is in automatic.

LWhich one of the following will be the IMMEDIA_TE response of the system? _ [ Power _ operated relief valve RC-402 OPENS and proportional heaters go to minimum. l MFower operated relief valves RC-402 and RC-404 OPEN and spray valves OPEN if previously closed. M [Sp_ ray valves OPEN ifpreviously closed and proportional heaters go to minimum. l fjpray valves CLOSE if previously open and proportional heaters go to maximum. __ _J M[d]M[B l Dean!!b!t.hel!d.1LApplicalion ld ceNert clans 1 11nno } M[01000_0A107 ] WeWesue:l L3 7j Wwatus:1 [3)) M [5YS_J M[_2; '940emej{r { ti_2 . ^ ~ :-1 teel [EressurizetPEssure_ControLSystern I Matanueltd [Abuy to preAct aneet monnot changes in parameters associated with operating the Pressuruer Pressure Controt System controls ~ pnclud t ng;_ [RCSyryssurf endensmenet ' ane== p,y,,ym [r gm..mmp y g p gg , ppg 7,,s,g,,,,,Ogg g,7 s g scSinstrumentation l[CRO 6218 ll ._ . l[OH 20 ' __jl l[6.3b l E-- IE E ji n 1[ ] . % ,, _mi- , BW!MistM

M ECled Pow;tSupply _ _ l %ich one of the following d:scrib:s the rpsponso to a loss of 120 VAC Bus 117

                                                               ~                                  _

j M[OFOnit 1, a loss of power will occur to 1/2 of the CEDMs. l l M[O3it i reactor trip. l M RUnit 1 & Unit 2,4 Trip Circuit Breakers will open. l 1 (On Unit 1,10 RPS Channel A trip units are tripped, j hinuntlid J d ',8 I hsktEhl5pplication IW ceivert cin. IW< iiii7to } dio12000K201_j d [38 M [iJJ d [SYS_1 M L2] h L2: Mnl [Res.ctor Protection _ System j

IKnowledge of electrical power suppies to the following yPS channels, components. and interconnections p qgemg-em gnemv-emjyg g gjpmg-gg g gs.~;, g lRPS Lesson Plan _ j[CRO-591 11 j{ lM,46 ~ ll

                 ~                                                  -                                l[9.03     }

F 11 T~ ll JL ll I { . , , .. j _JE 1Fl 1F- _n 11 1 beinMiES

          'Allti!(goVM .ESFAS Logic I

Ttmoving an ISOLATION modula from one of the Engin:crcd Safety Fcaturcs cabin:ts places tha k,

         ' OGIC_ modules 1ogic in:

M;1 out of 3

~~

_] M[2 out of 3 [ M(1 out of 4 l

         'Ammuur llbj bWl[0                                                   l '$esudlituiMlMemofy                    ld calvert chn.        lM!                        11/1991 d[1}660A403_J M [M hil#Valueil l4.7} M FYB MI ilIM { 11                                                                               ~

hustleiGuillWeaWile! Mneered Safety Features Actuation System Mh$ ,IAbilty to manuap operate y

an$or monitof in the cofittol room.

[E SF AS inRetion I AttPr . y3,,. r - ,wm..-

q. g j g g.. <g ;-.

[ESFAS Lesson Plan _ ,,__ j iC RO--63 1 7 j[19 _] [_ _ ._ . _ J{ ][1.2.b l

                                                                                                                                   =                      - - - - - - -

L: . :~~~ _ , ~ , , - __ L.= _. . _ -. - . JL :.l f - Y ][ l q

                                                                                                           . - ' -.  ~k-

Bunsen!iMI ID51.ys3PS

[The Diverse Scram Syst:m (DSS) cecomplishes a roccior trip signalind:p nd2nt and div:rse of ths Reactor Prote_ct. ion System (R_PS1by:

       ~           ~

MITr'ipping Engineered 5afety Features Actuation System (ESFAS) input parameters which are [ independent / diverse of RPS. M[Using non safety related control channels for inputs since RPS uses the safety related channels. l M $pping the reacW by opening the CEA MG set input breaker through the ESFAS. l M[ Tripping the reactor by opening line contactors upstream of the Reactor Trip breakers which t RPS opens. MU d;B l M LComp.reheslon lg calvert chffs lM titifiel MIO13000K104 e v _l M @ M [ 3?j Ngdgiul [SYSj M l il M [ ._1J

          """ Mil [ Engineered Safetybatureslcluatto1 System                                                                      j R&h$ [ Knowledge of the physical connettens enior cauto-effect relatenships tatween Engineered Safety Features Actuation System andi
              /El.D*l"9.                                                                                                               t SPS,{ycten  = _ , -                                  _,_,.
                                                                                                                                       ]

r ,- ,,,,,,,,, , m m _ i o . ,m ,,,,,, ,, , w y (SFAS Lessgn Plan _- . - - - . __j fCRO-6317 jl l[OH 34,34A ll l[1.2a l _ _ , - _3 7..-.. L __]F JE jl ll JI I mm w e >1 .]

                                                       $M$93u

1 emensavestil [Chg Pmp starlon SIAS w/ LOOP _ l l Which one of th] following d:scrib s th3 responso of the Unit 2 ch rging pumps following r:c:ipt of Ign_autornatic SIAS signal, coincident with a Loss of Offsite Power? M One charging pump is automatically started on each emergency bus 10 seconds after it is knergized by the diesei. MlAll chargingpumps are automatically started immediately after their respective bus is energized.l d fhe operator must manually start one charging pump on each emergency bus 5 seconds after it js energized by the diesel. d One charging pump is automatically started onto each emergency bus immediately after it is pnergized by the diesel. M DJd[B l MMICorpptehesion JM calvert cierfs Ihj i 111 6 97 d[013000K111 l b W $I [3 g W E :I [31 M [S18 J M L 1) WM l_1) WMI [Engineere.d Saf.ety FeaturesActuation System l MA ! Knowledge of the physical connectone and'or cause.efrect relationships between Engineered Safety Features Actuation system and t 4&?1"9 kY_cs _ _ _ _ assasnamen et Answee gr , ,

                           . g,, _              7g                                 . gg                               g
                                                                                                                                          ,.q

,ESFA_S Lesson Text _ j[0RO-6317 )(_ l(38 }l l[1.Sa l [ lE II.. .ll l[. ll I E

~~~

IL_ IL ._ JI 11 11 I m w n.w i.,em - 1 i Nei#M!stZd

'Anuhtiltidd [ Operation _off fde Range.t.og channe.! l lDuring recctor st:rtup, pow:r is rcis:d to th] Point of-Adding H:st. All Wide Rcng) Chann:Is cro ! indicating approx.1%. The Operator-At-the Controls observes power range indication at 4%. l [What action is required by OP 2 " Plant Startup from Hot-Standby to Minimum Load"? dContinue the reactor startup per OP 2, indications of proper overlap have been verified. l kContinue the reactor startup per OP 2 and declare MODE 1 at 5%. l YStop the reactor startup. Observe linear power indication on 1C15 to determine proper Nl fresponse. kStop the reactor startup. Observe Wide Range indication on 1C05 to determine proper NI lesponse. M licJ Weistiniell B l'esimisl4siilLApM. cation ld ceivert clrns lM i1/17/o l M[0}$000A303 l WDWenuehl[3g IBRD%dpl 19) M [SYSJ Ml il 1929Seempll 1l DETMiltial huglearinstnamentation System 1 "Abliny to monnor automate operations of the Nucleer instrue.1entaten System including Venfication of proper functioning' operability taptenssion of Ameeser pm m gwymm - ~, g ryg g 'g yn- gg g,y g [NIS L sson Plan l[CRO-571 11 l [ _... _....._... j (2 7 ll l[2.2 l [ ll l l .. .jl ll ll l f___,. , JI _ _lL ..j l _ 11 Il I .%g ..7 j WMM19D

emannedsels] [CETMTCroling Eans automatic _operat. ion. J I55ich one of tha following is tho reason that CEDM f:ns cro operat:d wh:n RCS 1:mp:ratures aro l:ss than 300 F during EOP conditions?

M }3inimize the build up of condensation on the CEDM windings. l

diid_in the collapse of voids that may have formed in the RCS during the event. l M Aid in the cooling of the containment atmosphere during the event. ]

     $ Minimize the buildup of condensation on components, other than CEDMs, attached to the vessel Lh .ead.

Aasaw I bJ tasiblEB 1 hWl!Aem.ory I,W caiort ciert. lW iiiirg d[022000A401 I W L3A M L3A: W [srs._j Wl il hinomil il Am!bummushanih] [contalrlmentcookng system

Abuy to manually operate entor rmnitor in the Contf01 f00m. CCS fans Aamset y-en, r. .n g ww wg gne l( ,gp m. g g.g l ! Cont. Vent. Sys. Lesson Plan __jpRO-113417 IL _ _ .j !2_s ll .jil.4a_J i .__

                                                          ][ .--                 _ __ ] l..

7

                                                                                                     ][_       l L ..      ll        I
.%_                                      ,,4 7           7_-

j P ,iss Vist D

M hequired contal.nment fans 1

   " Unit i rcccior power is 82%. Recctor Cavity Cooling fan 11 is in s:rvice when it trips dua to
   'cl:ctrical fault.

lWich ine of the following describes response,if any, of the remaining cooling fan? M[utomatically start after 10 seconds. j M hust be riarted manually within 30 minutes. l M [must be started manually within 45 minutes. ]

MIcutomatically staris. l hammadid_J Mississiiiidh IhiiiiisaisiiiiiidMemory Igc ivericun.~ lhainead itnml M[022000G132.__] kd [3f W [3=8] hada'ad [SYS If 'R9fisll 11 h jl il MWeissWNheisWeil [Cp_nlainrnen1 Cooling. system l M g, io ..,1.s. .,,,s .,.i.m w. . p,.c... ._ _ ga ~ ~ 7.,,,-,,,.,,, c g.y.: .m m,y,q .p ,, g g g l [Containmen.t Coohng 1.esson Plan p _ -._ __. __j(CRO 13417 ll ..

                                                                                                          ![28
                                                                                                                       ]l               l[2.6     )

_ _ -3

                                                                    . v. 2

M [Effect_on Ciontaln.rrentl3 pray.pumpfgwp J [Nincrease as control valves in the Spraf header slowly thr result of changing _contain_ ment. pressure.

~~

M decreaie becauselontainment pressure presents less backpressure to flow durin~g~Ihiinjection' lphas_e,of containment Sp ay actuation. M IInc7 ease because Containment pressure presents less backpressure to flow during the gecirculation phase of Containment Spray actuation.

M he~cr~ ease because Containment pressure presents less backpressure to flow during the [ recirculation phase of containment Spray actuation.

answw 1O assutewilEB l'essasWeslovelliComprehesion ld.c.ivert ciert.

jM~ 1169] d[0i6000A101_J 40Valen][M 420Vatw:l [Q $seWoml 35S] W L2) W Ol ?_J-. t ' ~ 7'111sl [Contalnment. Spray System I bility to predict and'or monitor Changes in parameters associated with operating the Containment Sprey,f

                                                                                                                       $ stem Controit including

, $ "'*'"*'"10"E:===. - _==-- ----=___m= a p ,,y m.n. , y ye , . g' y y e. g w LECCS Lesson Plan _ ________j [CRO-7 1 8_ __ j [_ _ l[53 ___jl__ j[11_j E i_Z._ ~ ^ ZZZZZZlE~~~EE ell ~ ? L_ll-~ll;][_. __] [gggg, 7=1 -= E 1 -JI I

hten ej Sinef;moyalmelhod s 7 Mch one , (following[d_escribps the Containm:nt lodine _R;mov:1 Syste_m flow path?

M,Mo_is_tur6 L parator, llEPA Filter, Charcoal Filter, Circulating Fan. _] MCharcoal Filter, Moisture Separator, HEPA Filter, Circulating Fan. _[_ j M Mpisture Separalgf Charcoal Filter, Hepa Filter, Circulating Fan. ~~l

[Cir~culating Fan, Moisture SEp~arator, HEPA Filter, C_harcoat Filter, l

'Aset*IE] d B                         } MLMMemory                            JM cetrert entf.                    ]hj~                                   t sit 7/o]

N027000$$01___J '40Ml @ gWj @ d (Sy$_,J d [._$ Wemi,j [T % :- i~ T51Miel [Contain_mentjodintRemqyaLSyt. tem

._J

[KrioWIedge of the operationalimplications of the following concepts as they appY lo the Containment lodine Removal System furpose of charcoal Nters 'W# . y,, _ ,,,,_, _ y ,y. ,,, ,_ , [ECCS Less_on Plan _ _____ __j[C_R0 718 - l( j[OH 108 l{ _ j[28dO_j CJZZZZE~~

__1 1 JE TR[ .J i.e , - ,1: j WMMWL1

1 himJhmBWitj [sBCs statusjollowingleactottrip l IGIvI:n the following pl:nt conditions: Unit 2 tripped from 80% power due to a loss of vacuum All systems responded as expected Tavg is 533 degrees F

 ,      Steam Dump valves are closed l
 ]f Tcvg begins to increase above 535 degrees F the steam dumps will:

Il[guick-open.iMediately [ begin to modulate open until T avg reaches M 'immediately begin to modulate open until T avg reaches 548 degrees F, at which time they will pe fully _open. O! remain closed until T avg reaches 540 degrees-F, at which time they will begin to modulate op [3[emain closed until T-avg reaches 540 degrees F, at which time they will quick-open. l l *Wa*Laaa'l!comprehesion M J ic_ J m a a n == ( B - I W ca'<*ri c'i"' IW' " 7/S I Mii000MQB_.J a*El M Whl La'i M lsysJ m.(Eeji 3! LutoesiiiPI(( ti' f ' ' T4eoj [ Steam pump system and Turt)ine Bypass pontrol l Ability to manually operate and'or monitor in the control room

tst 9m dump 5aive.

haswer p ,,._ . g y 7 mmy, g p- p7 3.p g.pg [R_Rs }[CRO 5819 ll li9 ][

~ ~

l$2 l L.__ ][ ll ll ,U ll I i l[ IL _11 ]l 11 I mw ,,,wunng i

                                                                    - P#iMistI3

M driRoLMain Feed Eump ] [WHICH ONE (1) of tho following will rcsult in th3 initiation of cn AUTOMATIC trip of tha "11" Main FC:dwater pump _when Unit 1 is at 100% power? _ kump dischargepressure increases to 1500 PSIG. l

  }I5uctionpressure decreases to 250 pslg._                              _ _

j kPump discharge pressure decreases to 1100PSIG. l krip of the "11" condensate pump. l Amouer j3]MdB l hMl Memory IM calvett cim lM i tit 7F; Mh9000K4_16___.] W La*j M L.2$ W Lsys__] MI il M i il l

'assiefWBvetulletilliol Main FeedwateJystem

_] [ Knowledge of Main Feedwater System desigti esture(s) and or arterlock(s) which provkle for the following futometc trips for MFW pumps

          'imi g_          _ ..

g .., , _ _ m , % . g%_ , , gg, q I Cond:nsate and Feed Water Lesson Plan _j[CRP.103 2 8' l[. .._ _.jg _){ i[3.5 l

 =====___._=___                            _ . _
                                                                                              .2=    --                     I

-- , i M30kW3

M [Q_ontroloLs eam supply to AFW Purpp turbines l hich one of th] following d:scrib:s the op; ration of th) St::m Supply Vciv:s for the Turbine

Driven AFW Pump?

l lWh:n operated with the handswitch: [CV-4070 an'd CV-4670s open simultaneously. l M f9 4070a closes first followed bgCV-4070. ] dCV-4070a opens first followed by CV-4070. j M 5V-4070 opens first followed by CV-4070a. l [Cd [B l Memory j M Calvert Chrfs l 1 11/17/g l M061000K103 I d [3 g d M M [Sy j M [ il M [ 1l NWl ' ugliary1Eme.rgencyA Feedwater System l M Md [ Knowledge of the physical connectens antor cauto-effect relationships between Aurgiary / Emergency Feedwater System and the following l Main steam System

h et masser , pyp .. .~ % g 1.y-m u,,w'elra m m w irr" w m l M M g W y"j 'MW Control an.d_ Inst. _ l[CRO 3U2 6 }l l[18 ' lI' l f3.1 ) f-wwge,m- > m ll 11 lE ._il il 11 I q

tMMMtanLW

h!!nalettsel 'AFWfmp_TiiMhrottle opetation _] ' Stet th] function of th] k yswitch s locat:d in tha Auxili ry Feed Wat:r (AFW) Pump room foi tis-durbine Driven AF_W Pump _ Trip / Throttle {T/T) valvo. _ _

              ~                                                                                                 _ _ _

k5naI5ie~thTT/T valve trip function from the AFW Pump Room._ _ _ _ _

                                                                                                       ~~ ~ [ ~ ~ __]
                                                                                                                    ~            ~~

MIr]p the T/T valve locally. _ j dDisable the T/T valve trip function from the AFW Pump Room. l kOisable the T/T valve trip function from the control room handswitches. l Ameser l[] bemMl[8 l M..l[Comprehesion l@ colart cliffs lg 11/1719] M05(00K201 l M [#j M [L3] M [SYS_J M L 1J h E_1 MDilej [Auxika_ryLEmergencyfeedwater System. 7 k&M rKno# edge of electncel power tupphes to the following AFW system MOVs h N . p + rr m g y g g ~ e - m - e y m g g lp r g ~j y g g g g l hFWControl & Inst ][CRO 34 2 6_ j l ... .,___ _ j [19 jl l'p.0 J E

_ ~lL - ~lL iI J E._._._J (_.._ ._] E 7 J t- il n L_J . wmq ; MS2VJsitll1;

M IEowelto,_RlR Tdp BAfs ] lNO cther TCB's open. Unit 1 is opercting ct full power wh:n 4 Rccctor Trip B Mich one of the following_e_quiprnent failures is the cause_of this event?

                                                                                                                             ~ ~ ~ ~

M 208/120 VAC Instrument Bus )

M[125 V Reserve Battery Bus [ M[125 Volt DC Bus l

QEA MG set l

  'N [CJ "ERimifund IB_j IBM!Gnimiglj [Applicati.o,n                                          lM cetvert cirrte           lM[                             t1/tili]

M N2000K201 J M(( M [3f ]higtem][sySJ ML2J hlL2j hue =1 ' AElectdcalDistJtution e l [ Knowledge of electre.at power suppoes to the fo: lowing [M8)or system loads

--~

pmy,-g % ,g -m

                                                        .%                                         gp % ,y                                                        g

[125 VDC/VAC Dist j[CRO 5413 jl ((0H10 }{ l l(3 2

 ;RPS l[CRO 591 11                              ll'     -~h45                      ll               l[9.0.3 J

[ T~ JF ~ll 11 Il J wwwm '

1; ;

i 1 4 -' <4 4c-1

M.fastej hiessurtzer heaters ayallat$1onJOOP_ _ _ _

Milch one of the following indicat:s the pr;ssuriz;r h:st:rs th;t would be avail:ble following a Loss ~ hf Off: site Power (LOOP _)? Assume the EDGs start and carry the ernergency loads. ___~ ~ ~ - ~ - kProportional Heater Bank 1 and Backup Heater Bank 3. J Aj proportional Hester Bank 1. l M jackup Heater Bank 1 & 3. _] M)ackup Heater Bank 1 and Propotional Heater Bank 1. } hasser j {g@j {] WWl[MeElory }g calvert clifft lQ t tit 7/91 M[d55000K301J M M M M M ISYSJ M L2j h.e.mel L_.2; 4

 ' MIIndvedubscDilpl [AzC. Electrical Distribution
                                                                                                                                          ]

M 3' 0Moogo of the effect that a lost Of melfunctOn Of the A C Electncal Dittntn# tion wlO l, ave en the follow 6ng 19P'.*!!4.mlo*85 et y .. . .

                                                             -,, ,                   ,,,,,,,,,,,, _                               y,, ,

h0P 71 ~~ _.__J[CRO 2_02 712 l[ ![23 _ j[ l[9 l h.essal5MWZZ~ _. - - _ . _. IE8BF.~65- j l ._ _j[42 __jl ;11_3 i 3

' timshe!stesisj l J IThe 125VDC Batt:ry Charg:r 11 h:s fril:d due to an clectric^l fault. I Mich ONE of the following identifies the remaining sources of power to 120VAC vital Bus 117__ Mji25VDC Battery Charger No.12, ji25VDC Battery 11, l (120VAC inverter Backup Bus 21 1 M 125VDC Battery Charger No. 23, 125VDC Battery No.11, 120VAC Inverter Backup Bus 11. j Y125VDC Battery Charger No. 23, 125VDC Battery 11, 120VAC Inverter Backup Bus 21 M 125VDC Battery Charger No.12, -~ 125VDC Battery 11, 120VAC Inverter Backup Bus 11

 'Ansiuer l b j B!!R!nWMB_

_ l beilltue W l [Comprehensionj h ceivert cliffs ihj t sitvs] d[@iOOOK410_j MWl[31J WDWool [3Jj d [SySj llRtospl(( homespl[f 1 M ? N tuisl LC ElectricalDismbution t l MM;l [ Knowledge of A C. Electncel Distnbution design feature (s) and or intertockts) which prov6de for the followinD:

[Uninterruptable ac power sources napsummier ans w p,, g_ < $, .me.,yy y, r,. p. . py ,, g ,g [120_VACd2'5&250_VDC Lesson Plan l$RO-5413 lL l[OH6,9 l[' ~l ).2 ' l L _ _ _ . _ ll l[~~ ~ll ll Il i I- lL ~] f... A Il l[_ 1 m wwe -l ; NEMMMU

M [Gou!clof. control power to 4,16 KV loads l W]h 1 oro of the following is_the_ source of control powcr for br:ckcrs on tha 4KV Unit Bus 117

                                              .                                                                                                                   j M L120 V Vital AC                                                                     _                                                                       l
                                                                                      ~                         ~

Siiiv oc ~ j 1F2s0 voc l

         $l208/120 VAC                                                                                                                                                l

, M ib_j M IS I hM.IMemory I@ ceivert cliffs lM' 1i/t rio l M[04000 pol _J B,Mdir.] L9j W L1d h!I!ami!d !sys_.] M L.2 WomariI7 ANGIWWusheipMI [DAEleetrical Distrtbution _ l KnoMedge of electncal power ado ~ pies to the follow 6ng- [M*Eoc31d* _m_ _ y.v,,n...m w g ,we ,w pn,p g g g g g., . l [4KV Dist. Lesson Plan l[CRO 4815~- l L _.i ._ -. ! L li 14.4 I [dFSAR _ _ j' _ l[ig. 8-5 ![ ll ll_ ] E '- T l[ T JL lE IL I

    . ,7                                        --7 t
                                                                              . . .       5

mena!Liekj })CLBusin;erlocks 1 [Which on] of tho following st:t:m:nts b:st d:scrtes th3 rclntionship of the 120 VAC cnd 125 VDC ' power.to the plant computer? . M The static inverter feeding the computer has both a 120 VAC and a 125 VDC power supply and it_ cutomatically switches on a loss of the 125 VDC. MIThe staIIc inverter feeding the computer has both a 120 VAC and 125 VDC power supply which

    'gianually has to be switched to the 120 VAC when the 125 VDC is lost.

M[he static inverter la a backup to the normal 120 VAC power source. When 120 VAC is lost, power is automatically switched to the 125 VDC powered inverter. M The 125 VDC powered static inverter supplies the #11 120 VAC inverter bus which in turn suppliespower to the plant computer. _ M l[_] WWI[B _l @W l [Corppreheslort,_J W ceivert clitts lg 11/17TJ M 063000K402_j h h j L9'j WWj L2*j 'WI[SYS J MlL_2) WhlI il eyetsutw6 den 1Mel RC; ElectricalDistribution _] Knowledge of D C. Enectrical Distribution design feature (s) and or interlock (s) which provide for the following

              ; Breaker interlocks, permissives. bypasses and cross-ties

r. _ __ _ ___ _ _ - ._.

y. - ,,m_ .

                                                                                  . _it, _ ,,7 w . ,                                   ,y h25yDC SystenL__ -

_ [CRO-541 3 1 _._jpH9 jl I[1.2 ] L__ 3 IL JL h L_ _J W3t?'tC

Whsisj [D; $-! AILStart Syste_m ] fihe annunci; tor "125 VDC Pow:r Supply Fcilure" has cn:rgized on the 1 A Dies:1 G:n:rator control pan:1.

 'Wh:n a diesel generator start signal is received, the diesel generator will:

M start because only 1 of the 4 air start distributer solenoid valves are affected by the loss of6C Lvolts. MIstari because backup power supplies will allow power to be supplied to the air start distributer _

       ! solenoids.

M 3DT start since DC power will only be supplied to 2 of the 4 air start distributer solenoid valves. l dA~dFstart because DC pov/er is unavailable to any of the air start disributer solenoid valves. l wildJ tinsel [e_ J tese=WILApplication lhj calvert chffe lhj 11/17/9 l

 .WJR4000K105_j he##*l[M bWehml ((3 M [SYSJ Bitselt!L2) !nwemmel E E
 $_'_ ^ _ I          99Bl hergengy DieseLGenerators                                                                                                    }

WA M [ Knowledge of the physical connections and/or cause efrect relationships between Emergency Diesel Generators and the following

                    @larytg air systern .__

thshmaman of answer p .m .7 , , , y

                                                 ,4 g g                                           ,.   ,,              .
                                                                                                                                             ,     g.

Dusel Generators Lesson Plan )[CR_O-48 21 l[ j[45 jl j[5.0 l 55 ll Qig 8 8E- ji ll ll l [Dusel Gen. Lesson Plan . l[CRO-48 21 T i!{$1 JI 1[i4.1 J p_ w - 3

                                                             $ 30Mjt22jj

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

M 'EDG Emerg. Stop Push. Buttons _

bich ONE of the following 1 A Diesel G:nerator trips will clso cetuate the Emergency Shutdown [ Signal alarm on the Annunciat_or_p_anel?_, _

                                                                                                                                ~                                         ~~~ ~~

r kGenera'toTDifie'e~riiiaiikotection _ ~l kGenerator Overvoltage j M 55nerator bearing HiHi temperature

M,I)ush Button 2A (Emergency Stop pushbutton on local control panel) depressed J M [a] hantM!!ilij;B l es!n!s!nte!Wlyemory IW cetveri cists lh suisil l jlejSToooK402_J W[3] W#sti*l L4=2j a!!!amed LsysJ MEf hlL2]

  'hhl [ Emergency _ Diesel Generators                                                                                                                                                                  l M IxnoMoope of F.mergency omsei Generators dwgn feeture(s) and or interiock(s) which provkle for the following h,._ _ps for E D/O whlw operstang (normel or ernergency)
 ,- , m , -                                                                             _y _ ,,y m y m ,y

[EDGs Lesson Plan _ __jiCRO-48 21 l L.. jl28,3o H 1[i 7___j [_- __, _

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emmale!hl [t.oss o.UnshmeOLAltprpteetJpn _ _j VMICH ONE of th] following is the expect:d rcspons] of the Instrum:nt Air Syst:m to a major [urbine Building instrurnent Air header rupture on Unit 17

n M'l'strun5eiit air pds's~u~re will decrease on Unit i until the air compressors trip on high curren Minstrument air cross tie valve to Unit 2 will OPEN, then RECLOSE if the Unit 2 Instrument Air py_ stem,gres,sure drops below setpoint. M The normally OPEN instrument air cross-tfe valve to Unit 2 will CLOSE when Unit 1 instrument Air System pressure drops below setpoint. MlThe Plant Air System cross tie valve will OPEN to supply the Unit 1 instrument Air System when pressure drops below setpoint. MCM[B l MWI[CoLnprehesion lM ceNert cwf. lW t titiT9] MN6000K393_} M M M [3d M [SYS_] Mj[_3] M [3]

 'NMI [lnstyrnentAILSntern                                                                                                                    l M ,fV,no# edge of the effect that a loss of malfunction of the instrument A6r System will have on the following-Lcrossaiea unne_ _     _ _.

assum pn e ce4rr g gm m w ejp q m m jpw m ml[y g g g mj sprnpfyssed Air System

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M M;;9hJnglangfgUolloMng droged cEA c ] f0P.1B,"CEA M lfunction", rcquires rc ctor pow:r to be incint:In d const nt during the rccov0ry of a single dropped CEA.

@ich one of the following is used to maintain Reactor power?
                                                                     ~

M[u]EIrie Load } kBoration l M[ Group C CEAs l Opilution l [h ] M [B l hppjiCation l Calvert Cliffs ]MI 11/17/9 l M00000)M05 I W L4al h L4J M[EP,LJ M3 Mi il MBerl [Djopped_ Control Rod l l

                ' Ability 10 Operate end / Of monitor the follower 3 es they apply to Dropped Control Rod-Reactor power.turtune power e_

p. .y .- ..y,7; g.e,m. w_,q p .

jpy w g. ,~ g ICEA Malfunction lh0P.1B }l I[30 ,_J[5 ~ ll l [Lqsson Plan _ ][CRO 2021B If~~ ~" ~ll lL_ 111 . 3 I i IE E 4 lE li mmmn i y ; N M MJ W 13

M Ltactotttip o!Lptopped_CEA l The following pl nt conditions exist:

1. One (1) CEA has dropped into the core.

2. Pressurizer level decreases to <95".

3. Reactor power decreases from 100% to 85%.

4. Pressurizer pressure decreases to 2225 psia.

gilCH ONE of the following is the minimum action required? [hripr the teactor and perform Standard Post Trip Actions. j Mgeduce Turbine load to match Reactor power. l kCommence a reactoi shuidown to suberitical. l CReduce power to less than 70%. l Mb_jM[B l M.d[Comrehesion lM cetvert Cliffs lM, t ilt 7/9 l M 00003K304 1M' I!dinEl L6*j Mj R M [EPE_l M"l[2]IR99str_j[ij

[ Dropped Contro1Roi l M KnoWIedge of the tessone for the following r**Pon**e es they appy .s Dropped control Rod Actione contained in EOP for dropped control tod pey r-,ye gyrm-~wemy) pggg,9 g"l prg rw l jg Q g gpr j l%OP 1B } {_.. ._.,j [29 l[4 ll l ((CEA Malfunctions lI l l ..- g ... _ ..._ ..j l II El y

g. .. m _m _ y q WMMi421

M indicatons of a stuck CEA _ l IUnit 2 has been opercting ct 100% power wh::: a lord d:cre:s3 to 50% is initiated. During the lord

  !decrcase ONE CEA remains at its fully withdrawn position while the other CEAs in the Group are being insertsj lWhich one of the following annunciator alanns would provide indication tnat the CEA failed to move?
                                                                                                        -                 ~

Mj"CEA WITHDRAWAL PROHlBIT". l Alf'CE A MOTION INHIBIT". l M fSECONDARY CEA GROUP SEQUENCl:". l M fSECONDARY POWER DEPFN INSERTION". l { [B l Mlfppliggggn lY Calvert Cirrfs l 11/17/9 l d!Q00005610L] W L3,6J _W_ M [M! M $Pf_] M[._1] Ml[_,1) I -^ I Ml [Inope@hle/ Stuck _Qontrol Rod ) iAbility to operate end I or rnonitor the following as they apply to inoperable / Stuck Control Rod [CRDi~- _ . _ g _ ,, , , , _ _ ,e, _ ,, _ m n ~ [CEDSlesspn Plan _ _ l[CRO-601 10 _JL I!59 IL ll14 I

 $ arm Manual                                          ll                                         l l'~                ll        l!         Il          l

[Ufikri~ _ 11 IE-~ ll ll II 1 g , . ., , g -

                                                                   %NMIC5

iniisiss1riiiiifsl ilndicctions of a leaking SRV l I Givsn the following conditions:

           . A RCS heatup is in progress.
       )

RCS pressure is 2250 psia.

A- The acoustic monitor for a PORV indicates valve leakage. 7

       ;Which ONE of the following describes the expected tail pipe temperature and how tail pips
       ;t:mperature will respond as RCS pre =sure decreases to 500 psia?

I(Assume l pressure downstream of the PORV remains constant.) M Tail pipe temperature will be higher than if the PORV opened at normal operating pressure. As pressure decreases tail pipe temperature will increase. M Tail pipe temperature will be higher than if the PORV opened at normal operating pressure. As pressure decreases tail pipe temperature will decrease. i Tail pipe temperature will be lower than if the PORV opened at normal operating pr6ssure. As i 1 pressure decreases tail pipe temperature will increase. M Tail pipe temperature will be lower than if the PORV opened at normal operating pressure. As pressure decreases tail pipe temperature will decrease. , haiwer l[]'tiiiiiGiell!B l 'Ceeni#isIC$siiil@ppil cation l)sealey:lcalvert chffs l'eskuestje 11/17/9 l M000008)M01 l MM L3.2j %n0Troissil (3Jj W*itiisil[EPE_.J MW L._2j WWi.iisi[_1 CT' "" Win] [ Pressurizer VapoLSpace Accer%nt l Knowledge of the operationalimphcations ofNIsljowing concepts as they apply to Pressurtzer Vapor space Accident. Thermodynamics and now characteristics of opo y leaking valves kaplehiissiW h ' Enthalpy at 2250 psia is 1126. A constant enthalpy process result in a tail pipe temperature of 285 F. Enthalpy at 500 pria is 1204. A constant enthalpy process results in a tall pipe temperature of approx. 345 (F. pmmw,sey g )gy pjggggjpyggggggj gggj

  =    I
                                                      ,_     _L                               ll._                 lF ~             ~lE      K         l lMollier Diagram                                          U                              IL            _ll                   ll      ll          I

[esson Plan l[CRO-5 2 ll ll ll l(14.4 l y qgghnewlSteam Tables l-kNd$52

FielseiliTiEls] ! Alt. Flow paths d_un}g LOCA l lWhich ONE of the following is en cpprovsd alt:rnato msthod of establishing hot I:g inj:ction during a 1 !LOCA event on Unit 17

kLPSI pump discharging to the pressurizer auxiliary spray line. l MlLPSI pump discharging to the hot legs via the shutdown cooling 5I2i lines. J 1lIHPSI pumps discharging to the normal pressurizer spray lines. [ MiContainment Spray Pumps discharging to the hot legs via the normal pressurizer spray lines. l answ'er'] pj hisishiidj ) j leiisishiiss LiisWliComprehesion l@ calvert cwfs lM :1117/9 l M[0_00011 A113 l MVaWiisl l .1*; M_hfrj 12j Ml[EPE_j M(_2j Ml 1l E-T'T""T1Niilil [Large Break LO_CA l MA bd Abikty to operate and / or monitor the following as they apply to Large Break LOCA: Safety injection components niiltiliiiiissil an

p. n g s p p m er g g 7 w g M m m m ;l {'p g g ' g j p3 g g w y j g g g g g g g;l ILesson Plan l FRO-2015 ll il IE ll8.0 l l ll l l... ._..j l II ll l

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M [R_eguired tripp[ng t;;_mperatures for RCPs l lWith powar c 94%, which ONE of tha following lists ALL RCP t:mparaturas that can sxcxd 195

F 4' nd cllow the RCP to continue to operate?

k-Upper or lower guide bearing temperatures. l kyer or downward thrust bearing temperatures. j dUpper or lower guide bearing and upper or downward thrust bearing temperatures. l MControlled bleed off temperatures. l

      %somiil[d l kniiilisie81:8         iMVWisil[ Memory                           IW caivert chtra                              Iksimmensl                11/17/s l M[000015G449 l hiDN*I 10j '4A D W .I I4.0: M fPEj dI il Wesisill il
      'M98sl l Reactor Coolant Pump Malfunctions                                                                                                                    l MM Abilty to perform wnhout toforence to procedures those adions that require immediate operation of system components and controls.

pra9piyWww g g ?w "m'E*rlg g gegjijgsgf g *jpp h ql 4 g "gg%gl

                                                ~                   ~   '

[RCP Lesson Pian lICRO iO617~ ^ ~l[~~ ~_][14 l[11~ ~ lI61 ] I j! Il I ll ll l 1 Il II ..-~l l ll 11 1

megamer gl 4

i i a EE =v

A MMTisisl ' lternateflowpath if the Emero:ncy Boration Valve does not open. I

  !A loss of MCC 104R h s occurred.

l lWhich one of the following describes a boration flow path that remains available? sJ;RWT, CVC-508, CVC-504, charging pump suction. l hl BAST, CVC-210Y, CVC-512, VCT, chargingjump suction l 5l[RWT, CVC-508, charging pump suction l 3l[ BAST, CVC-514, chargingyump suction l M Lb_J tsiiisGiid!B l 85faillveEiialLApplication ljsgeglcatvert cles lM l

 $000024A104 rg '

l M' L63 Wisiiisl l3.71 M !EPE l KMl il M Cil

              ~"Yeiel [ Emergency Boration                                                                                               l M               Ability to operate and / or rnonstor the following es they apply to Emergency Boraten:

Manual boration valve Rauwer p?wspep"gggg*memyrme:rl pg g,ggj;;;ggj ggg~nggg g ggpryl

          ~
                                 ~               ~~                    ~
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                                                                                                                             'lI~ l(2153l
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[CVCS Lesson Pian ' ~ lICFIO-107 I 6 l L.O. [7 ' gesponses , i Il 11 f Il _jl I L ll ll ll Il Il I mggm mg ;

MM [ack upJumps for loss of SDC ., l lThe r: actor is shutdown with shutdown cooling (SDC) in progr:ss wh:n tha op;rcting LPSI pump becomes air bound and trips due to low RCS water level. After RCS water level is restored, neither

      !LPSI pump can provide significant flow.

i What other pumps can be aligned to the SDC system to provide SDC flow? M! HPSI pumps - l M[ Containment spray pumps l MChargingjumps l 1 kSpent fuel pool cooling pumps l h'] h _j M W i[B l biiMrsMEid[Comprehesion lg Calvert Chffs lg! 11/17/9 ] N0000_25K101

          ,~~,n..a 1 **1 L31 leaWaisial LL3j hl [EP_E_J M L_2j M L_2j

[ Knowledge of the operationalImplicatons of the following concepts as they apply to Loss of Residual Heat Removal System-l Loss of RHRS dunng all modes of operation Sp6iiiiiiiiiiiif.oi ppegw ww g w ywm+ mom 7lp g g g 'l pre g eggg g g g gp7l IAOP-3B

l[ 'llV.C.5 lI2f~ l[3 l[A.AT l lLcsson Plan llCRO-203 5A ll ll ll ll7.0 l I ll Il ll ll ll l wggwyemq 4 i

M'Yepisl [ Loss.of air _to one RCP Component Cooling wat:r return be Containment isolation valves l The cir supply to tha Compon:nt Cooling Wat2r return lins contrinm:nt isolation valva (CC-3833) t lhas been broken while scaffolding was being erected. lWhich ONE of the following describes the effect, if any, this will have on Reactor Coolant Pump ppqrction? dRCPs will have to be tripped immediately. l

 $RCP temperatures on two of the four pumps willincrease.

l MRCPs will be able to operate for 10 minutes. l MCP cooling will be unaffected. l MC dd[B l M! Comprehension lM Calvert Cliffs lM 11117/9 l g!000026A107 I 5El[2g bWiliis:l [3.0j M [EPEJ Ml il Ml il C ~T " Vuiil [ Loss oLComponent CooingjNater l

              'Abilty to operate and / or monitor the following as they apply to Loss of Component Coohng Water:

Flow rates to the components and systems that are serv. iced by the CCWS; interactions among the Components kuplanetenk Aneuer - pren;wryg g w perm *mmujpr g g g pp m mj g g g gg;gl [CP Lesson Plan }[CRO-106d.7 l[ ll13 l[ ~l[8 l 8CP Of eration l[OI 1 A l[ ll ll _ ll 1 - %w.___~q j 65iE*MlN32

M LRequirement to trip on Loss of Cornponent Coolina Water I !According to the Abnorm I Op;r; ting ProcCdura for Loss of Compon:nt Cooling W tsr (CCW), Which one of the following CCW malfunctions would require the Reactor to be TRIPPED? MI[ow level alarm in the CCW Head Tank. l M[looding due a large rupture of the CCWreturn header. l WA trip of the 11 Cc Pp while running. j Mhgh RCP Outlet temperature. l

           !bd NN)[B                                    l *IoEl!IIWR_W][ Memory                          I .W._j calvert citffs        lh[             t1ft7/9 l M[000026K303              l M l4.0 irs %Iiis:1 12j M [EPE_] Ml il dI il WiliiiisisiiudiiDIlls! [ Loss of Component Coolina Water l

Knowledge of the reasons for the following responses as they apply to Loss of Component Cooling Water: Guusance actions contained in EOP for Loss of CCW/ nuclear service water Answer - peewryy pewe g g y w e n e m m lp;g g g g +gp p g wgl g -g gggj [Lcsson Plan lICRO 13-5 ll il ll ll10 l L __.J l I L_.. ._ . ._._.j l II II

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M [ spray viives stuck open I The following pt nt conditions exist: '

1. Unit 2 is at 100% power.

2. All control systems are in AUTOMATIC.

3. Pressurizer spray valve is stuck OPEN. a

4. NO operator action is taken.

1 WHICH ONE of the following describes the effect of RCS pressure DECREASING to 2210 psia? MiPressurizer Pzr CH 100 Press alarm is energized. l Ml Proportional heaters are fully energized. l M l Proportional heaters are deenergized. l MIAll backup heaters energized. l M [bj M S I MUi6IeMllApplication l M carvert Chffs lM_ 11/17/9 l M000027A101 y l M I E ll4.0' lift 6Timiliisl l3.9? M [EPE . I M l il 'M (_2j

          .w%l s              PmmMdWWm                                                                                        l Abthty to operate and / or monitor the following as they apply to Pressunzer Pressure Control Malfunden.

PZR heaters, sprays, and PORVs migEselen% ans== < pewwyymggremppew ylpgggg g;pgagj >ggggggl ~ ~

~~~

[RCS insE Lesson Piari lf l{0H-20 ll I f-~~l F63 l l ll }l jl ll li l 1 11 II II 11 l l_ __ 1 g p. -m=_,mq kh 1 3

1

'empiiseTiiislIAF_WP isolation                                                                                                    l Wth AOP-2A being impl:m:nt::d, s:I ct tha vciva th:t is r;quircd to be CLOSED for isol:: tion of a i

l tub 2 leak on steam generator 21, and is normally maintained open? l d} team Generator 21 Steam Supply valve (MS-4070-CV) l

   .%ll Steam Generator 21 Steam Supply Bypass Valve (MS-4070A-CV)                                                                l jhlISteam Generator 21 Flow Control Valve (AFW-4511-CV)                                                                        l j83'AFW Pump 21 Trip Throttle Valve (MS-3986) l hiniAmor lfc] WiisGiiilIB            l YU"TUisisl[ Memory                 lWasigtsj calvert cliffs       lh]             11/17/9 l M000037K307 l 'al0Mi 12j '8HsiNik:1 I4.41 45588Wl $PE_J jggskj l 2] 3R!LGi_ii41 L2; f_ES - TTmil (Steam Generator Tube Leak                                                                                          l M M$ l Knowledge of the reasons for the followin0 responses as they apply to Steem Ger...itor tube Leak:

(Actions contained in EOP for S/G tube leak N M.ar ane ppy.mymyy gp qvyw~qqg gyggg g pygymq g g

~~

[Exdess RCS Leakage l 'A052 [V.D.9'~~ ~~l[16,17 ~ lf4 ~ lf ~ l A ILesson Plan l[CRO-202 2A Il .,_j ! ll lIi0 l i li I L.._... ... ._.. .i l ll li I m %g..% e q l E5NW$YES

1 tiNWesMI [S/G Pressures dur_ing C/D following SGTR j IGiv:n tha following conditions:

11. A Steam Generator Tube Rupture has occurred.

2. All systems responded as expected.

!2. The performance of EOP-6 is in progress.

!3. One Steam Generator has been isolated.

14. All RCPs have been stopped.

!5. RCS cooldown using natural circulation is in progress. >Which one of the following describes the reason that the isolated SG pressure is of concern before !the RCS can be placed on SDC7 M The isolated SG pressure would be too low due to excessive cooldown causing RCS water to cnter the SG and reducing RCS inventory. M SG pressure is being maintained slightly less than RCS pressure to prevent secondary water cntering the RCS. MlSince the RCS cooldown rate was maintainea ss than 35 F/hr, the affected loop has not been

     ! cooled sufficiently to allow SG depressurization.

M jThe affected SG pressure is high due to thermal stratification of the secondary water. l 'M I[dj MMI) l Desal#wsMl[CoSprehesion 1% carvert ckffs lgyi ,11/17/s l d[000038K103 I I8liUMII[3 9] '4MiO%hEl 12] Iisiisss][EPEJ MihiiraslL2j hieiron( ,L2j Woesneh'Wesl [ Steam Generator Tube Rupture l M 9tshmjmt.l Knowledge of the operationalimphcations of the following concepts as they apply to Steam Generator Tube Rupture: Natural circulation pmyce , ggymggw3q)pggg~j pygwyj gy 7 gg lf

                                            ~
                                                                                                                    ~

(SGTR Basis Document l[lV.AB j[58 l[7 ' l[NA~ l ILisson Plan llSRO-201-6 ll ll ll ll5.3 l 1- ll ll !l ll li I wwgwmmy ; MMsa3 Msg

i [Requirerrcnt to trip turbine based on back pr;ssure and_ power hi!iu!!!lwisl l

                                                                                                                                                   ~
'A loss of cond: Ins:r v:cuum occurred on Unit 1 with racetor powcr ct 60%. Tha operators cro r:ducing power and are able to maintain condenser vacuum at 24 inches Hg,
;Which ONE of the following indicates the power level at which the turbine will have to be tripped if Escuum can NOT be increased to greater than 25 inches Hg?

d58MWE. l Ml176 MWE. l 1ll270 MWE. l

  $!440 MWE.                                                                                                                                          l
'Anoser j[c_] WGunfl[B                            I hesiktifilmJel(Mhoy                lM calvert chrfs            lM                         11/17/s ]

M [0000k1A202__.__l'3ID M (19] kne'ifesio:l 14,1l M [EPE I Ml il M M l il MM IAbility to determine and interpret the following as they apply to Loss of Condenser Vacuum: [ Conditions requinng reactor and/or turtune inp Amewer ymyww mew g g - _ ;l pryg% g j pwwwtgj g gpgl {1 AOP 7G V l[lV.A.2 } ,5' ~ ~ ' l[0 ~ lI l l Lesson Plan L ljCRO-202 7G ll ll ll ll1.3.1 l l my w gw,gwq ll lC ll ll ll l l

                                                                           $55M3835!E 1

M 1160 V feeder breaker interlocks l lDuring th3 p;rform nc3 of EOP-7 "St: tion BI:ckout" On Unit 1, which on3 of tha following dI;scribss

    !ths actions performed in aligning the electrical system for power restoration?

Ia

    ' Ensure the:

M113KV Feeder breakers are CLOSED. l M!4KV Bus LOCl/SD sequencer is OFF. l Ml EDG output breakers are CLOSED. l d[14 4KV Bus Alternate Feeder Breaker is OPEN. l M[d_jM LB I M! Memory Ig calvert chns lM, 11/17/g l MIO00055A203 l M M IIRindsliinl l4.7) M [EP_E_] 119Mll 11 M I il MMl IStation_ Blackout l AbilRy to determine and interpret the following as they apply to Station Blackout: l Actens necessary to restore power

              st The cross tie is between 1 AB and 2AB and the breaker on the unit with the blackout must be closed first.

p?mm,wfpgwsweewwmmllrpeigggggjjjglppwg* yJg'ggggegl

                    ~                                      ~
                                                                                             ~~

[St::t!on Blackout ~ ~ ~l[E057

                                                                                                ~
                                                                                                  ~~l[lV.H.      j[16-19 -~~l[4  l[          ~l

[ssson Plan llSRO 2017 ll ll h ll3.0

                                                                                                                                    .          l l                                                                              II                 ll            ll__       ll  ll           l mwnissiiiiisem                           *19                                                                                        R f

? bNiM@l2fD

M' %FW Flow dunng SBO l

 ,Wiich ono of tho following d:scrib:s tha m;thod us:d to op; rat 3 AFWflow control velvcs during tho '
 ! ;rform:nce of EOP-7," Station Birckout"?

p M[ Local manual control by an operator. _ l A:l[ Aligning N2 to the AFW amplifier 3r system. l M[ Placing the controller in Auto-Full open and controlling speed of the Steam Driven AFW pump. l M Allow the valves to automatically cycle between isolating on S/G hileve! and unisolating on AFAS actuation. -

  $mbinii j UM LBjMisiUIbplication                                                              lg caivert cliffs         lM!                     11/17/s l dl0000SSA204 l M M M 14.11 M [EP_Ej M' I il M i il M'91kl l Station BiaEkout                                                                                                                                I Ab61ty to determine and intsrpret the following as they apply to Station Blackout.

Instruments and controla operable with only de battery power available Wof m m {*pTwfFemMytiIf0"TS ""SPflIFM'MM'lFFFMMj rM M WWi"1 '~ ~ [EOP 7

ll' l,iE.2.c ]I9 'l[4 l[N.I.~ } [Lcsson Plan I!CRO 201-7 ll ll ll l!6 l I ll !l ...J I ._l l Il l wwgewn g ; i

M [Effect of a loss 120 VAC. ] lFollowing a loss of 12120 VAC bus, tha performance of st:ps in AOP-7J rcquires tha ESFAS l

        ' SENSOR cabinets be reenergized prior to the LOGIC cabinets.

Which ONE of the following is the basis for the order of the steps? , Th2_ step order is specified: Mito prevent inadvertent actuation since the Logic modules are deenergized to actuate and the

             ! sensor modules are energized to actuate.

M;io prevent inadvertent actuation since the Logic modules are energized to actuate and the Isensor modules are deenergized to actuate. M !so the Under Voltage Logic relays can be properly aligned. l M!so the Under Voltage Sensor Relays can be properly aligned. l b ows l L j M [B J "MIComprehension lg catvert chffs l h ill 11/17/9] M!000057A204 l MValiiill3.7J M ld M [EP_E_) MI il "sM9Esiill il 5777^f?" Mis l [ Loss of Vital AC Instrument Bus _. l l Ability to determine and interpret the following as they apply to Loss of Vital AC Instrurnent Bus: [ESF system panel alarm annunciators and channel status indicators x tem H W ~4 puwememyggerwemmmgj pggg gg pyrgyrgj - . - - g g gl [L:sson Plan llCRO-202 7J ll ll ll ll1.2 l

       !                                                             II                                   l[.                  ll         ll     ll        l mww                                    -mq                                                                                                         l

Miihlishile(sl [ Expected cause of a trip on a Loss of a Safety Related D.C. Bus I [Following a loss of the 12125 VDC bus, AOP-7J " Loss of 120V VitIl AC or 125 VDC Vital DC

 ' Pow;r", specifies that ESFAS Sensor Cab. ZP and RPS Channel C be deenergized.

LWhich one of the following is the reason for performing these actions? M o allow for a controlled restoration to prevent inadvertent actuation due to power spikes when power is restored. M To allow for a controlled restoration to prevent inadvertent actuation when power is restored in the incorrect order. M hace the ESFAS and Reactor trip logic circuitry in a more conservative condition. j M[i bus. Reduce the load on the DC bus to minimize the effects during the process o Answer I[b] R!iimisis8]) I'9medediMsilj[Co_mprehesion ]ll[ggilcalvert cliff. lg iiftwg ] M000058K302 l M 1 0' hIndheiiiiicl [4.2l Ml[5P_EJ ML2] be.wlL2 hEis] [ Loss of DC Power l

  'M&M [ Knowledge of the reasons for the following responses as they appy to Loss of DC Power.

[ctions contained in EOP for loss of de power tspleneNonist gymmww g ges wumylggmglpng-rjggg gpxgl

[ Loss of 125 VDC BUS Lesson Pian

~~

l[CRO-202 712 ~ll l[13 lf~ ~l(2 2 l

 @OP Basis                                                                 jl                                          ll  ll14    ll   ll         l l

wr%gm-q IL IL ll ll Il I 1 l tiiW N K W TJ u

    *eisiellesTaistil [ Release from WG h?ader in Aux. BJdg l

During th3 performcnce of e w::sta gas rcl:asa from the 11 W;sto Gas D: cay Tank, WGS-2191-CV l

    'is found to be closed.                                                                                                                      i 1

l Which valve must be closed as soon as possible to prevent a possible waste gas decay tank fdischarge to the waste gas surge tank? M[ Waste gas discharge flow control (WGS-2191-PCV) l M[ Waste gas decay tenk outlet (WGS-623) J 5ll Waste gas discharge to Unit 1 plant vent (WGS-683) l Ml Waste gas discharge final filter bypass (WGS-630) l

    'Asieworlaj WiiiUMifl[B                  l biIeMINiiIiMIAIlRemog                  lM calvert Chffs        lMiiiiiiDets':ll        11/17/g l d[000060K302_j h0Vduiil L3*] '4fl6MI L5'] aiiIs0*e:I[EP_E_j MsiiiiiiislL2J wemmelL2j

_ __.m MM [ Knowledge of the reasons for the following responses as they apply to Accidental Gaseous Radwaste Release: (solation of the aux 6hary building ventilaten ltiipienanesiioi ~ Anewer ppw-m*nw*mwggmmenw pl gyggigiiiiiiiiii, g j gyrgeggsijiw l [ggj g ggyj ~ ~~ [ Waste Gas sytem

l[0117B ~ ~ l[6.4.B.20 _j[18 l[18~~ l[NI] (esson Plan -~ llCRO-1341 ll ll lI ll$.0 l l ll If~ ll Il ll l wm,wwwpg q

                                                                          .:s    + .s

MM !!nstru_ ment Air Response to d:creasino prissure j lWhich on3 of th3 following is th3 exprct:d responso of tho Instrument Air Systsm to o mejor turbins building instrument air header rupture?

MlInstrumeld Air pressure will decrease until the IA storage tanks pressure of 75 psig is attained. l M;lnstrument Air cross tie for Plant Air will OPEN, then reclose when pressure decreases to 85 psi Ml Instrument Air cross tie for Plant Air will OPEN at 88 psig. l MlThe Instrument Air containment isolation valve will CLOSE at 40 psig. l O l[gj W180mllLB l Whisilhemory l#asew:lcalvert cliffs l$3editenej 11/17/9 l M M 0065A201 l MWI 2.9jL %810Weise:l (3.2] esseontl APE _I M L3j g_no_og.=el Lt N.l [ Loss of Instrument Air l M Md ' Ability to determine and 6nterpret the following as they apply to loss of instrument Alr; Cause and effect of low. pressure instrument se alarm

Weptenasen^et _] answw pry. e yo g g gpp< ygg m.we 3.g y

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g .gg xg l [AOP 7D' l[~ l!Iil.Ci l[5 ~l!O l[N.A. l l [ Lesson Plan l!CRO-202 7D }L _j l ll ll5.0 l I _jI U . _j l ll ll I mmam av :$ l P#sgsjus 1 ___________.-_u

1 MIAffect of less_of instrument air on feedwater l I

 'A loss of instrum:nt cir has occurr:d at 98% pow;r. Tha n;;d fnr a rcretor shutdown is ovaluat:d if                                             l
 ' instrument air pressure decreases below 40 psig.
 ,Which ONE of the following describes the cause and the expected response of steam generator I:;v;is to the instrument air pressure decreasing to less than 40 psig?

! iSt:cm generator levels will be: Mlowering due to Feed Regulating Valves failing as is. l Miowering due to Feed Pump Miniflow Valves closing. l Mrcising due to Feed Regulating valves failing open. l Miowering due to Main Feed Isolation Valves closing. l Amesistl C M M I) I[9eendiseMl[ Comprehension lM Calvert Chffs lQ 11/17/9 l M(000005A208 l M [f] M [3Jj b][EP_E.,j WIdiiiiiislI 3) MDuiiiiij [_2j UnistiDieditgilBl0l [ Loss ofInstrument Air l M [ Ability to determine and interpret the following as they apply to Loss ofinstrument Air. [Fallure modes of air operated equipment eflequer > pppp;?v , m y g "ggg e w ' w l p g g glpw g'mgjg g g gs;.l

                                   ~
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AOP 70 ~I l[Ill.c & V.A.1 1[S,7 ~ )[0 ][NA.~ l [L:,sson Plan l[CRO-202-7D II ll ll ll5.0 l b - Il I L._ - -_ ..j l 11 ll l u,.a.w wwe-wet l . l'5EMMl52kN

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

h T!!stej [ Method cf pressure controlwhen evacuatino the control room j I Giv:n tha following: Reactor power is 98% A fire has been detected in a panel in the control room e supervision has determined that the control room is to be evacuated I The actions of AOP-9A " CONTROL ROOM EVACUATION.. " procedures are being performed I Time did NOT permit performance of any EOP-0, " Post Trip immediate Actions." for either unit Which ONE of the following describes the response of RCS temperature upon abandoning the Icontrol room? Ml Temperature will be controlled at 515 'F - 535 F by TBVs. l M 5emper::ture will be controlled at 515 'F - 535 F by ADVs. l M Temperature will increase until Main Steam Safety Valves open. l 1l Temperature will be controlled by Auxiliary Feedwater flow and ADVs operating in automatic control. M C YIluiiA500l[B l hMIComprehension l W calvert chtts lM 11/17/g l M 100068A101 l '810Ml l4.3! WUniisil 14.5! M E ' PE_] M l 11 IMD$isiisll 1l E- MN"1llisl [ Control Room Evacuation I hM %bility to operate and / or monitor the foHowing as they apply to control Room Evacuation: [S/G atmospheric rehef vatve "ei The MSIVs are closed before leaving the control room and the ADVs are in AUTO., p::Pr?";Wei;WilsediindM'?"_PTW"MTM l T M~M'M j FF#4iiiheiji"Tj fMM_ Ed7d [Lcsson Plan l!CRO-202 9A ll Il ll ll11 l [ ll II ll ll __Il I wggmwmq ;

bliisinIslel hain of components used if fire in cable spreadjn2 room I Which one of the following d:scrib;s the timing of actions thtt are cecomplishad during th3 l performance of AOP 98," Safe Shutdown due to a Severe Cable Spread M[ Establish charging flow within 60 minutes and AFW flow within 30 minutes. l M[stablish AFW flow within 60 minutes and charging flow within 30 minutes. l MlStop Steam Generator Feed Pumps within 60 minutes and start 1 A Diesel Generator within 30 [ minutes. MIStart 1 A Diesel Generator within 60 minutes and stop Steam Generator Feed Pumps within 30 iminutes, M[a_j M[B l M Mem_ory lM carvert chrfs l "M > 11i11/9 l M[000068G132 l MM 13.4! WUsiiiisl [3_8] M [EPE_] Ml il M l il MpiitOII!Y!liiidii!eWiil l Control Room Evacuation l M Abthty to explain and apply all system limits and precautions. O ppemmuywe g gun'pwnumerl gg m w'j perggijggigvgj rgu - . Mg gg;gl ' ~

[AOP 9B !l l{til.C.2 l[4 l[1~ l[ ~~l Usson Plan llCRO-202-9A-6 lI l _Jl ll19.1 l l ll lI I! ll ll l wwwwwpeg ;

LAnalysic'Naturaj Ci.rgulation I

 'Giv:n th2 following p ram t:rs:

0830 0845 Thot 482 482 CET Temp. 587 585 Tcold 467 466 Which ONE of the following describes the conclusion that can be made about natural circulation? Adequate natural circulation has: M,INOT been established because Thot is remaining constant. j M!been established because the delta between Thot and Tcold is decreasing. l 1l keen established because Tcold is decreasing. I KNOT been established because the CET temp. is decreasing. l hj5ikj!gj MilAtilLJ ^MGidl[C_omprehesion lM calvert cliffs IMj! 11/17/9 l N00C.A.13Al03 l MEd L3f %fl6M l3.8! Ml[EP_Ej ML_jj K5iisiiEll'1l

          -~r 2 M             [Abilty to operate and / of monitor the following at they apply to the Natural Cuculation Operations:

[ Desired operating resuRs dunng abnormal and emergency situations eshum aa w pymm mmy g gTammguynyjgy g M " g lgyy g ?Pjjg g g ggwj

 ! Lesson Plan                                                l[SRO 2012                                  ll             Il          ll l(13        l

i 11 ll ll 11 I I

ewwwnweg JI

N M M Ik!$

hUselleiTiiiiiil [Cooldown limitations during natural circulation l 'An turcl circul: tion cooldown is in progress. Whila cooling down with ADVs, which ONE of tha j

;following will cause the most restrictive limitation on cooldown rate?                                                                                     ,

M[lsolating one steam generator. l M [ Complying with Technical Specifications cooldown restrictions. l M l Cooling down without SPDS available. l

  $! Complying with Pressurizer cooldown restrictions.

l

'AsisiiiflIaj MMl[B                        lMMiiiiill[ Memory                     lM calvert cliffs                  lM4                         11/17/9 l d[00CA13K102J MWl[12] WW:l [3_.5j M [EP_E_j Ml il M l 1l 9!NesiiEvedulisiiYl LNatural Circulation Oxrations                                                                                                       j M Md              Knowledge of the operationalimphcations of the following concepts as they appt/ to the Natural cerculation Operations-Normal. abnormal and emergency operating procedures associated with (Natural Circulation Operatens)
          'At ymm mtgar g g w m**"wmv^lpp g g g ] pp g wl g g j gpcl

[Lcsson Plan llSRO-2012 l[_ ll Il ll12 l [ ll ll ....I l ll Il I w % s m "m] W YdiWE*

e

  ' miaWeiiYeudil LRLsponse to loss of feedwat.ir pufpps l

lWhila operating Unit 10100% ow:;r, P ono Stccm G:n:rator Feed Pump (SGFP) tripp:;d dus to c m::chinical fault. Reactor power was reduced to 60% while troubleshooting the failed pump. Op;rction may CONTINUE at this power level as long as which one of the following parameters is imaintained. M5DFP suction flow rate is 18500 gpm. l MlSGFP suction pressure is 260 psig. l M[5GFP speed is 5375 RPM. l MISGFP discharge pressure is 1325 psig. l

 'A moussi l[b _ j M M l[B          l MMUiil[ Memory                                   lM calvert clefts     lM          11/17/9 l M[00QE06A_101 I W W fiiid 14.0 WNiiiEI [3_9' M [EP_E_J M L2j itum.iewEiil E2]

M 1X^ZZMI [ Loss offeedwater l MM IAbildy to operate and / or monitor the following as they apply to the Loss of Feedwater: fComponents, and functions of centrol and safety systems, including instrumentation, signals, intertocks, failure modes, and auto imanual features marW'eg '

~~

Anouser gunm ,mtm g g ww w wnl g y w g "jp;&gii;ijjggy]rg y 'j g g4wTl (1 AOP 3G }[ l(Step B ll9 l(2 l [N.'A. ' l l Lesson Plan l[CRO-202 3G ll ll _JI Il1.0 l ! I 11 lL ll U ll l l w%ggu-mq ; f I Y55$$3NE?

M [L'ocaLoperation of FRVs I

  !A Main FC:dw ter Regulating v lv s (FRV)is b:ing op;rct:d manu:lly ct the FRV wh:n a r: actor trip occurs.

Mich ONE of the following describes the required action? M 5irect an operator to locally close the FRV. l M[Close the Main Feedwater Isolation Valve. l M ! Direct an operator to position the FRV to 5% open. l Mkirect an operator to vent air from the FRV. I l M[o]M LB l 'Mernory i l'M calvert cliffo lMI 11/17/9 ] giOOCE06K102 Id12j Mj {3.7) M [5FEl M.IL_2] M u hysisiiW@EldEi11Gil ).oss of Feedwater I MM Knowledge of the operationalimplications of the following concepta as they apply to the Loss of Feedwater: Normal. abnormal and emergency operatog procedures associated with (Less of Feedwater). M ppmuwm g gm=m -may y p,gggggeg ggg ggg

 !AOP 3G'                                                          } (, '                } Step D.6            !37 '        ' ~ l(2 }[N.5.      }

cagtion l yOP-0 ll l[1~53 ll16 lf3 ll l {esson Plan llCRO-202 3G j{ ll ll l[5.2 m'g p w w wgrj \

-]

MnEfNIS

M %en will Aux Feed Pvmp start following an overspeed trip re. set l

  %ich on] of th3 following d2 scribes the I:ngth of timo from a vclid low ste:m g;n:retor I;vsl condition ( 170") to the opening of the main steam supply valves (MS-4070&4071) to the turbine drivcn Auxiliary Feedwater Pumps?

M Emediately - No time delay. l M[20 sec. l M[45 sec. I

    $[65 sec.                                                                                                                                                      l M k _l M [B                            l M' pplication                e                l M calvert cirffs     lM                              11/17/9 l d[00CE06K201 l M l3.3! M l3.7) M [EPEJ M L_2J IissMiiiiil[_2]                                                                                                       '
  'Millisj [ Loss of Feedwater                                                                                                                                     l Knowledge of the interrelations between the Loss of Feedwater and the followtng l

' components, and functions of control and safety systems, induding instrumentation, signals, Interlocks, U , J modes, and automatic manual features .

Splenesionef an , premywgg g g;*pmeygge;jg g g g 'gggp g eyj g

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gg gg-l ll I ~~~ AFAS tesson Pian l fCRO'34-1 8 !(16,18 ][~ ~ l[3.1 ~ ] I II Il ll ll ll I f-- 11 il 11 ll ll l 3_ ,,. m.,mq i

+i

M [ Procedure errors an_daquired approval for ch_ange l 4 You a performing a " Continuous UsD" t:chnical proc: dura to conduct 4160 volt (saftty class) I breaker operations. You are in the switch gear room and the procedure states, " To open breaker 4160 - D" but the nomenclature on the breaker is identified as, " 4160 V". 1

  ;Which of the below describes the action required?                                                                                                       i (Draw a line through the error, change the "D" to "V" and initial the change.                                                                        l kDraw a line through the error, change the "D" to "V" and inforrn the CRO.

J C M! ontinue the procedure and note the nomenclature error and process an issue Report" as described in OL-2-100. MReceive concurrence from the Shift Supervisor that this is a clerical error and proceed with the

         ! task.

MOMMR I MiiiWiiiiiiMIMemon iM ceNert cirrfs lML 11/177sl e

Ml194001G203 i'M [L3j d L3u 3J M !PWG l Ml il M L_1J hiliiiiiiisistigiiiiEkl I I Knowledge of the process for making changes in procedures as tjesenbod in the sa' sty analysis report p9emwn*w%g?"m;nmm=gj ggg'g l pygaaej

ggggl

[Use of Proceduhs _ ~~~~l[PR1!103 ~~ ~ ~ l[572Via~.~(2) lI ~ ~ ~ T ~lE l [Lcsson Plan l[SRO-204-PR101 ll ll ll ll2.0 l l ll ll jl ll ll l

maisWnminimahvM I e *%

M hentification of equipment requiringj)ost maintinance testing l l Equipment requiring a post mcintencnce t:st or evaluation is idatiftd by: l 1l}he safety teg_which initially took the equipment out of service. _

Allthe Technical Specification LCO tacking system. l M!a blue tag attached to the equipment controls. l

        !$j y ellow dots on the component annunciator (s) in the control room.

l M [g_j M ?jh l@Giiiill' emory M I g cewertentre lh isnus l l 916Whiid(I[ kl!Mi! i!l 3 M EWG] Ml ilIll!!Djii!iliill il M[1_94001G221 3 MM] I I hainniimmiel MoMedge of pre.and post-maintenance operebMy requirements fF"WWWWWWMMWirW**?wj gg FMTigsgijiSSj ggg gg,Ws j iNuclear Operations Procedure l[NO 1208 l[5.iD ~ ~~l I ~ ~ ~ lf~ ~ ll5.AT } l Il li ._ . .l l ll ll ] 1 wwwwwrwg Il C _ ~]l Il ll l j hi@iiNE}$12

M ! Color Cod _e of SPDS alarms l Mich ona of tha following d: scribes tha causs of tha 1/2 C06 pin:l annunci: tor " Unit 1/2 SPDS"? A critical safety function box on the SPDS has changed color from: M[ red to magenta l kgreen to yellow l Ml red to green l kgreon to red l M id I M !R I Ml[ Memory IM carvert clifts IMi 11/17/9 l M 194001G402 l M [53 M l4.11 Mii$iil [PWG l Ml il 'M l il Mi I massiinal i Knowledge of system set points, interlocks and automatic actions associated with EOP entry conditions. Note: The issue of setpoints n' automatic safety features is not spect?.cally covered in the systems se%ns. l pasmnwwwwwmweegrm p gig;;;ii;mirrmm4M*mggwwl I ]l ll lC ll ll I f ll 11 il ll ll- I wwgm eq ; fiiiil@l21Q

  'emswNehl lowetto trippreake s                                                                                                                               j
                                                                                        ~

I5 tic ~nUAG s:t running cnd th) CEDM bus x tb (TC'B 9) clos:d, wh:t is tho minimum numb:r of 1CB.s which must_open for a FULL reactor trip to occur? M[ _ _ _ . . _ l g, - M8 l Aas** 1 O WWI F_~] hlAMil hompreheSion l d c.N.rt Chn. lg ItaW9] P.j p01000K202.] MBhEl L16] M IM) MStr.] isys _I M O h LJJ maiimensiimaml [ControLBM Dr!ye.sysie.m 1 m M [wou.... on..i.n. .r .i.cu.i

a. ,. m .i m ,.r..,. .,i. w in o. ,..$.r.

i. i vonown, p,,,e,w ,n u g y ,.mg.gg g gw-g g g ,,

, [RPS Lesson Plan _j[CRO 591 11 l [.'. .j[46 ][9 03c_j l )l {[FSAR _ _ _ ~l E ~~ l[ Chap.7 FQ 7. !i IL - Il I t1 i _] l_ _._ ll.. jl J L____J L_ __l

 -w ,em                                        -l 3

wnwc s

M [CPP enable command for rod motion!CMI) l

     ;Which on] of the following prc trips / conditions will g:n: rate & CEA Motion inhibit? Assume logic has

b. een.. met - --- - . . _ . _. __

MPCS 1 M High SUR l ME6it _ . _ _ l

M[Tavg/ Tref Deviation

                                                                                                                                                  ]                         l C_] N M lR d M W lMemorf                                                                  l        Calvert Ch'is' ' ]*,.                          11/17/g l M[001000M08_J d L2*j h Laaj W(srsJ meinitiL.JJ hiefass!I il
                               -           [CoDt!01 Rod Odye System                                                           ..                                            l k& M ;IKnoWIedge of Control Rod Ortve System design feature (s) and or interlock (s) which provide br the following                                                      j tPrevention    of excentNo rod movement

{ M l

             ,,_, _ __ w ,, ,, % ,                                                                                                                      , ,

iceosAnsa Pin ~ JiCRO 601 10 j(_ _ _.J [59 l[_ lil 2_j i

                                                 - - _                             _JL            .__ _.__] l               ._.. ~._.... j l           Il      If-         I

_1

t- ____] [_ 1F jl ll- I ow _ my - j 4 1

husstseYM Er'essurtzer pressure contro_I l lTh3 Unit 2 RCS has be:n cooled down using proc-duro OP 5, "PI:nt Shutdown from Hot Standby to

    . Cold Shutdown". The Reactor Operator is preparing to place LTOP in service when annunciator
   ,!" Enable MPT Protection" comes in.

lWhich one of the following is the cause of this annunciator? kRCS temporaiure below setpoint and VARIABLE or SINGLE MPT ENABLE "not" sett o.,J. ] [ Pressurizer pressure above setpoint and PORV Block Valve Open. I dRCS temgerature below setpoint and VARIABLE MPT ENABLE selected. j kPressurizer pressure above setpoint and VARIABLE MPT ENABLE selected. _j

   'Answeil[a._j MjlR l hladquijpu6jlAppil cation                                  IM Cefvert enns                      lg                           11/17/9J 6002000K410,J Mhl[472) WWela:1 L41 wl[ sis] WemelLJ W.e. ele 21 rr:-             val Henetotcopuntsystem                                                                                                                     J U              #aowledge of Reactor Coolant System design feature (s) and or interlock (s) which provide for the fobowing.
                                                                 ~
                                                                                                                                             ~

[ Overpressure protection

g'et p, , - , , ,ym-y,g gje.wmg gm;

   ;RCS Lesson Text

_j[CR0.526 ll i[21_,24 _ }[ ~l[1_4.1] [1E 075 _ jf l[~ ~ ~ ][S30]SiiR[19 ][ l F~ __ l[- )I lI C--)E I m ,w % e., e '11 o MIMisG

emensial RCS.P.Jessure [esponse when sta.rting a RCP l [During normal full pow;r op; rations, one RCP cxp;ri:ne:s increas:d be: ring friction causing RCS flow to decrease by 0.5% l [Which one_o_f_the followjng describes the RCS param_eter response?

YT hoIIncreases, Delta V increasel and Reactor power remains the same. -R M[TEot increases, Delta T decreases, and Reactor power ircreases. [ M k hot decreases, Deata T increases, and Reactor power remains the same. __j MIT hot decreases, Delta T decreases, and Reactor power decreases. l M E_] h 5 l M[ Application l% cohort Cim lM! 11/1 @ M 303000A107 1 M 3 '988irch=1 L3 4J W Es] MI il Mi 1_I i_,1.""1 teel [eactor Coolan! Pump System j nelemmatl @ny to pred'et entor monnot che_nges in paremeters einoctii.d wnh operating the Reactor Coolant Pump System controle incl iRCS temperature and pressure _

%d dannar .. .. p.** h TW '"

                                                     "ll' PW h W l f? 'WWlbM M WNl tFundamental knowledge                    _       _

j{ l (__ ll l[ ' Q A. ] L___._.__.__._ l[. II[ ]I II I[_ l L ll _][ !L E _11 1 m.,w w 1

                  -                                                                                                                                     l
                                                               - . k,

taann.fasis] [;CP_ Seal FailurtjndicatJon

                                                                                                                                                          ]   '

IGiv;n the following conditions: ; RCS Pressure 2250 psia Middle seal cavity 2200 psig Upper seal cavity - 2050 ps!g Bleedoff cavity - 130 psig Scalleakoff flow - 1.7 gpm 4Which one of the following indicates the seal (s) that have or are failing?

M[oier seal l M[ower AND Middle seal 1 M jMiddle seal l , M; Middle AND Upper seal l MICdIR lM LApplicatjon IM calvert cle. lW 11/17/o l M[603000A404 1M @] M ['33 M [sysj Ml ilMl 1l h##'I LReactoLCoolantEump_ System. 7 TUtny to manually operete and/or monitor in the control room RCP 6eal differential pressure instrumentation r m , , , _ ,,_ m - g _ p e m ,,,, dCP Lesson Plan ]lCRO 10617 ll l[13 ]l _ l(7_ _j [ - ___ ll l[ _][ ll ll j l ._ll IE ~iE 11 l[_ 1

  .%7                                ._
                                              ,- i                                                                                                          -

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_. .__ _ _ __ - - -. _ - _ _ _ _ - - _ _ _. - - - - - - - - - - - - - - ~ - - - - - - - - hj [CP Shaft Seal HX Tube tak Indicationand Act#ns ] lW(integralLheat exchanger 1_____hich one of the following is indication o kHigh RCf 6omhonentTo~ojing Water (C'U@) outlet temperature. l M[ow levelin the GCW Head tank. l l M hllevelin the nCW Head Tark. 1 Mhjgh RCP CCWoulet flow. l hasser I[aj h. keel [R l IDeanW!ff AMd j Memory lg ceNen cirn. lMi itnvil

   $jy0T000Kj03_ J M [3.3l @) [3_6j M [SYSJ Mj( Il M l il MMd [ReactoLCoolant Pump _ System                                                                                                                                                  l M fKnoMedge of the physical connections an$or caute4ffect relationships t>etween Reactor Coolant Pump System and It RC,P toal tystem                                                   ,,

Aneuer

                                              . . e.        ,~

p. [ yy .m .

[CCypesspn Teo __.jtCRO f 113 5-8 J (__ j(OH 13A j[ I[9.11_] 4 L_ __ .. lio R L.-.. ... ...

                                                                                                                          .jl                               ._] l          11      7

[- ~ . ._J F 1[- li_ JI il I

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M besponseig.yC_Ueyttfallure l iThe following pl:nt conditions cxist:

1. Unit 2 is in MODE 1.

2. VCT makeup is in AUTOMATIC.

3. CVC 500 controller (Automatic Divert) is in the " AUTO" position.

4. VCT level transmitter LT 226 channel fails LOW.

5. VCT control room level indication supplied by LT-227 is normal.

6. No operator action is taken.

l LWHICH ONE of the following describes the system response? ItlkCT Inlet / Divert valve CVC-500 opens and diverts flow to the radwaste system. l OkCT makeup valve CVC 512 closes. l 1l { Receipt of VCT Level LO annunciator. l O! Charging _ pump suction shifts to the RWE l ihaswer 1 CJ miss e l?R l beAWutkP*lLApplication IM Calvert Cliffs lhj 11/174 ] [004000A309J 3l10 Valse:l[3g ISADE:l L3,2] *ese80eisl[SYS_j Wesetsl{ il M l Il t_ T 12"Emmel [Qhem! gal and Volume _CgntroLSystem l

              'Abildy to monitor automate operations of the Chem # cal and Volume Control System including VCT level Answet

{geme mer g ge~n~"rq*v rlp g g g lpe g mj g g g g yl PVCS Lesson Plan l[CRO 10716 F-

                                                                                  }l                 l[29    ]f  l f2.1.1_]

ll IF~ il 11 F i 1 a m _ ,,4 11 C 11 li H I NNM13C44

Mhotsl Minim.um. letdown backpressure ] %Ich ONE of tha following lists th3 condition csttblish;d to prcvent flashing in th3 Ch:mic:1 and , Volume Control System (CVCS) Letdown line between the Letdown Heat Exchanger and the Letdown ' Flow Control Valves? , M, Maximum Letdown flow. _ l Alhaximum Letdown backpressure. l dMinimum Letdown flow. } dyinimum Letdown backpressure. ] hoewee j { *tsamhj LR l Mles.il[ Comprehension l'W ceivert chtts lgt 11/175] EjIOO4000K411 } Mhht1l[6 M [@ jii!iiiEEd LSYS_j M$ijgjl iljgg,ggjjjl 1} t_T :: ^ " %I [Chempland Vojume_Qontro1 System I

             , Knowledge of Chemical and Volume Control System design feature (s) and or interlock (s) which provide for the following                     l Temperature' pressure controlin letdown kne. prevent boinng, lifting rehefs, hydrauhc shock, piping damage, and burst l

M 'el Am== p . , - - -,.g.; ., ,w.n,

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m LCvCS . _ _J[CR _10716 } [.. ..._...._.j [2 0 l[_ l[2.3.2 l EE.i~ - _ _T_~~__.] l__

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'tuMuse fasesl [RCS cooldown in SDC                                                                                                  j

{Which oro of the following describes the method of controlling RCS cooldown while on shutdown

,coogngpn.Un_it H__                       _

M Manually adjust the SDC Flow Controller (FIC 306) and manually adjust the SDC heat l bxchanger temperature controller (HIC 3657) to attain the desired cooldown rate. _ _ MManually adjust the SDC Flow Controller (FIC 306) and allow automatic control of the SDC heat lcxchanger temperature controller (HIC 3657) to attain the desired cooldown rate. MIAllow automatic control of the SDC Flow Controller ( FIC-306) and manually adjust the SDC heat xchanger temperature controller (HIC-3657) to attain the desired cooldown rate. NAllow automatic control of the SDC Flow Controller (FIC 306) and automatic contro heat exchanger temperature controller (HIC-3657) to auain the desired cooldown rate, beweij[cJ WuIsiiGii81[R I MWl[Cp!pprehesion lg carvert cwes lM, t sit 7/9 ) hij[6050006102_.] '80vn: IL3Jt a' noWI L33J hl Lsys J WMIL 3) W**ielE31 E' '-' '- Tulel [ResidualHeat RemovalSystem I h M;l [bilty to predict an&or monnet changes in parameters associated WRh operating the Residual Heat Removal System controls includin

                  !RHR flow rate Aam*              -

p.r ~mpw yg c, -

                                              > ~ g p-      g               g ger           -j.           g            gyg lECCS Lesson Plan                                   l[CRO 718                l [ .. .._.. .._ _j[OH57                 l[30.7,.8 l ll f
          %.m m 0; 11                       L            _ C'              il      -- J I           I We0Nm2

Ml Jources of Makeup to CCW Head Tank j 5: lect th] Norm:I and Alt:rnata sources of m:k up w:t:r to the Compon:nt Cooling Wat:r H:ad Tan,k?= -=-_._ -_. - dNormal- Condensate System hiternate Firewater System YAormal- Demineralized Water biternate - Reactor Makeup Water kNormal Condensate System prnate Domineralized Water System i AIN~ormal - Demineralized Water Sysyem Alternate - Condensater System A

' nswerl[d']emminsinistin            IW[Muory                                   IW ceivert cm.                             IM                        sitiWg M[008000K10$           l NHesis:l[0] lORDMl [3,1J d {SySj Ml 3] M { 3)

E_^ "t! ""meel [ component _Coogg yvater_ system I MM;l [KnoMedge of the physical connections and or cauto-effect relationships between Component Cooling Water system and the fo

               !5ources of makeup water
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[CCW Lesson Plan _j$RO-113 5 8 l ( _._ ._ ... .j {14

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  'gggg,tgld [CC_Wpump angnment                                                                                                               i During full pow r op;rctions, the annunci tor clarm "CCW PPS SIAS Blocked Auto Start" on C13 has                                             l
 ! sounded.

Mich one of the following describes the cause of the annunciator?

M Mphp 13 Breaker is open and its disconnect is closed. l M 5I 'S signal to CC pump 13 and the pump breaker falls to close. l M yCpump 13 handswitch is in Pull To Lock. l M 50 pump 11 Breaker is_open and its disconnect is closed. l Mic_J haidaiidiR IM[Copprehesion lM c tvert ente. lM' 11/17/9 ] lie.j[008000K401 l hk!lkha!l[U) M L31 thiiniiid Ers_J MEf M La) MassaMiNBa.1 [CowonentCooing.watetsystem I ka amamed pows.oo. or compon.ni coonna w.ter s .t.m v o.uon i..iur m .no or w.riockt.) wnien provio. vor in. voiiowing guiom.ie .i.ri or .i.nody pump

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y , g i. , wgp% ,yg g _g [CCWSystem t.esson Pjan -_ _ )(CRO 113 5-8 ll _. _j[12 .j[ ll9.3 ) I

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JE C~ il IF__]E I j bes *@CS

huompeMI iopeptionJIPressurtzer Pressure Controlin Man al l "Giv:n the f:llowing conditiorss: Unit 1 is operating at normal operating temperature and pressure. All systems are in automatic. Pressurizer Pressure Channel X is selected for control. Pressurizer Pressure Controller PIC 100X is pieced in MANUAL. e PIC 100X output is reduced to 10%. W ujh no further action, which ONE of the following describes the plant response? M [Uo~rtional heater output increases causingpressere to increase until spray valves open. _ l MIProportional heater output decreases causing pressure to decrease until backup heaters cnergize. Ml Proportional heater output increases causingfressure to increase until a reactor trip occurs. l 4g. ,_._ Proportional heaters will cycle at a lower setpoint. J M ic_] W Fl heashdeel l icomprehension JMceNed cirns lg, IU1W9j M[6f0000A107_.J #vaha'd M W L32] h isys_] W L_2j M D '22 ~ 'I Z Dl [Pressurtzer Pressure C_ontrgl System l [ Uiho predict and'or monnot changes in parameters estociated wth operating the Pressuruer Pressure Control system controta pncludJnp_ [RC_S_ preasure eghmuenW Answer 7,w % , m .- g g,7 g mq

RCS Instrumentation _ l[CRO-6218 ll ll24 29 }{' lhi }

BMMMM2

M !cospnents supplied wnh_ signals ftpapressure controlsysterp } ft.o RCS pr:ssure control syst:m (Ch:nnel X & Y) provid:s signals for which on] of the following !9ffups of contr.o!s?__ _ _ _ ___ __ _ _ . .__ =___

                                                                                                        = _ , _ = _

M jpray valves and proportional heaters. _] M[ Backup heaters and TM/LP trip. ] koportional heaters and safety injection interlock. ] kProportional heaters and PORV open signal l M!a_] hl[R l WWISerno_ry _ Id calvert chffs lM isit 7/9 ] M[6}66006302__j RM [33 M [3 SJ M [SYS] M L2J W L2) MI [Prusurt(er Pressure _ControLSystem ] hity to monnor automatic opetatens of the Pressuruer Pressure control System including PZR prenture W ~ ,-,,___, ,,,_ w rm - p g c, 3Cstnstrument Lesson Pan l[CRM2Q8_ __J L J[2o 23 jl 142__j E__ __ ZT ~ __.._ - IF _ E ._. J[ TR- JI I E~~Zi m w,,, mere 1_ ll _] L__ "L - - JE IE 9

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M ' [essurtz;r_l.eyeLControl f l I Giv:n th] following conditions on Unit 2:

      -- operating at 100 % power
      - pressurizer level and pressure controls in automatic, selected to channel Y pressurizer level and pressure at setpoint The operator reports the backup charging pump starts and all pressurizer heaters have de-energized.

Mich one of the following is the cause of this event? Mijfie controllingpressurizer prossure tiansmitter failed low. _] kThe controllingyressurizer pressure transmitter failed high. ] Mhe controlling pressurizer level transmitter failed low. l M[The controllingfressurizer level transmitter failed high. l M [c ] M d E I e' ssett.landj[Cornprehension lg cabert clirti lM i sit 7/o l M01._1000A201] MWl @ WpWehml M M [SXSj M[__2] WDespl] 4teteiumvelude#hl Eressurizer_l.eyelControLSystem _ l W Ibility to (a) predict the impacts of the following on the Pressuruer Leni control system and (b) band on those predictions, use Pfocedures to coneet, control, or mnipote the consequences of thou abnormal operation'

                    , Loss of PzR heeters---

7,_,-, m , _ .

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[R_CS Instrurnentation l[CRO-6218 ll ll l[5.0b_]

                                                                                                                ...- . . l[17 . - -
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M [PressyrlzellevelControlandletJowntolatJon j hich opof the foIlowing is a function of the Unit 2 pressurizgi;v l/ptcssuro control syst:m? M yecie~ase letdown flow to minimum on increasing pressurize level.

                                                                                                                                                                        ]
                                                                                                                                                                        ]

lj hovide a START signal to the backup chargingpump on increasing level. ] dlncrease letdown flow to maximum on increasing pressurizer level. l

fjyeenergize all pressurizer heaters at a 13% deviation from the control setpoint. ] [Qd I MffDoDf lMj.stvert Cliffs lMji 11/1N9] EjLO11000K101 1 M1dliEj lag PM L31 M [ii s-] ,$2!!tj L2] hs!ioniinnell_2j _ i Asteint!nt##aSilal EressyrtzeLLeveLContrlo Sgtem l Rhd KnoWIedge of the physscal connections and/or cause4ffect relationships betv'oen Pressurtter Level Control System and the following

                             ,CVC8 M I gyom,~~%g any mg yag% gp% - g g                                                                                                                               ggm; icvCs Lesson Text _                                        J[CRO 10716                            JL         . _J[OH7                                        ll   l[2.1.4 l                   l EZZZZ                                         _ ~~~~ ' l [                                      l              CL                                           li    1[      ~l E ~ ~~~                                                          JL                                1              RI                                         Il   JL       I
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M Auto swapoveton RAS . I Upon R:circul: tion Actuation Signal, valv:s aro r: position:d aft:r v:rifying HPSI pump flow. l

 ;Which one of the following describes the valve repositioning that occurs on an RAS?

outlet valvqs afgp(QSEDL

 @N[utomatically and containment sump discharge valves                                                                                OP l

l djmanually after the containment sump discharge valves are OPENED manually. l Mmanually and c5tainment sump discharge valves are OPENED automatically. l l kutomatically and the containment sump discharge valves are OPENED manually. l M[cjM[R I M(Memo _ry lM.c.Neri chfr. lM, 11/17y

 )PJ!o13oooso2_)seta!id L4JJ )!!!!3!!!Ed Luj aid &d LSrSJ 3,gijitjL._1)DE*iiitILJJ husseeneseMI [ Engineered Safftyfeatures,ActuatiorLSyslem w              Amy io monw .uiom.i. .p.,.i on. or in. one.n..,.a s.r.e, r..iore. Actu.i on sy.i.m inoivoing I

op.,.i.on o, .cio.t.a . uipm.ni y _- Answer p,m._ m,m7 g , ,, . . ,_ p g y gm. yg g g ,g

 )CCS Lesson Plan                                         _ _ l[CRO 718            jl ..
                                                                                                    .. l[2o        l[

l[30.2_ l [ _ s, _. _ J L__ _A . _. X CR E-] 3 -

.,4

W Es/TD Monn.otalagn l [During a normal react:r st:rtup, which one of tho following is usca t_o monitor count rato doubling?_J

                             ~                                                                                          . _

MMCount Rate CMr517~~ j M Audio amplifier circuits. ] [ Linear Power Channel. l M[ Shutdown Monitor. l Wid_.J Wiss#I[R l WWlhemory EW ceivert cim jg! 11it 7to l M Q15Q00A107 l 5Wadiio:l @ 'ameipsemeil [3JJ WeiWl[sys_j M.tesplU glaseniepj f ]

$ntelWWwouesp4l huclearinstrumentation system                                                                                         l MM Ebiiny to preditt antor monRot changes in parameters astociated wth operating the Nuclear instrurnentation system cordrols includin'

[changea en boron concentration __ } 'Sapannebee'of Answer p. s x . 9 n- g er g - w m g g; g p,<y e,g .,l

Excore NI Lesson Text l[CRO 571 11 } (_ ... ......_.. j [32 _ _]l l{3.1.3 l E~

m wn we 1 J Em___m___Il . - .J E R L_ ~] E-~9 i l h ) 3 l l

itsweefeAl hr;ssurtzelleveldeerease i Ediv:n tne following: Reactor power at 100% A transient hos caused pressurizer level to decrease to 8" below the programmed level. j lWHICH one of the following is the response of thepressurizer level control s

dBoth backup efiargingpumps will be running, with letdown flow isolated. l M[4o backup charging pumps will be running, with minimum letdown. l kB[oth backup charging pumps will be running, with minimum letdown. l [No backup charging pumps will be running, with letdown flow isolated. l M3)_J MWIh I h@l[ Application lhNlmlcalvert cmie l h j~ 11/17/9] d[016000K102J'MWehe:1 L._4*] ##W1 L3 j W [SYS I M[2] LN (( Ef '!_ ' '" 1 thel Non-Nuclear Instrumentatio.n System l l kA thj [ Knowledge of the physical connect 60ns and'or cauto-effecEelatbnthtpt between Non-Nucleet instrumentation System and the followl f g es_ _ _ . namensmener Answer Y?':V'"" "'m %~" "W:l Y'& M~%' W* m * * ' %M&Q CC'~ l ,RCS Instruments 1[CR0. -6218 __J L.. .. .. Ji14 Il Is.1 I [__.I.$__ - _ _. jI IL ._. .I jl_ II I L_ IF IL 11 lE _ll 1 mwn ser a==e

r 1 feesMMlSC]

M fW Regutting syst:m act6on_on dnning n bypasualye l fhe Feedwat:r Control Syst:m is in manual with the plant holding at 80% pow r. The fccdwat:r

   >r:gulating bypass valve for Steam Generator 12 drifts fully open.

Assumipg no gperatqr actippd2 Steam Generator level will: M[iriirease to the Hi Level set point, the feedwater regulating valve and Bypass valve close, with jteam Flow > Feed Flow, a reactor trip from Lo Steam Generator Level will occur. M will remain constant as the feedwater regulating valve closes to compensate for the increasing gl. increase to the Hi Level setpoirit and remains at that level as the feedwater regulating valve tgycles open and closed. M increase to the Hilevel trip setpoint closing the feedwater regulating valve and the bypass valve cnd causing a turbine trip and reactor trip. M b_JMIR I M,j[Applica!!on ld Calvert Chffs lM' 11/17/9 l M[059000.A211 l M.V.d!El LT03 W LJ'j hanEl[sys_j Mi il ime.arsiej [))

  !_ilf 'Mael Sainleedwater_ System                                                                                                         ]

N'j hiidy to (a) predict the impacts of the following on the Main Feedwater System and (b) based on those predictions, use procedures to porrect scontrol. or mRgets the consequences of those abnormal operation' Qilure of feedwater control system W at am w <

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[SG & FWCS Lesson Plan _ ____j[CRO 10315

l[ D28,29 l{ ' ][1.7 } [~ ~_ _ _ . ~ I[ T ill l[ l[ l C

i w%gw - 7 I C-R L_ _ji - 1 3 PM F ktn a

hj [FW Regul.ating Valves action on turbine inp l TThe ptnt was operating at 20% pow:r wh:n it tripped on low Stram G:n:rator bvcl. Tho Main Focd

W;t:r Regulating Valves closed and their bypass valves ramped to 5% feed flow.

I Which one of the following_ conditions caused this valve response? kAuxiliary contacts on the Reactor Trip Circuit Breakers. l kuxiliary contacts in the Steam Dump Permissive Circuit. ] M hndervoltage on the Control Element Drive Mechanism buses. l kSteam Generator water level less than 12%. l M5]M"R I'M bpplication lM cervert chtte l' M 11/17/s l ! M[6f910Fgis_._J anes l[e5 W Loj M!sXsJ WEll M[7 l E 1 "Timmel Main Feedwater System j hd ! nowledge of KMem Feedveter Syeiem design feature (e) and of interlock (s) wNch prov6Ce for the following

              ,h. omate feedwater reducten on plant tnp m            .[

p.;,, , e., . ,, en. ,., _ y y , (Main Feed Reg. Lesson Plan j[CRO 10315 ll i[19 _ j[ .j[1.5 j C._ _ - __

                                  . . _ _ . -  lI     _

II' . II_ }{ l[ q~] em.wn - - 'I _] fla

M [EDG operation during_surveijlances _ __J

 %en stopping Dhs:1 G:nerator 1 A following a periodic t:st, lo:d is first rcduced to cpproximat:ly 450 KW before the output breaker is Tened.

My is load reduced to th,ypower level? MIAllows for cooldown of the engine. l M The engine may overcrank if power is HIGHER. l OiThe breaker has a manual interlock above 4500 KW. l M[he engine trip circuit is energized below 400 KW. l M[a_J MIR I M[Co_rpprehesion lM ceivert cies lMi 11/17/o l g064000M07 l M M M [2.9j M !SYS I M L2) M L2j Nl [Emergengy Diesel Generators l Abilty to prodact and/or monnot changee in parameters secociated 'vnh operating the Emergency Desel Generators controm including Mainteirung minimum lood on ED/G (to prevent toverse power)

 , , , , _ _ , , _ ,, m _ ,, , _ ,, m                                                                                                        m .,

[ol.21A ll Il ll ll jl J [i.;sson pia F l[CRO 048 2 lI ~ ~ll ll l(18.0 l I ll IF - 11 11 11 1 m%, y .;; ; hiEnM18Cl

MM hCP Se3fal)urefequjre_ments l Giv:n the following conditions for RCP s:cis:

    . RCS Pressure is 2250 psia.

Controlled bleedoff temperature is 243
F.

    . VCT pressure is 50 psig.
    . The upper seal pressure 1250 psi.

The middle seal pressure is 1500 psi.

I Which ONE of the following describes the status of seal damage and which parameter (s) indicate gt seal damage is occurring? MISeal damage is NOT occurring. l M[eal damage is occurring as indicated only by controlled bleedoff temperature, l [jISeal damage is occurring as indicated by controlled bleedoff temperature and delta P between

       !the upper seal and bleedoff.

MISeal damage is occurring as indicated by controlled bleedoff temperature and delta P between

       !the middle and upper seal.

M!d_J MHiM48888j 5 l hWlLApplica!!on 1W calvert cints lMi ii/t7/o ] M000015A122J h L4 0' M Tl WIEPEJ Ml ilMi 2 il hilllel LReactor Coolant Pump _Malfungtl2ns I [ Ability to operate and / or monitor the following efe they apply to Reactor Coolant Pump Malfunctions {RCP seal failure /melfunction higemusheist h if controlled bleedoff cavity temperature is greater than 225 F, damage is occurring to the seals. If the delta P between the middle and upper sealis less than 200 psi or the delta P between the upper seal and [bleedoff cavity is less than 100 psi, se al_ degradation has occurred. pmy wwur g- . s

                                              %3g                           g          g gpg                 wg                    gyg 8CP Lesson Plan                                                          }(CFiO 10617         } l.. ._.,         '} {13    }[   ' l {7        l l

( IL -. .._.d ! ll II l I ___ ~g _f ll . jl ll IL_.J 9

                                                                                 +     +

hun!heVM ICethn line rupture. 1 I5hich ONE of th3 following compl:t:s the st:t:m:nt? I Automatic operation of the CVCS isolates a letdown line rupture outside containment on a CVCIS by Elosure_of;_ M CVC 515 on high differential pressure across the regenerative heat exchanger. _] M[CVC 516 on high pressure in the 27' West Penetration Room..

                                                                                                                                      ~ ~)

M[CVC 516 on,high regenerative heat exchanger outlet temperature. l M[CVC 515 on high differential pressure in the 27' West Penetration Room. j WOMIR } haa!!!NLlai!dj LApplicatjon lM cetvert ektts lhj 11ti69] DjioboF22A201 I M 17 W M 1{ M }[5] M L2j W ER 11 i ^ ' 1Wesl [ Loss _oLReactoLCoolant_ Makeup l M Abuy to oeiermne end mterpret tw fo%wmp as they apply to Lots of Reactor Coolant Makeup M**t.her tharggg hne leak egets___ p ,, y e. ,.5 , _ p. i

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[CVCS Lesson Plan _ ___j[CRO 10716 jl !) JL 1M_) [Z Z Z Z G il~C Z = - ]f~ -

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MBind ActiofLQn_H1jetdownlemp. ] Whib troubl: shooting a loss of 1 tdown, it was noticed thtt wh:n CVC 515 was op;n:d, tho valve

 !imm:diately closed due to high letdown line temperature.

lWhich of the following is the proper method to clear the high temperature condition so CVC 515 can

 .be r; turned to the open position?                                   __                                                                              j N Open the letdown level control valve and wait until temperature reduces to less than the alarm                                                   '

[value. YSecure charging _per OI 2A and wait until temperature reduces to less than the alarm value. l M bycle CVC 515 while opening the letdown level control valve. l 4 kCycle CVC-515 while increasing flow to the letdown heat exchanger. l Asimis.r l b WWI!_R I hM1bppiteatjon l M calvert cirrt. Jg 11/17/o l M.Aj[000022K304 I WW:l [3,2] WIDWahml [~3] M [EPEj j193J L2j IMe9sipj [_2.]

 ^ C di"~ Yl Ilos5 of Reactor Cootant M_akeup                                                                                                       l

, Mh1l OMedge of the reasont for the f0llowing responset 86 they 8pply 10 Lost Of Reactet Coolant Makeup

                              $=. --- -

em.e Answ.e gy. m -y . g. g, ,

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[CVCS ___ l[O128 _ [6.7 I[22 l[29__jf J [CRCS Lesson Plan l[ l[ _ ..j[ Il lI2.1.7] f- ]f C j f- _]l il 1 me w n *.se- so e I. I tass 5 Mini 2

                ..                                -       .        _ _-     -    ___ __ _ . . . _ _               _        _~        ._--- _.-_ -

htwisl [ Pressure channelfailure _ j

    " Unit 1 is at 100% pow;r with Ch:nn:l X PPCS selected in cutomatic if the Chann:1 Y controll:r             ,

pressure input fails low, which one of the following is the equipment response that would be

    !obs:rved?

M Pzr CH 100 Press alarm, proportional heater output remains the same, B/U heaters 12,13, and (14 deenergize. M f5portional heater output goes to 0%, all B/U heaters energize until all heaters de-energize at [22_7_5Jsla. M[zr CH 100 Press alarm, all proportional and B/U heaters remain the same. l [_)[Pzr CH 100 Press darm, proportional output goes to 100%, all B/U heaters on. l M Ii ] b M [R } MAApplicatlog lM calvert Cies lhI 11/17/9 l h!J[f0002LA21L.__J 3##88m'I[Il M [4JJ MI[EELJ M@jl il W9isiplL.2; f ^['T '~SITillDI Pressurtzer Pressure ControLM_a_lfunction l M aMagentll Ability to determine and interpret the follow 6ng as they apply to Pressurtret Pressure control Malfunction: (NEE ___ - ___ - p yy , g , m 7. y m ,, p - gy y, ,q [RCS Instruments l[CRO 6218 ll ![42 lf l[6.0 J [._________. . ll II li ll .j[ l E ]L 11 j[ II IF~~~1

    .                    , , , , ,              7                                                                                                             ,

0

MM [esponsa to a failed Pressurtzer LeytIJnstrument l I Giv:n the following conditions:

Unit 1 is operating at 85% power.

All systems are in automatic.

l, Channel Y is selected for Pressurizer level control. l Wilch ONE of the following level channel failures will cause a pressurizer pressure increase? M[ Channel X fails high. l Al[ Channel X fails low. l MChannel Y fails high. l

M$hannel Y falls low. ~) M Ic ] M IR I M.l[Comprehenslordd cetvert cliffs lM ti117/9 ] i W L3A M L3A h (EPEJ M L. 3!M O M[000028A201 [ Pressurizer L.evel Control Malfunction I gilty to determine and interpret the followng as they apply to Pressurget Level control Melfunction. n*2R levet indicators and alarms 4 d p y - evygg"m. ..,,,ynnwml gyg p'""gesass 7 lI h M M M N ! [RCS Instruments Lesson Plan }.!Djy6218 l[. l[16 ~ lI 'l[5.0 ~l j

                                                                  'j ['~'m~~~                    l[                    ll     ll   Il         l
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M EGTL vs. SGTL l I.ist 1 is being shutdown to HOT STANDBY duo to a St:cm G:nerctor Tuba Lcak. geh 0NE of the following indicates the TUBE LE_AK has become a TUB _E RUPTURE 7 M {5ih one charging pump running, letdown isolated, and pressurizer level can no longer be __ I icontrolled at setpoint. MIWith one chargingpump running, and letdown flow at minimum. R MiWhen letdown flow combined with the tube rupture flow exceeds 45 GPM. l M %en charging flow reaches 92 GPM. l I ,J .b R l M}[Comptebension lM calvert cliffs jg; 11/17/9 ) I ME i 000037A200 l M @) M [4}j M AP_E_._] M L2j M [_2j

                        .IIEBf (Steam Cenerator Tube Leak                                                                                                          l Mhd ' bilfly to determine A                and interpret the following as they apply to Steam Generator Tube Leak:

s IS/G tube failure ' gy y , _I y - . _m , - ,,,,, g_ , nmy, y y, NC'ss RCS Lpakagg ](VI .6.F.2. _. j[27 LLgsson Plan lIAOP.2A l[4 }L l R 5RO 202 2A lf~ jil l[ l {1.0 l L -- If- _ If

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t1; i l thMuD2

M h_se of designatedj0st!ume.ntall.on during use of EOP 8 1 h[9no of the following would rcquiro th] tripping of only one RCP in cach loop?

J M[A]teaniGenerator tube rupture has occurred, RCS pressure is 1825 psia. l M 5bntjInient Isolation Signal has been received, RCS pressure is 1800 psia. l

QSrnall Break LOCA has occurred, RCS pressure is 1725 psia. l M[4[o~ss of Coolant Accident has occurred, RCS pressure is 900 psla. l~ [Q N I [Co!!pitiledort l M C, e,lvert Citffs lM 11/17/9 l

 $$J[00cEosMot..] Mal! Led [Fil M L4A: BeniiiillIEP_EJ NWL2)ML2)
  'erWunstwemmisel functignst ReMvery                                                                                                                                         l MM                        lbilfly to operate and / or monitor the following at they appy to the Functional Recovery:

Components, and functions of cotMI and safety systems, includeg 6nntrumentation, alonels, intertocks, failure modea, and automatic manualisaturee prwywwe~ gn7-m,r ms g y g ggn g m. g g.gCg (Functional Recoyery_ _

~~

___j[EOP 8 l[lV.C l[9 ][8 l[N.A. ] ILes' son Pian _ l[iFEU~5010 ][._.._._. jl ll l[f0 l l _ _ _ _ _ _ _ _.__j [__ _ l. .jl II_ ' I

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s<< l

h@e!seY M IEOP 8 Entry

l [Which one of tha followin'g states conditions requiring EOP-8 entry? l Sjil two or more Safety Functions are not met in EOP-1 with parameters returning to expected

              ! values.

d6feactor Trip occurs due to an unexplained generator protection fault. l

          $ if any single event has been diagnosed with parameters not returning to expected values.                                                l 4'
                                                 ~

M!!f a serious condition exisis post-trip for which an optimal EOP has not been identified. { o hisweil{ ltisias6miWl[R l IOesie#EGNell[ Memory lg catvert cliffs

~-

lWiiiitide:ll 1 tit 7/9 ]

        $j[00CE09A201 l WWl [3[14H6WE:] 14.4! 'tecten:l [EPFJ iif*'eis11 21 !ssioer==sl L2j
                                                                                                                        ^

Viit?" "'n! LunctionalRecovery 1 M hd (Ability to determine and interpret the following as they apply to the Functional Recovery: j lFacday conddens and selection of appropnate procedures dunng abnormal and emergency operations. SuplenMien'el w m-i gm w9e mggper wpjp g g g g ]pg g wg g z- ss yg

                                                             'lf
                                                                        ~~~

[EOP-8 ^lhB.2 }

                                                                                                             ~~S~                l[8 TN.A.          I Esso ~n Plan                                          l[5RO 201-8                  ll               ...j l               ll   l[1.1       l L_.                                                   lI                           I I .-    - -._.. j L                 ll   Il            l y;                                                  .

i ,.

         'hi!IM] [Re_quirements/aproval to change logs                                                                                           ._ j

' lDue to a design ch nge to th3 main turbina lub3 oil cool;r, it his be:n d;t:rmin:d tha periodicity of , jrccording the temperature reading is to be increased from once every four hours to every two hours l

         !during a one week burn in period.

Mich one of the following is the minimum approval for this chaage recurding reou'rements M FOSRC , l MPlant General Manager l 1l! Shift Supervisor l M[ Control Room Supervisor l

        'AE!Liutt.l[c_J M [S                            l h ed! n Me! Memory            lM calvert cwfs         lW                    ttnal d[i94001G101                    I hk [3JJ Dill 9Mj l3.8! M1 [PWG j M I il M l il
                          - m,g Matinament$ i fKnowledge of conduct of operatens requirements.

Emidensteis pg nmrw mwrmgnnememy3l g4m m-l pygmnf ygQ ggg;l

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[ lesson plan )[SRO 204404 ![14 ~ - ~l [ ~ l[L.Ol3} [ ll l[ ll ll l[ l il ll __!! ll IE I mww -gm] ] 4

M ! Fit for duty . call out I i You cra th] D;y Shift CRS and it h:s besn brought to your cttention that a non-emtrgsncy call-in is i ne:ded for the CRO next shift. At 1620 you reach an operator who is willing to come to work and was the last one on the call-in list. The individual states she is fit for duty but, just completed drinking one glass of wine during a late lunch at about 1330 hours. W of the below describes your actions required for filling the call-in need? _hich _ MDirect the employee to come to work and report to the Nuclear Security Shift Supervisor. l Ninform the employee t.he can not come to work since the five ,iour abstinence period requirement would be violated. , 5l Inform the employee that the Shift Supervisor will waive the abstinence period since greater than one half of the five hours will have passed by the time the shift starts and she should come to work. NRevise the watch bill such that she could stand a Non-licensed watch and another employee

        '(with a current license) could stand the CRO watch.

M[ajM!S I Md[Comprehesion IM catvert chffs lh 11/17/9 l NEl[191001G104 I M [2] %MI (14j M !PWG l M[_1] M l il , w insno rm ais w l I i . namilsammel Knowledge of shift staffing requrements. l , pw*Mgymmengggpemmw;l rgg"w'j pngqijjggipqj gg g gg,q l

~'

IFitn:ss for Duty FUogram ~~ ~~ llSE 1100 R[S.12 B ]IE8 } f~ ' ~ ~ll } [ General Orientation Training l[ Module 9 ll RI ll llN.A. I I Il ll ll ll ll l meseminisibisEWinsisiiinii*W4 I hiiiBE#3#5 i 1

hintliteN ' Action for Safety 5 lated equiprnent having been det:rmined to be_ inoperable. I IDuring your Shift Sup;rvisor insp;ction of tha w:tch, you obs:rva tho stirt switch for thD 11 HPSI

  ! pump is in the " pull-to-lock" position. The unit is in MODE 1 at about 88% power the time is 0535                                  ;
  ; hours.

t j I I I [You cre required to: Ml review the operator's log to verify this condition has been logged and the control status board [:fisci this condition. M[immediately declare the 11 HPSI pump inoperable but functional. l M inform the Nuclear Engineering Department and assure a review of the switch position and goveming design bases is completed t y 0935 hcars M ssure the redundant counterpart is verified operable within two hours and an entry in the CRO's

        , log shall be made.

bewer l[djh[s I 'ceindevuMiissl[comprehesion o IM c.ivert cart. IM siti7is l Ml194001G110 I heiWehEl [2]j WiIsiEl [g be8Ml[PWGJ Mesell il Mesisjl 1l C2':"%l l l hAMd

                  ~ Knowledge of conditions and hmitations in the facihty keense.

hgiennisniid deswer pynyr*rwp e g g zeg wammqlp g g g jpy g ggg g g ~ gprj [NO 1200 ~ ~ ~ 'l[AO-1200 ~ ~ l[5.12.A l{~~' l{~ lI~ l heS$on Plan llSRO 204-100-2 ll ll ll ((19 l

 !                                                        }{                         dI             !!              ll  ll           l

_ m. 77,gm;; , NMN.N.bh

  'ensedesiTeiisl [ Low power operations I

he unit is in a " reduced inventory" condition with 13 Service Water Pump out of service. Emergent or priority repair is needed on the 11 Service Water Pump breaker. What is the lowest authority to approve this work in the reduced inventory condition? M[uperintendent - Nuclear Operations l M[ General Supervisor - Nuclear Plant Operations l M[ Shift Supervisor l M[ Control Room Supervisor plus an independent Senior Reactor Operctor l

  'Aiisiniil[b] kisiiliiill!s                   I MisiiiiEi[Eid! Memory                              I%iissiid:1 caivert cim      IM             imml M[194001G_122J bMI[2d UNOVEusi:l [3J M#lIPWG l Ml il ISR O W I I 1l E 1^L' Ml l l

messamamil l l Ability to determine Mode of Operation pynwy e m g ygemen irrr rlppggg-lFFMWMTSTd hissenAlCO!Ml ~ ~ [ CONDUCT OF t.OWER MODE' INOd103 ~ l[5.1K4 ~i[29~ ~~l[~ ~~ l{' ~ 'l

 ! OPERATIONS

[ Lesson Plan llCRO-203-5A jf" 'll ll ll3.0 l I ll ll "ll l[ H m%g% eq l kkIkkI3$$f$ g --

M lfei dte [ Control / review / approval of level 1 procedures

lWnn r:vi; wing for cpprovrl cn IMMEDIATE CHANGE TEMPORARY APPROVAL FORM for

  ;Cct: gory 1 equipment, which one of the following is criteria that would allow you as the Senior
  ;R: actor Operator (SROlto approve this change?

[Alection is being added to include the valve line up for non-safety equipment associated with i

        !the surveillance.

l M' The valve lineup for safety equipment intended not to be operated will be changed such that the l normally open discharge valve will be closed during performance of the procedure. M IThe periodicity will be increased from daily to, "once every it hours." l

    $ $he material list is being changed. (supported by an approved enginoring evaluation).                                        l W I[d ] W U n l[S l WUihlEGMILComprehesion IM catvert chffs lg                                                           11/17/g l dL194401G211 l '90Wl L2A WMl l .4*} WI[PWGJ MesilI 11 Wessel[~11
       ~r
            ~w:x~ y l W                Knowledge of the process for controlkng temporary changes hplammenam~of Answer pwmecewaarg gemmm:ew wl gg gg'g pggwrj ggg gpu l
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iPrepr.. tion & Coritrol of CC Tech. Proc. ' ) Ntachment (' l( 11 l[ l ILesson Plan l[SRO-204 PR101 ll~" l[4 ll I!2 l [ ll ll Il ll Il _)

 % %_ -my                                                                                                                         ;

e s @4

MILisiljaTepisj LSafety1agging1NO-1112)

                                                                                                                                                                  ]
   % n:w ci:ctric motor h s be:n install:d on en cxisting pump. Tho work ord:r rcquires the motor to
   'be ch:cked for proper rotation.

i I lWhich one of the following actions are required to remove the red tag from the motor power supply? iThe suction and discharge valves are to remain tagged. dProcess a supplementary clearance. l NProcess a modification to the tagout. I NAuthorize the clearance for all tags in the series and invoke the use of human danger tags for cquipment that is not ready to be returned to operation. NAuthorize the " lifting" of the tag for the power supply and re-install the same tag after the rotation check. j Answer l)_J hisisissiiuslls l besnieveWl! Memory lg4 lM calvett cirrts 1 tit 7/9 l l $!194001G213 l MMil[3] Wielsii:I [3J esinosiil[r ] Wililim s ll 1l WNuigEi@ll j} DniII5eeenemenfuel j j nasmilisiiimd !

                  ; Knowledge of tagging and clearance procedures.
   ,N pre ww;pargwg , enr^                             ' ' 4gr g % % -j g ~ g g j g
                                                               ~
                                                                                                                  ~

gg'7x; g [ Safety Tagging Procedure ~ l[NO 1112 l[5^ ~ ~~l[28 ~ lf'-~~lIs) ~l l Il ll .j l ll ll l 1 Il Il h 11 11 l m we,e,,,,,s , mi i IN'I!NNI!I3$ l

bosensTiipisl LEA _t. determination given plant conditions and ERPIP 3.0 l Tha unit is in MODE 6, fuel hindling is in progr:ss cnd 35% of the fu:1 h:s b::n remov:d from the coro. The FHS informed you at 1710 hours that a fuel bundle that was on the refueling machine had b:come disengaged and was dropped into the vessel. lTha control room received a valid " Fuel Handling Area Vent"(RI-5420) alarm at 1720 hours. At 1745 hours the site experiences a power outage and the diesels fail to AUTOMATICLY start. fwo diesels were subsequently started at 1835 hours. i LUsing ERPIP 3.0, which of the below is the classification and category for this event (s)? kUnusual Event RU2 ] Mite Emergency ES1 _ l MUnusual Event EU1 l MAlert EA1 l IM'I b _J 'RUiisOssfl[S l bonnelveUMl[Co_giprehesion l@ catvert chffs a llbiii^siknie5l 11/17/9 l y][194001G404_J WWI L4m0' '* aoul lA3: W I:PWGj 156eiE6ll il,MR,6eriiUl[ 1I m - s- gg MALRisl!aflieft! ! I fbnity to recognee abnormal indications for system operating parameters wruch are entry-level conditions for emergency and'abnormf gperat ng procedures l Sapaamation'of Answer pye gg:rgj ggpq g ypsewwnglypg g g jpgeg eqjg

lf ~l[i.Ci# 81

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[ Lesson Plan l!CRO-113 r n

                                                                                  ~~ll                l[6-~

I Il ll ll Il IL_ l I il I L_ JI il Il I 'Meterial Requised toilhiinnleason "W ?:l ERPIP 3.0 l IEIDIE1NY!

M LCEDMCS failed lift coil l On Unit 2, if a Control El:m:nt Asstmbly (CEA) lift coil fails on c fully withdrawn CEA. Which one of the following indicates the response of that CEA? l Tha CEA will: Mfall into the core, [ Mnot fall into the core but will respond to motion commands only in the inward direction. l Mnot fall into the core and will not respond to any motion commands. l Mnot fall into the core but will respond to motion commands only in the Manual Individual mode. l

   ' M (c _ j M i5iWl!S               l M[Comprehesion                            lM calvert cirffs            lM!                          11/17/9 l M[001000K103         l M L3J bMl 13.6! M ISYLl Ml il M l il
   '_^f T'"TMl LControl Rod Drive System                                                                                                              I g              Knowledge of the physcal connections and/or cause-effect relationships between Control Rod Dnve System and the following CRDM M ~st w 4' iMWRmm?D5?neamensives"P""NYM"Wl FMiniidiiiisies seisnbei l RMFeiiiismiiWj h6 @ WeiFil
                                    ~          ~

[ Control ElemeM Diive System 1. esso' n TexI l[CNCM0550 ~ ll d '~~ l[9 lI28 ~ ] {UFSAR l[ Chap.3 F9 3.3-15 ll jj7.4-6 ll ll l I ll ll l ll Il I mmwamnq l f hbWk

Itusiilleefisinl bpply cooldown limits

                                                                                                                                                           'l r

At 0830 a Unit 1 cooldown is in progress with Teold loop t;mp;raturo ct 210 'F. tWhich ONE of the following is the earliest time tb9t temperature can be at 180 *F7 { k848 } M(1000 l M(1012 l M[1130 l Assuiisiil{c l M@h 7 M89411NsWSl[A. ppoilication 1% calvert cirtfs l'h l! 11/17/s l M[002000G112_j EM l2.9? M [4.0j M [SlS_,J M[_2l M ] tl^ %M1tlis! [ Reactor Coolant _ System I kamiiimilist:1 Ability to apply tcchrucal specifr.ations for a system. 'WW A888# # 210 to 184 F @ 20F/hr = 78,184 to 180 @ 10 F/hr = 24, Total = 102 min. Other distractors use various cooldown rates. p;*:m7mmemr g g ryggnygyglpp g g g g jpr g mgj g gyj [ Unit 1 Technical Specifications ~ l( ~ l [' l[s4 4 28' ' )( ll l [OP5 ll ll i[13 ll35 ll } j '.esson Plan llCRO-203-5 _jL..._.. ll ll l[1.0 l w w g my:erl.LCO 3.4.9 including fgures l DN1Yhi?$s;

M [ Safety.jnjection Tank Operability Status ] Giv:n th] followitig Unit 1 control room and ch:mistry rcports:

       . RCS pressure is 1600 psig.

RCS temperature is 360
F.

l . Safety injection Tank #11 A boron concentration = 2250 ppm.

Safety injection Tank #11 A level = 194"

      . Safety injection Tank #11 A pressure = 225 psig

All rods are inserted.

   @ich ONE of the following identifies the qgerability status of #11 A Safety injection Tank?

M fihe Safety injection Tank is NOT required to be operable. l M[ Safety Injection Tank level is above the allowable level. _j MSafety injection Tank pressure is above allowable pressure. l M1oron concentration is bel 6w allowable concentration. l M[d] WiiiiiGisfl!S I Wiiiid GTAiiallbplication lMJ caivert chrfs IM 11nal [ 06000G1.12 l MMd 3 MMl [iOj Wiiitsiid 5YS .] WiIiiiiiiil[._J2j M5iiiiiiiiil[2] RT)M'lusl [ Emergency Core Coolino System l M! , %bihty to apply techncal specifmat:ons for a system. MW pymmemagy g g ypra m m*jg g g g *jppeg;;ggj;jj;g g g g ggpl

                            ~
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[Technii,al Specifications ~ l[ ~~ _][3.5.1 j f~ ~ l f~l JI3/451

 !Lisson Plan                                             } lCRO-71                   ll             Il        ll      ll32.4    l i                                                        ll                          ll           ll          ll      ll        l w ggm' ,m q                                                                                                                     ;

4 , s .2

' 1 M [evel channel failures effect on PZR PCS l l (Which on2 of th] following d: scribes th2 r;sponsa of c Pr:ssuriz:r Lcv;l chrnnal failing LOW?

    , Assume the failed channel is the 3 ELECTED channel and no operator action is taken.

M%ll heaters will deenergize,ietdown goes to minimum, standby charging pump starts, P.ctual

         ! pressurizer level and pressure increase, the reactor trips on High Prepsurizer pressure.

[All heaters will deenergize, pressurizer pressure decreases, the reactor inps on TM/LP. l NAll heaters remain energized, letdown goes to maximum, only or.e charging pump remains ON, hetual prest urizer pressure and level decrease, the reactor trips on TM/LP. M El heaters remain energized, letdown goes to minimum, actual pressurizer level and pressure increase, the reactor trips on High Pressurizer Pressure. AnswsliafiiiiiiiiGise![s i72finisRC9gorehesion lheimej:lcaivet em !)iiisesiiisi sis 7/9 l M!OJDQGr(303 l MUnhistl la2j hAOWehe:l l3.71 '61[SY_SJ WasisiislL2j wnsiiiist L2; m Ml [ Pressurizer Le31 Control System l M Knowledge of the effectinat a loss or me! function of the Pressurtzer Level Control System will have on the following PZR PCS

gymsmar ge ggg sitenw*:wg l pgg g'j pg:g*ngj ggg yg ggg-l [RCS Instruments ](CRO-6218 ' ll if41 ~ lI ~ lfii.0ti l I ll ll Il ll ll l l ll IL _jl ll 11 J wwwwppt ,

                                                                           ,$    , 4

M LVOPT ., l Giv:n tha following inform tion:

D:lta T power indicates 43%
Nuclear power indicates 41.8%
Variable Over Power Trip (VOPT) setpoint is 46.7%
Vari:ble Over Power (VOP) pre-trip setpoint is 45.2%

4Which one of the following is the new VHP Trip and Pre-trip setpoint after the VHPT RESET bit.to a is

 !d:pr:ssed?

MVOPT = 50.2%, VOP pre-trip = 48.7% l MNOPT = 51.4%, VOP pre-trip = 49.9% l [jiVOPT = 53.1%, VOP pre-trip = 51.6% l MNOPT = 55.1%, VOP pre-trip = 53.6% l s'sspjbjMLS I M fpplication lg calvert ciifts lQ 11117/9 } M[0_12000A101 I d I .9*I M [3.41 M] lSYS l M [__2j M L2_j 66l [ Reactor Protection System l IAbilRy to predict and/or monitor changer in parameters associated wth operating the Reactor Protection System controts including- [Tnp setpoint adjustment g^ii ppmesmesw=mmMN1FN6WDENFF1'M p M g Eri _- . _ l ll ll il ll 11 I i 11 ll wwwwwm jl 11 11 I P55Ei!Minild \

M stessurizsr Pr:ssura Trip Inhibit I [Wh:n the High Pressuriztr Pressuro Trip Inhibit kcy is instill:d in the bist:bla trip unit in th9 Rt:ctor

Prot: ction System (RPS) panel, it closes contacts inhibiting which portion of the High Pressurizer
Pressure trip?

M. Blocks the Diverse Scram System (DSS) input from that channel of RPS.

Ml Disables PORV motor operated isolation valve.

Ml Prevents Power Operated Relief Valve (PORV) operation by use of the key on CO3. l M[ Bypasses the PORV actuation from that channel of RPS. l hasaw I[q_J hiiihiiGniell LS I hiiiltlisijsiell; Memory IM ceivert curt. IMiing!s[ itnng] M F2000K604 l M k3j M [3J6' M]lSYS l bIis][_2j M L2j "$fetti!WSullI@iMl deactor Protection System i l Knowledge of the of the effect of a loss or malfunction on the fogowing wtW have on the Reactor Protection System: Bypass-block circuits g. pypergye ggvgyrproppq l p'g g gej pppggg g_ ~~

g gggwl [RPS'Lcsson Plan }[CRO 591A11 ' l[ _,.j [50,51 ~lf ~ ~ l[10.3 l I ll ll __j l ll ll l L w g ge,m mwg ll C il 11 II. I

                                                                $k.bWW$3$l$

 'ennue.YMI [ CSS. Pump aMnment 7

lWhich one of the following describes the respose (if any) of the Containment Spray System to a l SPURIOUS CSAS signal?

   $[Two Containment SprayJumps start AND SI-4150/4151 open.

l Miwo Containment Spray _ pumps start but SI-4150/4151 remain closed. l dOnly SI-4150/4151 open. l dl system lineup does not change. l Massiil[c_j WMimill[S_ _l bosnisse GW l[ Memory Ig carvert cim. Itiiiiimoe:] iiii7ts ] MIO26000A301 l MMil[L3' WNil L4.5) N1 LSYS._J M61L_2j WWII il sysesiidsvenusesThiel [Containme1 Spray _ System l Ability to monitor automatic operatens of the Containment Spray System including-Pump starts and correct MOV positening 3 W if Amewer prmnweryyg ~~twemmesm-lp,g g g ggy g;ygjg. g gn- g j

 ' CCS Lesson Plan                                  ~ ~ ][CRO-71-8                                                l[~                ~ ~~l[54                '~ l[   ~ l(14~.1" l L                                                      ll                                                         I 1..._.-. . ..... .. ....._j i            _ 11     II                 I E                                                      11                                                         4                            il                Il   11       _]

m_gm,3 PNdillRlNE. l l

iguessesTessl IResults of too low of TSP Volume j Tha Trisodium Phosph:ta Dod:cahydrata (TSP) stored in the Unit 2 containm:nt b:s m:nt will im intain the pH of the water in the basement following a LOCA: Mess than or equal to 7.0 to ensure radioactive lodine is scrubbed from Containment Spray Water. l Ngreater than or equal to 7.0 to ensure radioactive lodine is scrubbed from Containment Spray l Water. Mss than or equal to 7.0 to prevent corrosion crar, King of matals inside containment. l Mgreater than or equal to 7.0 to prevent corrosion cracking of metals inside containment. 1 Answei j { WiiiiiiLsisel!p l cisanWi0iiikj[Memog lM calvert cliffs lg, 11/17/g l M026000G409 l M M {3j M [3&' M [SYL M L2] M I il C ^i "Ml . S stem i k&Abdliiimied;l [ iKnowledge of low power i shutdown Imphcations in accident (e g LOCA or loss of RHR mitigation strategies) 8=W~et ,Amewer pyw"rywfm w g g p * ^ge mpg pp g g > g >jpp g gjr g _ g l ggygl [TS_B: sis l[ Unit _2 TS ' l[L l[B54 5 2~ lf _){~ l [Lcsson Plan J 5RO-21212 l [.. ll ll ll5.0 l I ll IL .. . ..! I il Il I anne. ins w e.iensnense.a " 4 1 tMB@iM~

M [S/G_ Overfeeding l

!Which of tha following actions is us d to directly mitig ta a St;;m G::n:rctor ov:rfeed ev:nt?                                                     l M % closure of the Main Feed Valves (MFVs) to 50% of full power flow in one minute following a
       ; Reactor Trip.

I trip f of only one of the running Main Feed Pumps on the receipt of a Steam Generator hilevel [ signal. M % closure of the MFVs and full opening of the Bypass Feed Valves (BFVs) in one minute following a Reactor Trip. M[An opening of the BFVs to the equivalent of <5% of full power flow in one minute following a l Reactor Trip. hessiil[djM!S l biUiUG86Ml[ Application lM carve t chffs lhj6iimpeni:l 11/17/9 l M059000A203 l MWNisilLul M Lrj iliiiair.ii1!sy.s_j mmiiiiiiiilI 11linoaliiiiiill e t.lf~"~~NI [ Main Feedwater System I {Abdity to (a) predict the impacts of the following on the Main Feedwater System and (b) based on those predictions, use procedures to

                 ! correct, control, or mitigate the consequences of those abnormal operation:

l Overfeeding event Sqplenden'Of answer pge s e myyy g pennen7) peg" g g ')pg g wyjg g g g g ggml [ Main Feed & Feed Pump Controf }(CRO-1031d 'll }h9 l[ l[1.5 l [ ll ll jl ll ll l l n li _ _ jl n li l m%g , myj hiiis[i!8ENI55

M LEDG operation durLng surveillance and ESFAS signaloccurs, l [he 1 A D):s:1 G:nerator(DG) is running und:r lord during periodic t: sting. Tha DG is parall;d to th3

  'ESF 4KV bus 11.

What is the diesel generator response to a Loss of Offsite Power? Th2 diesel generator output breaker will: Mremain closed, will pick up all required loads, and continue to supply power to the emergency l_oads on bus 17. Ml remain closed, will try to pick up the required loads but will trip on overcurrent. l M limmediately trip open and remain open until manually closed. l M will trip open and reclose to bus 17 if no faults exist and normal and alternate feeder breakers re open. M [u ] M y 'S I hEules.liig8l(Application lg ca vert cuffs r lg 11/17/9 l M[064000K411 l M L3Jj M310j M iSYS I WL.1) M L2j j MMI LEmergericy Diesel Generators l ) M 'Knowdge of EmerDency Diesel Generators design feature (s) and or intertock(s) wtuch provule for the following: Automatic load sequencer: safeguards ' g. ans== gra3*$imsNWrg,jjiiiiiiiiiiiihre?Mm"mn"i j ((p,,m,~ggiiiiiis; 6'] p0;Pgwit j igg g gggl

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[DG L:sson Plan l l[CRO-48 21 ~~ l[ lI42~ ~ T' ~ ~l[f 0~l Il ll .)l ll ll l I Il 11 11 ll II I

p. ,7,xy 4 I

s i 4

Mj [EOP Action oD HiCt. Rad. ] During perform:nce of Unit 1 EOP-0, which ons of tha following radiation monitors in en clarm status would require Alternate Actions to be performed? M[ontainment l kWide Range Noble Gas l MMain Vent Gaseous l

MMain Steamline l

            'hlU                           [S           l MMl[ Memory                                 lM calvert cliffs       lgj                      11/17/9 }

M[000007K321 l M [4] M Y l4.BI 'M [EPE_j M L2j M L2; MWhpl [ Reactor Trip i Knowledge of the reasons for the following responses as they apply to Reactor inp: Actens contained in EOS for reactor tnp

pqvptew?pggggr*merymemmj pg'gg*j pmg'gej tgg g gggl

                                                            ~                              ~~
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[1 EOP-0 ~ lI ~ hlV.F.3 l[N ~ ] [3 l[ 'l

[50P-0 Lesson Plan l[SRO 2010 lL ll ll ll14.0 l l ll II __ j l ll ll I
mwem watt ;

1 J N dII M N [d

     'eusemesTweel ESDE_ys. SBLOCA l

lWhich ONE of the following parameters will discriminate between a Small Break LOCA and a Steam Line Rupture, both occurring inside containment?

M[ressurizer Level

Myressurizer Pressure l MContainment Pressure l M[ Cold Leg Temperature j hower 10 Wimisteisl 5~~l keyeheiW 1; Memory Ig Caivert Cim I g h j: i tii7/9 l M[6ooo09A201 lh0Vsu3s @ WW:1 l4 8' 9esees][EP_Ej M L2j MM L2; 5-_~1""^"1NEl [Small Break LOCA _ l h $legnessW$ %bility to determine and interpret the foilowing as they apply to Sma'r 3reak LOCA: I

                  . dctions to be taken, based on RCS temperature and pressure, saturated and superheated
                                                                                                                                     .[

Amewer p y e ., _ ,- q. , .

                                                   .. g                                       -

p ,y .;g. q JSDE l[EOP 4' l[li.'B ![4 ~ l(3 }C l [OCA l[EOP 5 llll.B }[4 l[8, ll l l Lesson Plan

     .m               g gg % ~*~>yp llSRO 2015                                            ((                  [             ll        l[io        l WiifEiMi                                                                                    \

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       'tueedseTepiel 5SF mainte_na.n_ce I

hich ONE of the following mechanisms is utilized to satisfy the RCS Pressure and Inventory

       ! Control Safety function during a Large Break LOCA event?
          .a 1][ Containment Spray _                                                                                                                                                   l kressurizer heaters                                                                                                                                                       l MIieactor Coolant Pumps l

MPSI Pumps l huomer l[dj Ylisi.Edl[S l MMll Memory l% catvert chna _j kiisseessl, 11/17/9 l M 900011 A115 l A0Value:j @ WVelue:l [4Jj Wl[EPEj '800'ersupl[] Weisipll il

       'SpeissialBMMI [Large_ Break LOCA                                                                                                                                           l Ability to operata and / or monitor the followmg as they apply to Large Break LOCA:

RCS temperature and pressure IlCll""" l pw yo; > , gy cw ;vyjpgggg'jpgggppggj' gpj ll

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M [ Core HeaLR_emovat Maintenance durino Large_ Break LOCA l i Which ONE of th3 following is ustd to check th:t Two Phass N:tural Circut tion cnd Breck Flow is fsufficient to maintain core heat removal in EOP-7 " Station Blackout"? M fore Exit Thermocouples indicate less than 700 F. l MIhot - Tcold delta T is less than 50 F. l MCore Exit Thermocouples indicate less than superheat. l M[ Steam Generator pressure is decreasing. l M!c lM[S I M.l[M,emory lM calvert chffs IM' 11/17/9 l Mi600011 A201 l M 12j M 14.7) M][EPE I Ml 2l M I il Mnl [Large Break LOCA l AbMy to determine and interpret the followtng as they apply to Large Break LOCA: Actons to be taken. based on RCS temperature and pressure saturated and superheated pyer*Wywy g gimmgewmmlp'g 'g g ')pyr g wyjt g g ggnrl fLssson Plan llSRO-2017 jl l{ ll ll3.0 l l ll ll jl ll ll l 7 . m,,,yf , NNkIN3

IReduced Level Definitions I

   %ich on2 of tha following is tha d:;finition of " REDUCED INVENTORY" rcftrring to tho Rsactor
   ! Cool:nt System?

M!the middle of the hot leg l M[the bottom of the Hot Leg l

     $ !4 feet below the reactor vessel flange                               .

l M 7 feet below the reactor vessel flange _ l M[c_J Wi!!It4Miiill[S I MV!rdl! Memory Ig caivert chrt. IM i siirts l d[000025A102 lM[3J) M [31' M LEPE 1 M1L2j M L.I

   'BIE!iiRYUiiiREERIsl [ Loss of Residual Heat Removal _ System

_] M Abilny to operate and I or monitor the following as they apply to Loss of Residual Heat Removal System: RCs inventory Vessel Flange is at 45'. Reduced inventory is defined as level less than or equal to 41'with fuelin the y m m e r w g g n m m p p y ygg j p g g g -lg s g w jpgggggp;l

{UFSAR~ ~If ~ j[9.2.7 l[9.2' 5 ~ l(20 ~ l[N'A }

   !Lcsson Plan                                                   l[CRO-203 5A                               Il    _ .._j l              ll    ll1.0        l 1                                                              11                                         I L._  . _ _ .J I           11    11           I w.w3 umw l                                                                                                                                              l

     'tweeisaMI LHazafds associated _with new fue! damage l
    %ich ONE of the following would be the primary radiation hazard if new fuelwere damaged?                                                          l dneutron l
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Ml[bd MailisTosnl!s l M~isimilMemm

                                 ,                                                     Ig ceivert ciirt.                      IM-l            11/17/9 l M 60036A_101 1hovaEil[L3l hftoVaEil [3g "asiainij [EPE_J WWiiiil L3) im**aarl L3)

M[Nullein! LFuel Handling Incidents _j M 9lMggdgit$ Abtilty to operate and / or monitor the fobowing as they apply to Fuel Handling incidents-Reactor butiding containment purDe ventilaten system g - pwv3~em pe g g mwmw;3qylyp g g g ypg yj gur . _g gg .7g [AO_P-6D ll' ~ ~ ~ ~ ~ l[Ill,C.1 !!6 ][10 l[' _j [Fudamental Knowledge ll ll ll ll j[ l I l[ l l._.. .. . .. . ...j l ll Il I w%g% q .

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MYeiiile] [EOP_05 ESDE actions following dryout 1

The following plant codtions exist:

1. A steam line break exists upstream of 21 MSIV on Unit 2.

2. SGIS has automatically initiated.

WHICH ONE of the following conditions could result if a steaming flowpath from the unaffected steam generator is NOT established immediately following dryout of the affected steam generator? (Rapid repressurization of the RCS and subsequent Pressurized Thermal Shock (PTS) conditions.l M Inability to open SIG "22" MSIV due to pressure difference created when affected steam generator reaches dryout conditions.

M % rapid decreaFlin T-cold of the unaffected loop resulting in an interruption of natural circulation. l

     $ % decrease in the core exit temperatures resulting in an interruption of natural circulation.

l Muisw l[aj Wienisliiise4llS lIsiiiinissMiisllComprehesion lW calvert cliffs lQ 11/17/9 l M$LOOO40K106 1 'iWiWiEl l 3.7) Wheamisl l3.8l Esiillionil[EPEj Ml 11 M l il g7# T' ^ ~"1911El l Steam Line Rupture l [ Knowledge of the operational lmplicatens of the following concepts as they apply to Steam Une Rupture: ' [High-energy steam kne break considerations sapisiuthene[ Asusser pwpwmeegggvggym>wmewm] lyggg"g>l pgegwggg __. g,ng [EOP 4 Basis Doc. ll lllV.J (5 l[3 ll l l Lesson Plan l[CRO-201-4-4 ~ ll Il ll l!7.0 l rgg y - em q M iMM3NIE

Feistiiiied !!soiation of s>G ossoe l

  'Given the following:
       -During an Excess Steam Demand event, BOTH steam generators are suspected of being affected.

MICH ONE of the following identifier, the steam generator (s) that should be isolated? 1llBOTH steam generators, since a potential exists to over-cool the RCS. l hl!ONLY the steam generator with the highest Tc. l

     $l[ l lTHER steam generator, since it will aid in identification of the affected SIG.

l

     $l$NLY the steam generator with the lowest pressure.

l El[d_l WiiiiiUisillLS I hasamis1Giisiil[Comprehesion o lM~calvert cirffs lg itniigl MLOOOO40K304 l hDWalsil[4JJ Wbees:l [4]j M [EPEJ Ml il WWll 11

y;y:y?'"" heel [ Steam Line Rupture l Mj { Knowledge of the reasons for the following responses as they apply to Steam Line Rupture:

                %ctons contained in EOPs for steam kne rupture M5

( perm m;g g y wygam;lpg g 'g lpy g e;j ggpg [ESDE ][EOP-04 ~ l[lV.G l[11 l[3' l [N.A.' } [ Lesson Plan llSRO-201-4 ll jl ll l!6.0 l L_ Il ll I L__ ll Il l m%gawq ; MNkbME

  'M:.tietsj [EOP.101 Strategy l

IEhich on] of tha following d:scrib;s the ov:rriding strctegy cmployed in EOP-7, St tion Blackcut, { prior to power availability? [Utilizo Natural Circulation to: M[cstablish and maintain SDC entry conditions. l M! maintain the RCS temperaturo constant. l M[ maintain RCS subcooling. l

    $!obtain a maximum cooldown rate.
                                                                                                                         ,                      l MsEEj[c~]Esisistils I hisiaiinfeliifllComprehesion                  lg calvert chffs             lMlj            11/17/9 l M[00005SA202_j M i4 41 W^61 L43 M lEPE I M L_jj M l il e N"YT11eil [ Station Biackout                                                                                                             I A' bC ty to determine and interpret the following as they apply to Station Blackout.

[RCS core coohng through natural circulation cochng to S/G coohng p _ , ,. m y --,,,,mge w _ - = - w p m ,q g g g w w y i H I F~ ~~ il n 11 1 magmungg ; WiMMWi% i

M !NC Flow cstablishment during LOOP l

  'Following a Loss of Offsita Pow:r, n:tural circulition flow can not be accurtttly vsrified foi cpprox.

15 minutes. Which one of the following is the cause of this time delay? MReactor Coolant Pump Goastdown. l M[ Steam Generator inverted Delta T. l MLow Steam Generator Levels. l Mincreased loop cycle time. l sisiE]W__J BiliiiGiiinlls 1 MiiiiilusiBiasil! Memory Ig cervert cwf. IMgBEiill iinno l M!000056A251 l M i .3*] M l .4*l M IEPE I Ml J Mjl 3! 6l ILoss of Off-Site Power i M Abildy to determme and interpret the following as they apply to Loss of Off-Site Power: DeltaT, (core, heat exchanger, etc.) ppmmeWe gniggjijiisgTgymmml pgggjijgijjirl pygmyj pg g ggqj [ Lesson Plan QSRO-2012 ll ll ll ll12.0 l l Il Il ll Il ll l wwgwwmq l \ l J

M ILOSs OLA5Unclat;n. actions I h loss for 15 minut:s of which of tha following, with the cecomp;nying AOP, will rcquira cntry into tho ' Em;rgency Plan? M30FfEfil126VU~~ ] ML @VE5i125 VDC l M AOP 71 11208/120VAC Inst. Bus l M[OP 71 21208/120VAC Inst Bus ] Ib ] b . M l ) l Memory l Calveri Chffs ] 11/17/9] M[000058k203_] M 16] M 19' M [pE] M[_2] M [2l M' kOSS_0[QC_f014f j hbuy to c~ .ormino and mterpret the following at they apply to Loss of DC Power: [DC loat's lost. trr.psu on to operate and mondor plant systems g nys m % ,,,,p *m + 'wcfre n ele w-(IM M g gr1 [AOP 7J __ ~ _l[ IMA._7.c ll77 l[3 j[N.A. l His~odP[i[ai" [~ __ _ ]ERO 202 7J l [...._._. l[_ ll l[2.3_j maww w ws.ww ~ L ._ 1 I [ n a s D _o

h MI [(co for spectrig Activity. I

 %n increase in pow r has just be:n perform d and the Dose Equival:nt lodin31131 cxc Ods the Jimit_ Operation f.or the next 100 hours is limited bases on:

1l)3eIof DUe Equivalent 1131. l lj spercentage of the units total yearly operating time. l. 1lIrcte of change. l M[c]MmMs I hresWIMemory lg'c Nert em lgI iinne] ,

 .9J[000076G134J M [2A Md [2f M [EP_EJ M3CJ Ml 11 Nhl S6grLReactor_CoolantActlytty                                                                ,

l M (g. _ -- uy io m.ini...i pnm.ry .no ..cona.ry pi.ni cn.mi.iry wanin .iio di. imn. r,_ m ,c_ - , ,c, _ ,g c , , LIechnical Specificat60ns _]l . j[3 4 6 l[3/4 42 4 l[216]iN.A. , l l Eh55 L _ _d"5:==$$$==j 9 [621212 IL JI .l L__,_] E0 I om,w m en-

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M 'Jocreased letdown.nogon.tilacs acMty I I One of the first cetions the operrJor is instruct:d to take LAW AOP 6A " Abnormal R: actor Coolant lCh:mistry/ Activity" on increase.1 RCS activity is to adjust letdown flow. I Mich_one of the following statements is correct as to the adjustment and the reason? M' Increase letdown to maximum so that more RCS water can be diverted and processed by the haste management syajem. M(Decrease letdown to minimum to minimize the amount of radioactive letdown that is flow groughout the auxiliary building. M [ Isolate letdown until the cause of the activity increase can be determined.

                                                            ~
                                                                                                                                                              )

M keresse letdown flow to obtain the rnaximum purification flow.

M !d _ J M [s l bsannholesid[ComprehesMn IM c wert cwv. "aggf isnml M000076K_30$l NHdiNGl[2 9] MM [3&} M IEPEJ EW L.11 M LJJ 1 M1Hbl SWLReactof_ Coolant A_ctlylty l [ Knowledge of the reasons for the fol6owing respontes as they appy to H6gh Rtactor maant ActNity: [ Corrective actions as a result of hs0h thselon-product radioactNRy levelin the F CS L p,mm w g-ym.,7 m e mg gmgggi h0P6D_ _~~_ _ _ _ ~ _dl l[V.A.3 Ji7 l[8 llN.A. l [Lessonflan ___ ~l[CRO 202 6A 3 l[ _ .jl ll l[4.0 l E' il-]l Il ll Il 11. 1 m% , m,- i7 y W % h $t:0

M [techntpaLSpecirk-22. RCSleakage1QO n Entry ! l "Giv:n the folkrwing Unit 1 conditions: e Steam Generator 11 has .03 gpm tube leak. RCS Identified leakap is 9.2 gam. g Mich ONE of the followir,;;is the maximum allowable leakage from 12 Steam Generater?

M[.03 gpm l

MLOS gpm l 8.gpm

C[(0gpm ] M C M [S I$M[ Memory Ig ceivert chffe 1Mi t tit 7/o I j M000A16G133._j d [H M [4pj M [ER_] M L 3J M L3] MDl IEx_ cess RCS Leakage l Abilty 10 tecogn 9 indicatione for systern operating parameterm whk;h are entry. level condRions for technicet specifications

  .'        ~'W [13pm leakage toial primary.to secondary through the steam generators and 100 Opd through any one S/G
                   'is allowed.

p.n .,, m ,, , yy .py-m9 l g.ggl (Techn.ical Spectrications Unit 1 }l l[3.4.6.2 )(3/4419 l{188 l[N.A. l [L)sson Plan ____ _____

                                                        ,___J [CRO.212 1 2                                      ll         ll         ll          l[4.0            l alutedelltsensedius tsaudemos ^ "TTech Spec Section 3 4.6 (RO. Exam only) Per the LO.                                                                             l E' k' +

_j

M j:Dasis for SGISpakage Limits ] IWhich ONE of th9 following is the basis for the Tcchnical Specification limit for sto m g:n:rator lt:kcge? hh] Technical Specification limit:

~~

M issdr'eith'at (fie leakage rate used in the analysis for a steam line break accident is NOT cxceeded. MIcssures that the exposure to plant personnel that could occur following a Steam Generator Tube hupture is limited. M issures that at the rainimum rate, a leak can be rejiably detected. l M cssures that the exposure to plant personnel that could occur if a atmospheric dump were to

     .o pen is limited.

M;'ajM[S I hadjed_llMemoE Ig ceivert chris lM! 11/17/9 l d[00{ 05??25] d [2] d (3]J M $PEJ Ml il Ml il

MRioj [ Excess Stearn Demand I (NOI?fge opstes in technmal specifcahons for kmRing condnions for operations lal ... ensures tha the dosage contribution from the tube leakage will be limited to a small fraction of Part 100 limits in the event of either a S/G tube rupture or steam line break. p ,, . ,e g : r em rp gp 14 g eyg $ S __ _.. ._. .__ ~ ~ ~ ll k ...-. J[B 3/4 4 5 lL _ ._J f 1 I[esson Pian

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.%,,,mm f i M388MN2

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bimulation I tcility Ghtt1Gdh Mario No.: 2 Op lest No.: 1 Esaminer6: Operators: SRO to E02 4 To evaluate the applicants' ability to initiate a normal plant power increase; to implement the ALMS. Ols, AOPs, Objectis es: as appropriate, for a reedwster Regulating Valve erratic operation, failure of a second Power Range Safety channel, failure of the second stage seal on a RrP; and to execute the EOPs for r.n Excess Steam Demand event outside containment complicated by a SGTR o the same Steam Generator. Initial Conditions: The plant is at 13 % Pow er,110C (IC.19) Pow er Range Safety Ch?nnel 11 Talled and Ilypassed, i Turnover: Present plant conditions: Unit I is at 13% power 110C. All applicable control systems are in automatic. Power history: Startup after short maintenance outage following 15 days of operation. Equipment out of service: Power Range Safety Channel 11 is 00S and bypassed until the next Cold Shutdown. Abnormal Conditions: None Suncillances due: None instructions for shift: 1he GS NPO has given permission to continue to increase power to 100% at 10% per i our per OP 2 and OP 3. a j

        = _ =

qU f C

__. __-~ _ . _ __ _ _ _ _ _ _ _ _ .- __ - - - _ _ _ _ _ _ _ _ _ __. Esent Mall. Event , Lvent No. No. Typeo Description as Preload None . . N/A R RO Continue raising plant pow er to 10096. Initiate Main l eed after transfer to Hi N IlOP Pw r Mode. 2 173,0, $ 1 DOP Approximately 2 minutes after commencing power increase (and after $*6 power (1 fw007,_01) increase) feed Regulating Valve LIC llii begms cperating erratically. The candidate is expected to recognize that a control problem exists with the feed regulating valve controller output and therefore direct that the valve be pinned. S/G level control will be on the bypass valve. 3 v19 0 i RO Approximately I minute after the f eed Regulating Valve LIC lli t is pMned (ini0lo,f) and S'O level control established on the bypass valve, Power Range Safety Channel A fails high. Upon receipt of the subchannel deviation alarms the candidate is expected to diagnose the cause of the problem and take appropriate response as dictated by the Tech Specs. The candidate is expected to recognize that this is the second failure of a Power Range Safety Chsnnel therefore requiring one channel to be placed in trip. 4 044,4,75?e C RQ Approximately 5 minutes after lech Spec requirements are implemented for (vrcs012_02) Power Range Safety Channel A,110 RCP second stage seal fails. The candidate is expected to recognize that a seal problem exots. The severity for the malfunction will be such that the candidate should increase monitoring of the RCP and may discuss removing the RCP from service for repairs. The candidate ! is expected to determine which seal has failed.

       $           102.0                        C    llOP     Approumately l$ mmutes f ollowing the RCP teal failure, the MSIV on 11                        ,

(Ims00R_01) Steam Generator begins to slow close. The candidate is expected to recognize ' dualindications, increasing steam pressure and lowcring steam flow. Crew should realire that ASGT trip will occur and should manually trip the reactor. 6 113,20 M ALL i ollowing closure of MSIV for the 11 Steam Generator, Safety Valve I.RV. (s ms017_06) 3997, on 11 S'G, fails open. The candidate is expected to recognize that there is an uncontrolled steam leak in progress. The candidate is expected to trip the Reactorrfurbine, isolate the steam header and then determine the location of the leak. An audible sound effect simulating a steam release will be heard in the Control Room. The catdidate is expected to implement EOP-4. 7 092,0,1 M ALL 2 minutes af ter implementmg S'O isolangn guidance contained m LOP-4, a (s ms002_01) Steam Generator Tube Rupture occurs on 11 Steam Generator, The candidate is expected to diagnose that a tube rupture has occurred and to transition to EOP 8 (Safety function Status RLEC.2 a. NOT satisfied). Scenario should end at first pass through APPENDIX l',) RADI ATION LEVELS EXTERNAL 10 CONTAINMENT. RLEC 1 CONTAINMENT ISOL ATED with deterraination that safety fur.ction CANNOT be satisfied without closure of S'O Safety Relief. NOTE AS the RO will be working Plc.3 and the BOP wil be working IIR 3, validation should detennine end point if time to get to RLEC 2 is excessive for scenario. 0(N)ormal, (R)eactivity (1)nstrument, (C)omponent, (M)ajor Transient

SCENARIO 1 1 OVERVIEM. I' rom 13t6 powcr, a normal power increase at 10*6hr should be establish:d in accordance with OP 2, step M. and Op 3. Power will be raised to at least 1519% and the feed system aligned to illGil POWER Mode. During the power increase,l'ced Regulating Valve LIC Ill t begins operating erratically. The candidate is expected to recognlie that a control problem exists with the feed regulating valve controller output and therefore I direct that the valve be pinned. S'O level control will be on the bypass vahe. After the I ced Regulating Valve LIC Ill t is pinned and S'O level control re established, Power RanSe Safety Channel A fails high. Upon receipt of the subchannel deviation alarms the candidate is expected to aingnose the cause of the problem and take appropriate response as dictated by the Tech Specs. The candidate is expected to l recognlie that this is the second failure of a Power Range Safety Channel therefore requiring one channel to be placed in trip, as addressed in Technical Specification 3.3.1.1. l After Tech Spec requirements are implemented for Power Range Safety Channel A, ll!! RCP second stage seal fails. The candidate is expected to recognize that a seas problem exists. The severity for the malfunction will be such that the candidate should increase monitoring of the RCP and may discuss removing the RCP from service for repairs. The candidate is expected to detennine which seat has failed based on indicatioris. Approximately 15 minutes following the RCP Seal failure, the MSIV on 11 Steam Generator begins to slow close. The candidate is expected w recognise dual indications, increasing steam pressure and lowering steam flow. Crew should realire that ASGT trip will occur and should manually trip the reactor and implement EOP-0. Following closure of MSIV for the 11 Steam Generator, Safety Valve 1 RV 3997, on 11 S'G, fails open. The candidate Is l expected to recogniie that there is an uncontrolled steam leak in progress. The candidate is expected to trip the Reactorri'urbine, and attempt to determine the location of the leak. An audible sound effect simulating a steam relcase will be heard in the Control Room. The candidate is expected to implement EOP 4 and initiate isolation of the 11 S'G. Afler implementing S'O isolation guidance contained in EOP 4, a Steam Generator Tube Rupture occt.rs on 11 Steam Generator. The candidate is expected to diagnose that a tubc rupture has occurred and to transition to EOP 8. It will be determined that the Safety I' unction Status "RLEC 2 a." is NOT satisfied and actions will be taken in accordance with APPENDIX (6) RADIATION LEVELS EUERNAL TO CONTAINMENT. RLEC-2: CONTAINMENT IfiOLAT ED. The scenario should end at first pass through RLLC 2 with determination that safety function CANNOT be satisfied without closure of S't Safety Relief and actions to address the problem.

l Scenario No: 11 laent No. I Page lfL of .20 ant Description- Normal Power increase to full power. lime Position Apphcant's Actions or behavior j CRLW Review Prerequisites and Precautions associated v sth OP.2 and OP.2 NORMAL POWLR OPERAllON SRO Direct load increase per OP.3 Section 6.l:

ONE to I OUR hours prior to changing pow er 5% or greater, notify Chemistry to drew RCS boron sample (NOTE: If contacted, Chemistry will report having drawn sample earlier.)
Reviews guidelines for LRNis followed e RPS Delta.T pow er is primary power indication e Comparisons should be made periodically between the FOUR RPS channels and plant computer for secondary calorimetric l
NI power should be used for trending purposes only until pow er is stabilized and a Ni Calibration has been performed e Deterrnine maximum power increase rate for normal cps per APPENDIX A e NO, YES, YES (or NO,NO) -e Limit power increase to < 30%hr
Direct Loading Rate of 10%hr RO Ensure Pressuriier spray flow:

e Energite PZR backup heater banks e Adjust P7R Pressure Controller setpoint to maintain 2250 psia HOP increase load e (in LOAD LlhtlT) Raise the load by inetcasing the load limit setpoint in small increments AND maintain LOAD SET no higher than 200MWe above actual load OR e (In LOAD SET) Raise load by momentarily depressing the LOAD SELECTOR INCREASE button AND maintain LOAD LIMIT no higher than 100MWe above actual load RO Perform RCS dilution OR withdraw CEAs as necessaiy to maintain Tc within 2'F of proFram _ _ . _ - ~ _ __ ___ - ... _ .__ . . - . -

Scenario No: 11 Lvent No. I Pige.bL of .20 Lvent

Description:

Normal Power increase to full pow cr. lime Position Apphcant's Actions or lichavior CREW Ensure requirements of APPENDIX C are met ' e if Tc deviates > 2*F from program Tc, notify CRS AND initiate corrective actions to restore e Reset VOPT setting every 2% to 4% power increase ! d

Raise MSR 2 stage pressure in no more than $0 psig increments per Figure 2 (local) e Notify Chemistry to sample RCS if pow er is changed by > 15% in ONE hour ;

e Do NOT exceed turbine limits e l$0'F/hr rate of change of 1" stage shell inner metal temperature (Point 6 on TR 4404)

7$'F I" stage shell metal temperature differential (Diff between Points 6 & 7 on TR 4404) e LP turbine inlet temperatures stay within $0'F of each other (Diff between Points ll&l6,12&l$,

and 13414 on TR 4404)' e Rate of change of temperature at 1.P Turbines does NOT exceed 12$'T per hour

Periodically compare all indications of power e

if unexplained difference exist between NI, Delta T. or calorimetric power, stop increasing reactor power until discrepancy is resolved e Periodically ZERO the Voltage Regulator Transfer meter

Periodically verify PZR Program level is within acceptable PZR level band per Figure (3) e Periodically monitor ASI to ensure oscillations will NOT reach the ASI pre trip value SRO' Prior to exceedmg 20% power, ensure CEAs are NOT inserted beyond Long Term Steady State Insertion RO Limit ilOP At approximately 130 MWe (15% power) ,

e . Verify ll and 12 MSR Drain Vahes auto shut

I RDV 3703 CV e I RDV 3710-CV e I RDV 3701 CV e 1 RDV 3708 CV d

e Open MSR 2 stage stm source valves e t MS-402$.MOV e 1 MS-4026 MOV

Scenario No: 11 la ent No. I Page El_ of lQ LSent

Description:

Normal Power increne to full pow cr. J ame Position Apphcant's Actions or 13chavior liOP (Cont.) e d (cont.) Open 2 stage scavenging steam to 16A & 1611 FWils 1401

I.RDV.172
I.RDV.173 e Slowly open LOW Load Valves 1.MS-4021.CV & l.MS-4024-CV.
Maintain maximum 2" stage pressure per Figure (2)
LP Turbine inlet temp rate of change should NOT exceed 125'F/hr e Differential temperature between LP Turbine h4lets should NOT exceed 50'F e Shut Jrsin valves on IC02
1 115 3700 MSR DRN e

1 115 4651/4652/2314/2315 12/14/13/11 STM LEAD DRN

1 115 1431 EXTR LINE DRN ORIFICE !)Yp VLYS e 111S 6600 MS LINE DRN d

e Verify 11 & 12 MSR 2 stg drain valves auto shut

I.RDV.3705 CV e I.RDV.3712 CV e

Check Feed system transfers to the 111G11 l'OWEtt Mode between 17% and 19% power

Scenario No: 11 Lvent No. 3 Page id of .20 laent

Description:

I cedwater Regulating Vah e LIC.IIll begms to oscillate close and open around current position.1his , causes fluctuation in feed to 11 S0. lime Position Apphcant's Actions or llehavior CUL: Annunciator alarm ICO3 C.38 IISO l-W CONTR Cil LVL ICO3 C-67 II/12 SG FW CONTR XFER TO MANUAL llOP Identify / report I cedwater Regulating Valve (i RV) controller LIC.l l l l erratic response. SRO identify / acknowledge erratic response of I RV. ISOP lake manual control of LIC.Ii11 and adjust feedwater flow to maintain constant SO level. SRO Stop power increase Direct actions of AOP 3G Section Vil Step D llOP Perform actions as directed: e Place handswitch 1.IIS-4516C in the MAIN Fall position

Adjust PDI CONTR I.PDI-4516 to maintain SG level of approx. ZERO inches CREW e

if operation of FRV llYP in ilYP OVERRIDE desired AND SG level setpoint is available from the FRV CONTR.

Verify FRV CONTR and FhV !!YP CONTR are in MANUAL NOTE: Actions of 3.b and 3.c should be performed concurrently (next 2 paragraphs)

At Plasma Display Units on Microprocessor (IC35) Depress !)YP FW VLV OVERRIDE on touch screen at MAIN microprocessor

Depress CONFIRM OVERRIDE ENABLE w/i 10 sec
Depress IlYP FW VLV OVERRIDE on touch screen at II/U microprocessor
Depress CONFIRM OVERRIDE ENABLE w/i 10 sec
Adjust affected FRV ElYP valve AND FRV to obtain-
FRV IlYP CONTR output or= 50'4
SG level = ZERO inches a _= _

l 1 Scenario No: 11 Lycnt No. 2 Page 4 5 of .2D l Lvent

Description:

Feedwater Regul:tmg Valve LIC Illi begins to oscillite close and open around current position.1his

causes fluctuation in feed to 11 SG.

( , hme Position Applicant's Actions or !!chavior CREW (!!YP OVERRIDL cont.) (cont.)

When either condition exist, place associated FRV ilYP CONTR in AUTO e AU'IO operation of FRV ilYP CONTR desired
FRV !!YP CONTR output is = $0% AND SG level is = ZERO inches e

Adjust affected FRV CONTR setpoint to obtain FRV 11YP CONTR level setpoint of = ZERO inches l l llOP e Control RCS 1 cold-

Adjusting TilVs e Adjusting ADVs e Adjusting feedrate To maintain within ?'F of program Tcold SRO Notify GS NPO or Supt Nuclear Ops of need to pin i RV T

(NOTEt Directions are to maintain current power. pin affected FRV and repair) llOP Pmmg of I RV e Adjust SGFP speed as required to maintain affected SG level e Dispatch operator to take local control of FRV and to pin FRV e ifin llYPASS OVCRRIDE hase operator locally adjust FRV to obtain a FRV DYP CONTR output of = 50'h while maintaining SG level = ZERO inches SRO Direct OMC/l&C to investigate problem with FRV/FRV controller.

Scenario No: 11 Event No. 3 Page b_ of .20 Lsent

Description:

Power Range Safety Channel A fails 111011 due failure in summer amphfier circuit. This the second PR safety channel to be inoperab?c. lime Position Applicant's Actions or 13chavior CUL: Annunciator alarna IC05 D-08 HI POWER 1 RIP RESL1 DLMAND IC05 D.12 POWER LVL 111 Cil PRE TRIP IC05 D-05 PROTECTION CllANNEL TRIP IC05 D-43 NUCLEAR DELTA T POWER Cil DEVIATION Power levelintlication on IC05 & IC15 indicates high on PPS channel A RO ldentify and report failure of Power Range Safety Charmel A e Determines CEAs NOT misaligned

Metroscope position SRO identify / acknowledge failure of Power Range Safety Channel A SRO Recognize applicabihty oflechnical Specification 3.3.1.1 ACTION 2 for TWO channels inoperable. Notes that Specification 3.0.4 is NOT applicable Direct Trip of following bistables within ONE hour : (OR trips other channel (13) and places this channel (A) in bypass)
1 e 2 e 7
8 e 10 RO e Verities or trips atTected bistables SRO Contact OMCel&C to investigate failure of Power Range Safety Channel A.

Scenario No: 11 Event No. 4 Page 2., of .29 l Inent

Description:

1111 RCP Reactor Coolant Pump has a failure of the second stage seal. lime Position Apphcant's Actions or Behavior CUL: Upper seal SIGMA alarm at IC06 pancl; Alarm Window s E.55 and E.53 RCP middle seal pressure decrease RCP upper seal pressure increase RCP lower seal temperature increase RO identify and report RCP problem associated with reals (temperature and'or pressure) Diagnow middle seal failure for IIB RCP. SRO identify / acknowledge 1115 RCP seal problem Diagnose / confirm middle seal failure for 11B RCP. SRO Direct actions for f ailed scal (per IC06 ALM window E 55 and'or IC07A&B ALM window X.20118 RCP) may also reference OI I A:

Closely monitor and trend remaining seals for increased rate of degradation e Contact System Engineer immediately t

e if RCP controlled bleed-off temperature exceeds 200'F [NOT EXPECTED]

Trip the reactor e implement EOP 0
Secure llB RCP Contact Plant Management to inform of seal failure NOTEt Splem Engineer should report that continued monitoring of remaining seals would sumet for immediate response. He will take responsibility for mobilizing OMC in response to seal failure.

l

Scenario No; l1 Event No. 5 Page.8 10 .of.29 Lvent

Description:

MSIV on iISO begins to slow close. lime Position Applicant's Actions or 11ehavior CUL Annunciator Alann ICO3 C 41 ll htSIV llYD SYS 1C03 C 42 11 htSIV TEST VLV CLOSED MSIV CLOSE light lit (dual indications) 10% closed light will be lit ilOP Identify / report slow closure of 11 MSIV SRO identify / acknowledge slow closure of IIMSIV CREW Diagnosis failure of MSIV will result in ASGT trip of reactor SRO Direct action of ICO3 ALM,if time allows:

Dispatch operator to panel IC161 to determine cause for C-41 alarm.

Direct manual trip of reactor prior to automatic actuation. I RO I rips reactor by depressing manual reactor trip pushbuttons. SRO Direct the implementation of LOP-0 POS1 TRIP IMMEDIATE ACTIONS RO 'iIerform Post lrip immediate Actions:

Depress ONE set of Manual RX TRIP buttons e Checks reactor tripped;
Prompt drop in Ni power e Negative SUR e Check ALL CEAs fully inserted e Verify demin water makeup to RCS is secured e 11 & 12 KCMU pumps secured VCT MU valve I CVC 512 CV is shut e

if RCS MU is in D: RECT LINEUP, RWT CilG PP SUCT vahe I CVC 504 MOV is shut

Scenario No: 11 Esent No. 5 Page_s.10 of,20 Event

Description:

MSIV on 1150 begins to slow cic:; hme Position Applicant's Actions or Behavior 1)OP e Check reactor has tripped

Ensure turbine has tripped.
Depress U.I MAIN TURil Trip button
Check Turbine Stop valves shut
Check turbine speed drops l
Verify turbine generator output breakers open:

e ll GEN BUS IIKR,0-CS 552 22 e 11 GEN TIE IIKR,0 CS 552 23 e Verify 11 GEN FIELD HKR, l.CS-41 is open.

Verify 11 GEN EXCITER FIELD BKR 1.CS 41 is open.

DOP e Check II OR 14 4KV Vital Dus energized e Check ALL 125V DC BUS VOLTS greater than 106 volts e Check at least ONE set of 120V AC Vital Buses is energized e Check at least ONE 208/120V INSTR AC BUS is energized e IF ANY RCPs are operating TilEN verify component cooling flow to the RCPs.

Dispatch an operator to verify Switchgear Room Vent, operating RO identify and repon RCS pressure decrease e

Ensure PZR pressure stabilites between 1850 psia and 2300 psia AND is trending to 2250 psia NOTE: Pressure should be high due to MStV closure until S/G safety valve fails open then: 4 Determine PZR pressure is continuing to drop Verifies or manually operates heaters and sprays to attempt to restore pressure

Scenario No: 'l . l Lvent No. $ Page B ILof 2 Event

Description:

MSIV on iISO begins to slow close. hme Position Applicant's Actions or llehavior e When PZR pressure falls to 1725 psia, verify SIAS actuates (May manually actuate SI AS if directed) I;O (EOP 0 cont.) (cont.) e Perform RCP Trip Strategy. e if pressure drops to 1725 pin, trips either e ll A AND 1211 RCPs or e 1111 and 12A RCPs (NOTE: Crew may consider tripping at least the Illi RCP due to presiously noted seal problem) e if CIS actuates, trips ALL RCPs e if RCS temperature and pressure are less than the minimum pump opere:ing limits PER Attachment (1), RCS PRLSSURE TEMPERATURE LIMITS, TilEN trip ALL RCPs. Ensure P2R les el stabilites between 80 and 180 inches and is trending to 160 inches e if NOT operate charging and letdown to restore

Ensure RCS si'. cooling GREATER TilAN 30'F NOlEt Actions of EOP 0 continuein Esent 6

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

Scenarso No: 11 Lvent No. 6 Page ..ll l$ . of .2.0 ' Lvent

Description:

Safety Valve on 1150 opens (below setpoint) due to pressure spike and fails to rescat. lime Position Applicant's Actions or Hehavior CUL: Annunc'ator Alarm ICO3 C 57 11 b~lM LINL RUPIURE I Indicated steam flow for 11 SG Lowering pressure for 11 SG

!                                 RCS temperature and pressure lower than expected Audible sound of steam release

) CRLW e Verify turbine bypass valves or ADVs operating to maintain-

SG pressures between 850 and 920 psia identify report preuure falling in ll 50/ Safety valve open l

e if SG pressure falls to 800 psia, shut DOTil MSIVs

When SG pressure drops to 685 psia, verify SGIS actuated

] e When pressure dilferential between SG drops to 115 psid or greater, verify AFAS Block is actuated for 11 SG e Tcold betw een $25' and $35'F HOP e Check at least one SO available for controlled heat removal e SG lesel between .170 and 4130 inches e Main or Aus Feedw ater operating to maintain level e Check at least one RCp operating in loop with available SG f . If any RCp operating, check Thot minus Tcold LESS TilAN 10*F in loop with available SG CREW e Check Containment pressure leu than 0.7 psig e Check Containment temperature less than 120*F e Check containment radiation monitor alarms CLEAR with NO unexplained trends-e Check RMS alarms CLEAR with NO unexplained trends-e I RIC 5415 U l wide range noble gas

                                     =     l kl.1752 Condenser Offgas e     I RI 4014 Unit i SG Blowdown e     I RI 5415 Unit i Mairi Vent Gascous i

l Scenario No: 11 Lvent No. 6 Page Il 15 of 2D Esent

Description:

Safety Valse on 1150 opens (below setpoint) due to pressure spike c.nd falls to rescat. lime Position Applicant's Actions or llehavior t SHO e Determine Recovery Procedure per Diagnostic Howchart.

NO for RCS preWinv safety function e YES for either 50 pressure (800 psia e NO for RCS subcooling < 30*r e

Consider EOP 4 (ESDE) e (if)NO for Corc/RCS Ileat Removal safety function e YES One SG with flow e 7 RCP trip strategy (bus should have at least one RCP running) e NO SO D'D or Offgas Rhts alarm o NO for RCS subcooling < 30'F e Consider EOP 4 (ESDE)

Singf.e Event Diagnosis SRO 1ransition to LOP 4 LSDE e Direct actions per EOP 4 CRLW e Commence 5Al LiY l'UNCllON S1 ATUS CllECKS -

e Determine ESDE diagnosis correct

Determines appropriate ERPIP response.

CREW e if PZR pressure LLSS TilAN OR LQUAL 101725 psia OR CN1h1T pressure GREATER TilAN 2.8 psig. e Verify SlAS actuation

Determine maximus. safety injection Oow exists-e ll and 13 IIPSI pumps running e

llPSI now per A1TACithtENT (10) when pressure below 1270 psia e 11 and 12 LPSI pumps running e LPSI now per ATTACilhtENT(II) when pressure below 185 psia e All charging pumps running

Verify DOTil htSIVs are shut

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

Scenario No: 11 L5ent No. 6 Page .11 15 . of .20 L5cnt

Description:

                     * .ety Yahe on 11 SG openo(below setpoint)due to pressure spike and fails to rescat.

June Poution Applicant's Actions or lichavior A 1 l RO e Perform HCP 1rsp Strategy. e When pressure drops to 1725 psia, trip either e ll A AND 1211 RCPs or e Ilil and 124 RCPs e if CIS actuates or Component Cooling f'ow to RCPs CANNOT be verified , trip ALL RCPs

If RCS temperature and pressure are less than the minimum pump operating limits PER Attachment (1),

RCS PRESSURE TEMPERATURE LIMITS, TilEN trip ALL RCPs. 4 4 IlOP e Detennine if steam leak isolated e SG pressure stabilized 4

Uncontrolled RCS cooldown secured e SG levels constant or rising e ()ctermines leak is NOT isolated llOP e identify SG e SG with lowest pressure e RCS loop with lowest Tcold e SG with most rapid downward level trend identifies 11 SG as affected e Isolate affected SG e Direct local operator to shut 11 ADV using the lland Transfer vahes e Verify I.FW 4516 MOV 11 SG FW ISOL shut e Verify I MS 4045 MOV 11 MSIV IlYP shut e Shut 11 SG lilowdown valves e 1.D D-4010-CV e 1 ilD-40ll CV e Shut 11 SG AFW MAIN STM SUPP & !!YP e I MS-4070-CV e I MS-4070A-CV

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

Scenano No: 11 Event No. 6 Page 11 15 of .20 Lsent

Description:

Safety Valve on ll SO opens (below setpoint) due to pressure spike and fails to rescat.

lime Position Apphcant's Actions or Behavior e Shut il SO AFW HLOCK valves

I. ATW.4520-CV e I.AFW 4521.CV e I.AFW 4522.CV e I.AT W 4523.CV i

j i i HOP (LOP 4 cont.) (cont.) e Place 1 1156622 to CLOSE to shut MAIN STM UPSTREAM DRN ISOL l 1 1 e Direct operator to Aux. Bldg roof to check SG safeties shut (NOTEt Operator later reports steam from the 11 SG safety area)

'~~

CRtiW identifies steam leak as NOT being in CNIMT J

l . s i f 4 i k I.

Scennio No. 11 Event No. 6 Page Il 15 of.29 Lvent

Description:

Safety Valve on ll SG opens (below setpoint) due to pressure spike and fails to rescat. lime Position Applicant's Actions or flehavior RO e With SlAS actuated, verify boration in progress-e I CVC 512-CV VCT M/U valve shut e 1 CVC 514 MOV !!A DIRECT MU salve open

IIAST GRAVITY FD valves open-
1 CVC $08.MOV e 1 CVC $09.MOV e ALL available 13A pumps running

e I CVC $01 MOV VCT OUT valve shut e ALL available charging pumps running e Record time boration started e Record 11 AST levels-e 11 IIAST e 12 IIAST

Continue boration until ONE condition met.
Shutdown Margin requirements met per NEOps e ilAST levellowered a total of 71 inches e 15 oration has been in progress for-
35 minutes with TilREE charging pumps running

                               *     $3 minutes with TWO charging pumps running e      105 minutes with ONE charging pump running CRLW        e   Maintain RCS temperatures e    if difTerence between unaffected SG temperature and CET exceeds 25'F during the blowdown, then cool unaffected SG to within 25'F using ADV e    When blowdown has stopped, use unaffected SG ADV to stabilize RCS temperature wn--            y    e 4 --: - r       -              -              .- - - ev   v

Scenario No: 11 Event No. 6 Page 11 15 of 20 LSent

Description:

Safety Valve on ll S0 opens (below setpoint) due to prGssure spike and fails to rescat. lime Posi: son Applicant's Actions or lichavior I IlOP e Lstablish Al W flow to unaffected SG. e if 13 AFW pump available e Open 12 50 motor driven train AFW valves

l.AFW 4532 CV e 1.AFW-4$33 CV l
Start 13 AFW Pump e Shut 12 SU steam driven train AFW valves
I AFW 4530-CV e I.AFW 453'6 -CV e Shut 12 50 AFW MAIN STM SUPP & flYP e I MS-4071 CV e I.MS 4071 A CV e

Restore and maintain 50 level between 170 and +30 inches while NOT ex;eeding cooldown rate of 100'F in any one hour using 1.AFW 4535 CV e Secure Main Feed e Trip SOFPs e Place Ci1Ps in PULL 10 LOCK e Place ONE COND pump in PULL TO LOCK e Place llDT Pumps in PULL TO LOC.

Shut SO FW ISOL e 1.FW 4516 MOV e 1.FW 4517 MOV e Shut hotwcil to CST dump CV by placing controller 1 LIC 4405 in MANUAL with 50% output NOT Et Espected that Event 7 would occur

Scenerlo No: 11 Lvent No. 7 Page .16 20. of .10 Lsent

Description:

A Steam Generator lube Rupture (SG1R) occurs on the 1I SG. This results in an unmonitor.d radioactive release to atmosphere from the 11 SO due to the open safety 5 alve from Event 6. Ime Position Applicant's Actions or behavior CUL Decrease in rate of level drop for Ii 50! rise in SO level increase in rate of RCS depressurization and loss of les el CRLW identify and report e dropping RCS pressure e steaming resuming from ll 50 Diagnose rupture in ll 50 l i SRO Ident' y/acknoAledge RCS and 50 conditions l Concur with SOTR diagnosis for 1150 SRO Implement LOP 8 l'UNCllONAL RECOVLRY PROCLDURE CRLW e Perform RCP 1 rip Strategy e Direct Chemistry to sample ilOTil SGs for activity

Direct Chemistry to place flydrogen Monitors in service CRLW e Identify Success Path for all unsatisfied safety functions (RLSOURCE ASSES $MLN11 AllLE)-
RCS PRESSURE & INVENTORY P:C 3 SIS e S'O IIEAT SINK WITil SIS -IIR 3 e

RADIATION LEVEL S EXTERNAL. TO CNTMT RLEC 2 CNTMT ISOL e Commence Recovery Actions for identified Success Paths SRO e Direct performance of Status of safety functions CREW e if PZR pressure LESS 'lil AN OR EQUAL 1O 1725 psia OR CNTM1 pressure GREATER TilAN 2.8 psig-e Verify SI AS actuation

Scenano No: 11 Esent No. 7 Page __16 20. of .20 l Lvent Descriptmn: A Steam Generator lube Rupture (SGIR) occurs on the il 50. This results in an unmonitored radioactive release to atmosphere from the 11 SG due to the open safety valve from Event 6. lime Position Apphcant's Actions or llehavior CRiiW (LOP 8 Plc.) cont.) (cont.) e Determine maximum safety injection now exists. e ll and 13 IIPSI pumps running e llPSI now per ATTACllMENT (10) when pressure below 1270 psia t e 11 and 12 LPSI pumps running ' e LPSI now per ATTACllMENT(11)when pressure below 185 psia e All charging pumps running e if CIS actuates or Component Cooling now to RCPs CANNOT be veri 0ed , trip ALL RCPs e if RCS temperature and pressure < minimum pump operating limits per A1TACllMENT(1), trip ALL RCPs e When following conditions can be maintained.

At least 25'F subcooling (CETs) e PZR level > 101 inches l141 inches if CNTMT pressure > 4.25 psig)
At least ONE SG available for heat removal e RVLMS indicates level > top of hot leg e llPSI How is NOT being used for reactivity control e

llPSI now can be reduced by throttling IIPSI IIDR valves OR stopping ONE HPSI pump at a time-

Maintain RCS subcooling between 25'F and 140'F (CETs)

Maintain PZR lesel between 101 inches and 180 inches [ 141 and 100 inches] if PZR pressure > 200 psia AND either constant or rising, stop operating LPSI pumps e if criteria CANNOT be maintained after pumps are throttled or secured, restart appropriate pumps and restore full now

u

     $cenario No: 11                                             Lvent No. 7                                            Pcge 16 20 of .20 laent

Description:

A Steam Generator lube Rupture (SGIR) occurs on the ll 50. This results in an unmonitored radioacth e release to atmosphere from the 1150 due to the open safety valve from Event 6. lime Position Applicant's Actions or Behavior CRLW 'Wal' 8 PIC 3 cont.) (cont.) e if bubble exists in PZR OR reactor vessel head, restore and maintain subcooling betw een 30'F and 140'r (CETs)- e Raise subcooling by ANY of following-e Operate PZR heaters e Raise RCS cooldown rate NOT to exceed 100'F in any ONE hour e If IIPSI now has been reduced, raise llPSI now e Lower subcooling by ANY of following-

Decnerglic PZR heaters e Lower RCS cooldown rate e Throttle or secure llPSl! Charging now e initiate Aux Spray e if bubble exist in P7.R AND llPSI now secured, restore and maintain PZR level between 101 and 180 inches [l 41 and 190 inches] by operating charging and letdow n CRLW e Attempt leak isolation.
Verify shut L/D CNTMT 1501 e I.CYC 515 CV e 1 CVC 516-CV e Check PORY leakage o Quench Tank parameters
PORY disch temp, computer points.
T107 e T108 e acoustical Monitor indication l

l 1

Scen:rio No: 11 Event No. 7 Page 16 20 of .20 Lvent

Description:

A Ste:m Generator Tube Rupture (SOIR) occurs on the 11 SG. This results in an unmonitored radioactive release to atmosphere from the 11 SO due to the open safety valve from Event 6. Iirne Position Applicant's Actions or Dehasior CRLW (LOP 8 PIC 3 cont.) (cont.)

Shut 1 PS 5464 CV RCS SAMPLE ISOL e Shut RXV Vent valves.

e I RC 103 SV e I.RC 104 SV e Shut PZR VENT valves. e 1 RC 105 SV e 1 RC 106 SV e Determine leak is NOT inside CNTMT-e CNTMT parameters normal e U l WR Noble Gas Monitor and U l Main Vent Gaseous Monitor NOT in alarm 1 e Place DOTil PENET RM EXil FANS in service e Determine NO leakage into CC System by-

Clear alarm on rad monitor 1 RI 3819 with NO rising trend e

CCW llEAD TK l.VL alarm (ICl3 K 17) clear e Maintain RWI level > 2 feet by replenishment

Prepare for RAS actuation CRLW (llR 3)

It is anticipated that ilR 3 will not be used based on entry is from RLEC 2 or EOP-4 Status Checks (should be satisfied for RCS IIR) and RLEC 2 should terminate the scenario prior to llR 3 entry point. CREW (RLLC 2)

Check radiation levels external to CNTMT Normal e

I RIC 5415 alarm clear (U l WIDE RANGE NOBLE GAS) I RI l?$2 alarm clear (CNDSR OFF GAS) e I RI-4014 alarm clear (UNIT 150 B'D) I RI 5415 (UNIT l MAIN VENT GASEOUS) Determine NONE in alann l

Scenario No: 11 Event No. 7 Page 16-20 of .2.0 Lvent

Description:

A Steun Generator Tube Rupture (SGTR) occurs on the il SG. This results in tn unmonitored radioactive release to atmosphere from the 11 SG due to the open safety valve from Event 6. lime Position Applicant's Actioru Or Behavior e Verify SRW Pump Room ventilation is in service per 01 15 i ( I CREW (EOP 8 RLiiC 2 cont.) ! (cont.) e Perform checklists as appropriate ! ATTACllMENT(2) SIAS e i ATTACllMENT(4)CIS e if any automatic CNTMT ISOL valve or manual valve open, shut the valve or the next valve out from the affected penetration e if activity detected in secondary, identify the most affected SG e Mismatch in feed flow prior to trip e Unexplained rise in level prior to trip e Main Steam line RMS e Post 1 rip SG level changes a SG samples NOTE: Chemistry will report /have reported sample results by this point identify 11 SG as affected SG e SG samples e Steam'ing after blowdown If tube ruptere identified in SG, then attempt to isolate per Heat Removal success path Determiae isolation attempted NOT effective with Safety Valve stuck open. I w

htmulation I acility Calvert Chffs Scenario No.: 2 Op lest No.: 1 Examiners: Operators; SRQ RO I102 To evaluate the applicants' ability to initiate a normal plant power increase; to implement the ALMS, Ols, AOPs, Objectives: ) as appropriate, for a failure cf a Steam Generator pressure channel, a loss of CVCS letdown, a loss of position indication for one CEA, and a loss of turbine generator load due to partial closure on a Control Valve; and to execute the EOp3 for a large Steam Generator tube leak which degrades to a multiple tube SGTR and the failure of a liFSI pump to start. Initial Conditions: The plant is at 5046 Power; MOC(IC ll) Power Range Safety Channel Il failed and Bypassed. Turnover: Present plant conditions: Unit 15046 power MOC. All applicable control systems are in automatic. Power history: Return to nower following short downpower from 75?6 due to oil leak on 12 SGFP.12 SGFP is now in standby per OI ila. Equipment out of service: Power Range Safety Channel B is OOS and bypassed. Abnormal conditions: CEAs are NOT ARO due to power reduction 2 hours ago. Survullances due: STP-097Il412 CONTROL ROOM IIVAC BIMONTill Y TEST schedaled to be performed within next I hours. instructions for shift: Continue plant startup at 12th per hour IAW OP 3, step E and place 12 SGFP in parallel operation with 11 SGFP per OI 12A. NOTE: 11 & 12 FW lleaters are in service. Continue raising plant power to 100% $lf SCEN AR-1.RTF i 10!!4/97 3:11 PM

1,ver., Malf. E vent Event No No- Type

Description Preload N'A R RO Contmue raismg plant power to 1009s and place 12 SGFP in parallel operation.

N llOP 2 252,2,I I ilOP Approximately 2 minutes after commencing power increase,12 S'O Pressure (Ims021_02) PT 1023fl faia low resulting in a i out of 4 RPS trip and an ESFAS ZE SGIS. The candidate is expected to recognize that a Steam Generator Pressure transmitter has failed and is expected to comply with all applicable Tech Specs. 3 073 C RO Approximately 2 minutes after the lech Spec requirements are implemented for (Icvcs006) the failed S'O Pressure transmitter, a loss of normal letdown occurs w hen vah e CVC 516 fails closed. The candidate is alerted to conditions by indications and alarms, and is expected to secure the charging system and initiate troubleshooting activities. 4 033, CEA 35 i RO Approximately 2 minutes after the chargmg system is secured and (Icedsol? 26) troubleshooting activities are initiated, CEA 35 reed switch position indication fails. The candidate is expected to recognize the loss of position indication and take the appropriate action as defined in the Tech Specs. 5 138,0,1096 C IlOP Approximately 5 minutes after the Tech Spec requirements are impkmented for (vtgo24_01) the failed CEA position indication, a load rejection occurs (10% closure of CV-1, no trip desired). The candidate is expected to recognize that turbine load has decreased and that a misnis.A exists between the turbine and reactor power levels. The candidate shousa attempt to reduce reactor nower to the correspondmg turbine powcr. 6 091,4,100 M ALL Approximately 2 minutes after attempts are made to reduce reactor power to (vms001_02) compensate for the load rejection, or after the reactor tr? if one should occur, a major tube leak occurs in 12 Steam Generator. The candidate is expected perform actions of AOP-2A ana EOP 0, to diagnose the event, and should implement EOP-6. 7 188, O C ALL The 1 I itPSI Pune ipsr w hen started (fails to start) on SI AS. The candidate is (IsiOO2_01) expected to recogO : that the selected ilPSI Pump has failed to start and should take action to insure that the backup nump is operating. 8 092,4,5 M ALL When the Post-T rip immediate Actio : are complete in EOP-0, the S!G tube leak (vms002_02) worsens to become a multiple tube n < ure. The operator actions for the SGTR are still addressed in EOP-6. Scenario should end following step J of EOP-6 with evaluation of the need for ilPSl/LPSI throttling' termination

 *(N)ormal,        (R)eactivity      (1)nstrument,        (C)omponent,         (M)ajor Transient SCEN AR-l.F,TF                                                 2                                              10/14/97 3:11 PM

E SCENARIO 1-2 OVERHEE From 50% power, a normal power increase at 12%'hr should be established. The 12 Steam Generator Feed Pump (SGFP) will be started and placed in parallel operation with running ii SGTP During the power increase, the 12 S'G Pressure PT 10238 fails low resulting in a i out of 4 RPS trip and an ESFAS ZE SGIS. The candidate is expected to recognize that a Steam Generator Pressure transmitter has failed by indications and alarms. The crew is expected to comply with actions directed by Technical Speci0 cations 3.3.1.1

 ]     (RPS), 3.3.2.1 (ESFAS), 3.3.3.5 (Remot: Shutdown), 3.3.3.6 (Post-Accident).

h Following determination of Technical Specification ACTION (s) conceming the failed S!G Pressure ' ,mitter, a loss of normal letdown occurs when valve CVC 516, Letdowr CNTMT isolation, fails closed. The candidate is alerted to conditions by indications and alarms, and is expected to secure the charging and letdown system and initiate troubleshooting activities. (See IC07. ALM window F 24). After the charging system is secured and troubleshooting activities are initiated, CEA 35 reed switch position E indication fails The candidate is expected to recognize the loss of position indication (Cashing) and alarm, and to i take the appropriate action as defined in the Technical Specification 3.1.3.3. After the Tech Spec requirements are implen ented for the failed CEA position indication, a load rejection occurs (10% closure of CV 1, no trip desired). The candidate is expected to secognize that turbine load has decreased and that a mismatch exis's between the turbine and reactor power levels. 'Ihe candidate should attempt to reduce reactor power to the corresponding turbine power. Actions are expected to be taken I AW AOP 7F LOSS OF LOAD and'or i g AOP 7E MAIN TURI 31NE MALTUNCTION Section Xill. Approximately two minutes after attempts are made to reduce reactor pow er to compensate for the load rejection, or aner the reactor trin if one should occur, a major tube leak occurs in 12 Steam Generator. The candidate is expected perform actions of AOP-2A and EOP-0, and to diagnose the event. During performance of the post trip actions, the candidate is expected to recognize that the 11 HPSI Pump has failed to start and should take action to insure that the backup pump is operating. When the Post-Trip immediate Actions are complete in EOP-0, the S/G tube leak worsens to become a multiple tube rupture. The operator actions for the SGTR are still addressed in EOP-6. SCEN AR-1.RTF 3 10'14/97 3:11 PM

l scenario No: 12 Esent No. I Page _LL of _12 vent

Description:

Normal Power increase to full power. lime Position Applicant's Actions or Behavior CREW Review Prerequisites and Precautions associated with OP 3 NORMAL POWER OPERATION t SRO Direct load increase per OP 3 Section 6.1.E: e ONE to FOUR hours prior to changing power 5's or greater, notify Chemistry to draw RCS boron sample (NOTE: If contacted, Chemistry will report having drawn sample earlier.) e Reviews guidelines for LRNls followed e RPS Delta T power is primary power indication e Comparisons should be made periodically between the FOUR RPS channels and plant computer for secondary calorimetric Ni pow er should be used for trending purposes only until pow er is stabilized and a NI Calibration has been perforn.ed e Determine maximum power increase rate for normal ops per APPENDIX A e NO, YES, YES (or NO,NO) -+ Limit power increase to < 30%hr l

Direct Loading Rate of 10%hr l

RO Ensure Pressur:zer spray Dow:

Energize PZR backup heater banks e

Adjust PZR Pressure Controller setpoint to maintain 2250 psia BOP increase load (in LOAD LIMIT) Raise the load by increasing the load limit setpoint in small increments AND maintain LOAD SET no higher than 200MWe above actual load OR e (In LOAD SET) Raise load by momentarily depressing the LOAD SELECTOR INCREASE button AND maintain LOAD LIMIT no higher than 100MWe above actual load RO Perform RCS dilution or withdraw CEAs as necessary to maintain Tc within 2*F of program 1

Scenario No: 1,2 Event No. I Page l-L of .12 Event

Description:

Normal Pow er increase to full powcr. Time Position Applicant's Actions or Behavior CREW Ensure requirements of APPENDIX C are met e if Tc deviates > 2'F from program Tc, notify CRS AND initiate corrective actions to restore e Reset VOPT setting every 2% to 4 .power increase e d Raise MSR 2 stage pressure in no more than 50 psig increments per Figure 2 (local) h

Notify Chemistry to sample RCS if power is changed by > 15% in ONE hour e Do NOT exceed turbine limits e

150'F/hr rate of change of I" stage shell inner metal temperature (Point 6 on TR-4404) 75'F 1" stage shell metal temperature differential (Diff between Points 6 & 7 on TR 4404) a LP turbine inlet te nperatures stay within 50'F of each other (Diff between Points ll&l6,12&l5, and 13& l4 on TR-4404) e Rate of change of temperature at LP Turbines does NOT exceed 125'F per hour Periodically compare all indications of power e if unexplained difference exist between NI, Delta T, or calorimetric powe , stop increcing reactor power until discrepancy is resobed e Periodically ZERO the Voltage Regulator Transfer meter Ptriodically verify PZR Program Level is within acceptable PZR level band per Figure (3) e Periodically monitor ASI to ensure oscillations will NOT teach the ASI pre-trip value DOP Start second SGFP, per Ol 12A Section 6.7 Place the 12 SGFP in IllC-e Ensure the 12 SGFP is in MANUAL e Adjust output of 12 SGFP to illuminate XFER PERM indicator on OCS When XFER PERM lit, depress HIC pushbutton Check DEMAND RPM display on OCS and output of 12 SGFP are within 50 rpm

                       . Verify bias setting is at 5.0 Place 1-FIC-448512 SGFP Miniflow Controller in MANUAL Ruise 12 SGFP speed to match AUTO signal with MANUAL signal e

Place 12 SGFP SPD Controlin AUTO l

Ycenario No: 12 livent No. 1 Page.1.:L of 12

f. vent

Description:

Normal Pow er increase to full powcr. Time Position Appiscant's Actions or Behavior ilOP (01 12A Section 6.7 cont.) (cent.)

Monitor SOFP for proper operation-
SGFP speed e SG levels e SGFP disch pressure e Steam flow

                              .             Feed flow I

e Slowly shut 1 FIC 448512 SOFP Minillow, while returning bias to 5.0 on 11 SGFP e Place 12 SGFP Miniilow Controller in AUTO t 4

Scenario No: 12 Lvent No. 2 Page _1of _12

 " vent

Description:

12 SG pressure transmitter L1 102315 f ails LOW resulting in I out of 4 channels RPS trip & LSFAS SGIS.

   ' lime   Position                                                  Applicant's Actions or llehavior CUL:        Annunciator alarm ICO3 AFW STATUS PANLL IC04 AFAS IllST TRIP IC05 PROT Cil TRIP

] Single pressure indicator reading low IlOP identity & report f ailure of 12 SG pressure channel LT-102311 SRO identify / acknowledge f ailure of 12 SG pressure channel L1 102311 SRO Recognize applicability of Technical Specification 3.3.1.1 ACTION Direct Ilypass (or trip) of following bistables within ONE hour; e SG Press - LOW Recognize applicability of Technical Specification 3.3.2.1 ACTION Direct flypass (or trip) of following histables within ONE hour; SG Press LOW Main Steam Line isolatica e RPS - TM'LP e AFAS - Pl2>Pil OR Pil>P12

                       . ESFAS - SGIS -Ilioci Should also reference TS 3.3.3.5 and TS 33.3.6 SRO         Contact OMC to investigate failure of SG pressure channel LT 1023fl.

[ Scenario No- 12 Event No. 3 Page 1.of J.2 ' " vent

Description:

A loss of normal CVCS letdown occurs due to failed closed containment isolation valve CVC 516. Isme Position Applicant's Actions or Behavior CUh; Annunciator alarm IC07 l>09 L/D PRESS IC07 F 17 HORON/ RAD MON FLOW LO CLOSE indication for ICVC 516 Letdown now at ZERO RO identify and report loss of letdown flow Diagnosis closure of ICVC 516 SRO identify / acknowledge loss of letdown How Concur diagnosis of closure of ICVC 516 SRO Direct actions (see IC07 F 24)OR AOP 2A: Shut ICVC 515 L/D CNTMT ISOL e Operate charging pumps as necessary to maintain Pressurizer level near normal o Verify 1 ilS 2516A is in NORMAL at IC43 ) e Attempt to restore Charging and letdown per OI 2A (may wait for results of troubleshooting spurious closure). SRO Contact OMC to investigate closure! status of ICVC Sl6,

l Scenario No: 12 Event No. 4 Page .JL of .12 , ' Sent

Description:

Control Element Assembly 35 reed switch position indication fails due to open circuit in reed switch assembly. lime Position Applicant's Actions or Behavior CUE: Annunciator alarm IC05 D-31 SEECONDARY CEA POSITION DEVIATION 14 " 1C05 D 32 CMI Metroscope position indication erratic RO identify and report erratic position indication / failure of position indication for CEA 35 Determine CEA is neither dropped nor misaligned (power stable, Nis reading same, Pu pressure stable) SRO identify / acknowledge failure of position indication for CEA 35 Concur with CEA status May reference AOP 1B and /or 01-42. SRO Recognize applicability of Technical Specification

3.1.3.3 ACTION Within 6 hours restore to operable, or be in at least ilOT STANDBY, or reduce power to < 70* h using boration. Further actions required to maintain 70% powcr-e CEA Group with inop position indication is fully withdrawn OR e CEA Group with inop position indication is fully inserted i e 3.1.3.1 ACTION With CEA Motion Inh. bit inop, within 6 hours either e Restore to operable e Fully withdraw Group 3 & 4; Withdrav' Group Sto < 5% insertion OR e Be in at least ilOT STANDDY SRO Direct RO to withdraw Group 5 in CMI bypass as necessary durin; power increase SRO Contact OMC/l&C to investigate failure of CEA 35 position. s.

[ Scenario No: 12 Event No. 5 Page 7 of.12

     ' ' vent

Description:

Load rejection results when CV 1 for Main Turbine fails closed 10% from current position. Time Position Apphcant's Actions or Behavior CUE Annunciator Alarm IC06 E 29 CV 1 position indicated LOWER than expected. Megawatt indication lower than expected RCS pressure and temperature increase higher than expected Tc off program high IlOP identify and report loss ofload' decreasing generator output RO identify and report increasing RCS temperature and pressure CREW identify CV l position not as expected SRO identify / acknowledge plant status and f ailure of CV l. SRO Direct actions of AOP-7F (& possibly 7E) CREW e Take action to stabilize the plant l e Control Tcold at program I e Verify PZR lesel control maintaining level at program o Verify PZR pressure control maintaining pressure at program

l Ensure Feedwater level control maintaining SG levels at ZERO inches e

Ensure secondary safetics, TBVs and ADVs are closed at proper pressure. e Insert CEAs to lower reactor power SRO e Notify Main Turbine System Engineer

                  !!OP      e    Adjust AUTO setpoint wheel for I PIC-4056 TURBINE BYPASS VLV-e Set to pressure just above present SG pressure w hile maintaining TBV shut SRO       Recognize applicabiht) of Technical Specification ACTION e

3.2.5 DNB part. meters (if applicabic)- restore parameter to within limit in 2 hours SRO Contact OMC/l&C to investigate failure of turbine control valve CV-1. Notify BP-SO of reason for loss ofload

l Menario Nr 12 Event No. 6 Page .1 tL of .12

, '

vent

Description:

A large tube leak of approximately 100 gpm (at normal operating pressure) occurs on the 12 SG. lime Position Applicant's Actions or Behavior CUL: Annunciator Alarm ICl7 L-10 RAD MON PANEL IC22 IC22 A 4.2 UNIT 1 S/G B'D IC22 B4.1 UNIT 1 CNDSR OFF GAS I May recognize plant computer alarm for RI-4014 pHor to the following: SG Blowdown alarm light for RE4014 Condenser Offgas alarm light for RI 1752 Lowering RCS pressure and Pzr level. 50 level rising or constant with less feedwater flow CREW identify 4 d report excessive RCS leakage / radiation monitor trends and alarms

SRO identify / acknowledge excessive RCS leakage / rad monitor alarms SRO Implement AOP 2A EXCESSIVE REACTOR COOLANT LEAKAGE e Notify RCSS of excessive RCS leakage / radiation concerns

Direct Chemistry to sample bOTil SGs e Directs reactor trip if PZR pressure lowers tt , ,,re trip value 1

l CREW e Determine if a SG Tube Leak exist-

SG sample

                                 =     l RI 1752 Ccndenser Off gas radiation levels e

1 RI 4095 or 1 RI-4014 SG B/D radiation levels e I RIC 5421 or 1 RIC 5422 Main Steam Line Rad Monitor levels I RIC 5421 A or I RIC-5422A Main Steam N-i6 Rad Monitor levels a SG water level rise e Feed flow mismatch Determine and report SG tube leakage for 12 SG CREW When SG tube leakage determined-Shut Letdown CNTMT ISOL valves e 1-CVC 515-CV m

Scenar o No: 12 Lvent No. 6 Page 8-11 of.12

1. vent Description; A large tube leak of approximately 100 gpm (at normal operating pressure) occ',:rs on the 12 f re.

 ,  hme ' Positir'I                                                 Applicant's Actions or Behavior e    I CVC 516-CV ( Already shut due to earlier failure of CVC 516)

CREW (AOP-2A cont.) (cont.)

Ensure SG II/D valves shut e 1 ilD-4010-CV 11 SURF

] . e I-IlD-40ll CV . GOT 1-BD-4012-CV 12 SURT e 1 BD-4013-CV 12 BOT e llorate to reduce Tave to < 537'F, by either method-e ilAST then R%T e Open 1-CVC 514 MOV BA 71 RECT M'U e Start all available charging pumps 7

                                   . Start ONE IIA pump and operate for = 1 minute e     Shut 1-CVC-514 MOV

Open 1.CVC 504 MOV RWT CilG PP SUCT Shut I-CVC-501 MOV VCT OUT OR e lloration from BAST e Open I CVC-514 MOV BA DIRECT M'U e

Start all available charging pumps

Start ONE BA pump and operate for = 1 minute Operate the IIA Pump = 15 seconds per minute thereafter.

RO e Obtain desired rate of pow er reduction-

Adjust boration rate

                              . Using CEAs DOP

Reduce Turt>ine load as necessary to maintain SG pressure between approximatclhEpsia and 825 psia CREW =

When any of the followmg exist, trip the reactor with permission of SS/CRS-

Tave < 537'F PZR level CANNOT be maintained above 101 inches e

PZR pressure reaches TM'LP pretrip setpoint

Scenario No: 13 Event No. 6 Page 8 11 of.12 Event

Description:

A large tube leak of approxirr.ately 100 gpm (at normal operating pressure) occurs on the 12 SG.

 ;  lime    Position                                             Applicant's Actions or Behavior RO           When directed, depress one set of Manual RX trip buttous SRO          Direct the implementation of EOP-0 POST-TRIP IMMEDIATE ACTIONS RO           Perform Post lrip ..n' mediate Actions:

e Depress ONE set of Manual RX TRIP buttons e Checks reactor tripped-

Prompt drop in NI power

                             . Negative SUR e    Check ALL CEAs fully inserted e    Verify demin water makeup to RCS is secured e    11 & 12 RCMU pumps secured e

VCT M/U valve 1 CVC 512-CV is shut e if RCS ht/U is in DIRECT LINEUP, RWT CHG PP SUCT valve 1-CVC-504-MOV is shut BOP e Check reactor has tripped

Ensure turbine has tripped-
Depress U-l MAIN TURB TRIP button Check Turbine Main Stop Valves shut
Check turbine speed drops e

Verify turbine generator output breakers open-e 11 GEN BUS BKR,0-CS-552 22 e 11 GEN TIE BKR,0-CS-552-23 u , ,. .. .

Scercrio No: 12 Event No. 6 Pege . B-1I of .l.2 j Event

Description:

A large tube leak of approximately 100 gpm (at normal operating pressure) occurs on the 12 SG, lime Position Applicant's Actions or Behavior e Varify 11 GEN FIELD BKR l CS-41 open e Verify 11 GEN EXCITER FIELD BKR l CS-41E is open BOP e Check 11 OR 14 4KV Vital Bus energized e Check ALL 125V DC BUS VOLTS greator than 106 volts e Check at least ONE set of 120V AC Vital Buses is energized e Check at least ONE 208/120V INSTR AC DUS is energized e IF ANY RCPs are operating. TilEN verify component cooling flow to the RCPs.

Dispatch an operator to verify Switchgear Room Vent. operating RO e Ensure PZR pressure stabilizes between 1850 psia and 2300 psia AND is trending to 2250 psia Determine PZR pressure is continuing to drop Verifies or manually operates heaters and sprays to attempt to restore pressure (heaters will not operate if pressurizer level is less than 101" e

When PZR pressure falls to 1725 psia, verify SIAS actuates (May manually actuate SIAS if directed) o Perform RCP Trip Strategy-o- When pressure drops to 1725 psia, trips either o ll A AND 12B RCPs or o llB and 12A RCPs e if CIS actuates, trips ALL RCPs e if RCS temperature and pressure are less than the minimum pump operating limits PER Attachment (1), RCS PRESSURE TEMPERATURE LIMITS, THEN trip ALL RCPs NOTE: EOP-0 Actions continue in Event 7

                                 /                                                                                   m

hcenano No; l2 Event No. 7 Page 12-13 of.12 ven t Desenption: The il 11 PSI fails to automatically start wben the SIAS is generated. The pump is capable of being started manually. 3 Time Position Apphcant's Actiorts or Behavior CUL Annunctator alarm IC0911 17 11 HPSIN$iAS BLOCKED *AU10 START II HPSI pump Green (stopped) light remains lit No pump discharge prenure CREW Identify and report failure of 11 llPSI pump to start. SRO identify / acknowledge failure of 1I llPSI pump to' start. RO!!!OP Perform actions of IC09 ALM window 11 17; e Ensure 13 IIPSI pump ie running e Consider aligning and starting 1;ilPSI Pump e Direct opera'~ to kically check breaker 152 1108

                             . Breaker racked in e     Charcing springs charged e      186 Lockout reset e

Direct operator to locally check Ii lipSI PP handswitch I HS 30lX at IC08 in NORMAL i RO (LOP-0 cont.) e Ensure PZR level stabilizes between 80 and 180 inches and is trending to 160 inches e if NOT operate charging and letdown to restore

                         . Ensure RCS subcooling GREATER TilAN 30'F I

BOP

Verify turbine bypass valves or ADVs operating to maintain-SG pressures between 850 and 920 psia e

Tcold between 525' and 535'F e Check at least one SG available for controlled heat removal e SG level between 170 and +30 inches e Main or Aux Feedwater operating to maintain level e Check at least one RCP operating in loop with available SG e if any RCP operating, check Thot minus Tcold LESS THAN 10'F in loop with available SG 1 l ____ _ n

Scenano No; l2 Event No. 7 1 Page 12-13 of.12 Lsent

Description:

lhe ll HPSI fails to automatically start when the SIAS is generated. The pump is capable of being started manually. lime Position Applicant's Actions or Behavior

CREW e Check Containment pressure less than 0.7 psig e Check Containment temperature less than 120'F e Check contairment radiation monitor alarms CLEAR with NO unexplained trends-e Check RMS alarms CLEAR with NO unexplained trends-

I RIC 5415 U l wide range noble gas
I RI 1752 Condenser Offgas
l RI 4014 Unit I SG Blowdown
I RI 5415 Unit I Main Vent Gaseous Detennine that trends prio to trip indicate SG tube leakage e if not done prior, secure SG Blowdown g NOTE: May transition to RLEC if RI 4014 and'or RI 1752 are in alarm.

SRO e Determine Recovery Procedure pcr Diagnostic Flowchart-e NO for RCS press /inv s fety function e NO SG pressure <800 psia e YES SG D'D or Offgas RMS alarm Consider EOP-6 (SGTR) e NO for Rad Levels Ext to Cont safety function e YES SG B/D or Oligas RMS alarm Consider EOP-6 (SGTR) e Single Event Diagnosis

l Scenario No: 12 Event No. 8 Page 14-19 of .12

 ' Tent

Description:

lhe large tube leak on the 12 50 increases in magnitude to a multiple tube rupture.

    'l ime  Position                                             Applicant's Actions or Behavior SRO      implement LOP-6 STEAM GENERATOR TUBE RUPTURE CREW     e

) e Commence SAFLTY l UNCTION ST ATUS CilECKS Determine SGTR diagnosis correct CREW e if P/.R pressure LESS TilAN OR EQUAL TO 1725 psia OR CNTMT pressure GREATER TilAN 2.5 psig-e Verify SIAS actuation e Determine maximum safety injection flou exists-e 1I and 13 IIPSI pumps running Reports 11 llPSI pump NOT running (May have been started manually in EOP-0) e llPSI now per ATTACilMENT(10) when pressure below 1270 psia e if Cows NOT maximited, and NOT previous performed, start 12 fiPSI pump e If desired, verify safety injection system lineup per ATTACilMENT (2)

                          .      I 1 and 121. PSI pumps running e

LPSI How per ATTACllMENT (11) when pressure below 185 psia e All charging pumps running RO e Perform RCP 'Irip Strategy-e When pressure drops to 1725 psia, trip cither e ll A AND 12B RCPs or

118 and 12A RCPs e if CIS actuates or Component Cooimg How to RCPs CANNOT be verified , trip ALL RCPs

if RCS temperature and pressure < minimum pump operating limits per ATTACilMENT (1), trip Al L I' cps RO e With SIAS actuated, verify boration in progress-I CVC-512-CV VCT M'U valve shut I-CVC-514 MOV BA DIRECT M'U valve open e BAST GRAVITY FD valves open-e 1 CVC-508-MOV e 1-CVC-509-MOV

                                                                                                                            ---m- u                   -

Scenario No: 12 Event No. 8 Page 1419 of E Lvent

Description:

The large tube leak on the 12 SG increases in magnitude to a multiple tube rupture, lime Position Applicant's Actions or Behavior e ALL available BA pumps running e I-CVCA01 MOV RWT CilG PP SUCT is shut e 1 CVC 501 MOV VCT OUT valve shut ALL available charging pumps running e Record time boration started e Record BAST levels-e 11 BAST e 12 BAST e Continue boration until ONE condition met-e j 116% of Shutdown Margin requirements met per NEOPs

BAST level lowered a total of 87 inches e Boration has been in progress for-40 minutes with TilREE charging pumps running 60 minutes with TWO charging pumps running 127 minutes with ONE charging pump running CREW Commence RCS couldown e if SGIS NOT actuated-e When SGIS _ BLOCK PERMITTED alarm received, block tne appropriate train SGIS CREW (EOP-6 cont.)

(cont.) e if SGIS actuates and condenser is available, Reset SGIS e Place CBPs in PULL TO LOCK e Match handswitch positions per ATTACHMENT (7) l e Block SGIS

                                              ,                                                                                       l

Scenario No; l2 Event No. 8 Page 14 19 of 3 Event DescriptMn: 1 he large tube leak on the 12 SG increases in magnitude to a multiple tube rupture. i Time Position Applicant's Actions or 11ehavior e Reset SGIS signal e Open 1107.11 MSIVs llOP e if TURil 11YP valves (TilVs) available-e Ensure ADVs shut Commence rapid coolwwn to Thot <515'F NOT to exceed 100*F in any one hour, open TBVs e if THVs NOT available-

Prior to isolating 12 SG, record ADV open & close times for dose cales e

Conduct rapid cooldown to 'thot <515'F NOT to exceed 100'F in any one hour, opening ADVs l IlOP e Secure Main Feed e Trip L P, e Shut SG FW ISOL e 1 FW-4516-MOV e I FW-4517 MOV e Place CDPs in PULL TO LOCK e Place ONE COND pump in PULL TO LOCK e Place HDT Pumps in PULL TO LOCK e Shut hotw ell to CST dump CV by placmg controller 1 LIC-4405 in MANUAL with 50% output ilOP e Establish AFW flow

                              . If 13 AFW pump available e    Open 12 SG motor driven train AFW valves i                                      e     1 AFW-4522 CV
                                        . 1 AFW-4523-CV I                                    e     1 AFW-4532-CV

Scenario No: 12 Event No. 8 Page 14-19 of .12 Event (Ascription: The large tube leak on the 12 SG increases in magnitude to a multiple tube rupture. Time Position Appi. cant's Actions or Behavior e 1 AFW-4533-CV e Start 13 AFW Pump e Restore and maintain SG level between 170 and +30 inches while NOT exceeding cooldown rate of 100*F in any one hour using e 1 AFW-4525 CV e I AFW-4535-CV

                          =    Dispatch an operator to standby to shut 12 SG ADV CREW       4    Identify the most affected SG (12)-

e Mismatch in feed flow prior to trip e Unexplained rise in SG level prior to trip e Main Steam Line RMS

Post Trip SG level changes e SG samples y e When Thot <515'F isolate 12 SG.
Shut 12 MSIV e Verify I MS-4052 MOV 12 MSIV BYP shut e

Shut 12 ADV using lland Transfer Valves locally-e Verify 1 11C-4056B 12 ADV controller is set to ZERO % e Align 12 ADV hand Transfer Valves to POSITION 2 e Verify 1 FW-4517 MOV 12 SG FW ISOL is shut e Shut 12 SG AFW MAIN STM SUPP & BYP valves-

I MS-4071-CV e I MS-4071 A CV CREW (EOP-6 cont'.)

(cont.)

Shut 12 SG AFW BLOCK valves-
I-AFW 4530-CV e I AFW-4531-CV e I AFW-4532 CV I e I AFW-4532-CV i

Scenario No: 12 Event No. 8 Page 14-19 of .12 Event

Description:

The large tube leak on the 12 SG increases in magnitude to a multiple tube rupture. Time Position Apphcant's Actions or Behavior e Shut 12 SG D'D valves-

I BD-4012 CV e I BD-4013-CV e

Place 1 11S-6622 to CLOSL to shut the MAIN STM UPSTREAM DRN ISOL e Observe locally from Aux Bldg roof that SG Safety Valves are shut NOTE: Operator reports boek NO indications of steam release e Verify the most affected SG. e iI SG level change consistent with feed now e SG samples verify higher acti'.ity in 12 SG NOTE: Chemistry will report /hase reported sample results by this point i i l CREW = Contmue RCS cooldown e if any RCPs operating, continue cooldown to 300*F while NOT exceeding cooldown rate of 100*F in any one hour e if RCPs are secured, reduce cooldown rate to 35'F/hr e Verify now in 12 SG loop Loop Tcold trend consistent with other loop Tcold

Tcold > Thot e

Disable 12A and 12 B RCPs by removing the Reactor Coolant Pump Breaker CLOSE fuses e 12A RCP- 252-12P01 AND 25212P02 e 12B RCP-25214P01 AND 25214P02 CREW = Evaluate need for llPSI/LPSI Throttlingrfermination

When following conditions can be maintained-e At least 25'F subcooling (CETs)

   $cenario No    12                              livent No.                              8                                      Page 1419 of 12 Event

Description:

The large tube leak on the 12 SO increases in magnitude to a multiple tube rupture. Time Position App licant's Actions or 13ehavior e PZR level > 101 inches e At least ONE SO available for heat removal e RVLMS indicces level > top of hot leg itPSI flow can be reduced by throttling itPSI 11DR valves OR stopping ONE HPSI pump at a time-

Maintain RCS subcooling between 25'F and 140'F (CETs) e Maintain PZR level between 101 inches and 180 inches e

if PZR pressure > 200 psia AND either constant or rising, stop operating LPSI pumps e if criteria CANNOT be maintained after pumps are throttled or secured, restart appropriate pumps and restore full flow 5 I

rp Simulation Fccality Cahert chfTs Scenario No.: 3 Op Test No.: 1 Examiners: Operators: SRQ RQ DD2 To evaluate the applicants' ability to initiate a normal plant power decrease; to implement the ALMS, Ols, Objectives: AOPs, as appropriate, for a malfunctioning control system on Steam Generator Feed Pump (SGFP), trip of running floric Acid Pump, failure of VCT level transmitter with sw ap of charb ing pump suction to RWT, trip of SGFP, and turbine trip due to EHC power fault, and to execute the EOPs with an ATWS condition following the turbine trip and subsequent pressurir.cr steam space LOCA due to failed open Safety valve. Initial Conditions: The plant is at 80% Power, MOC (IC-68) Danger tag iI AFW Pp IMS 3988 " TRIPPED DO NOT RESET" Dypass Channel "C" TM/LP with key 7 12 IIAST aligned for DIRECT RECIRCULATION IAW OI 2C,6.3 with Fwric Acid Pp 12 tunning.

1) IIS-210 in MANUAL

2) IIS-2512 in CLOSE

3) FIC 210Y in MANUAL set to 0%

4) 12 BAST recirculation valve CVC Sil CV open Turnover: Present plant conditions: 80% power, MOC; Unit 2 is in MODE 6 for refueling -

Power history: Decreasing power at 10*i/ hour to comply with ACTION statement of Technical Specification

   ;               3.7.1.2.

( Equipment oui of service:

1) II AFW Pp has failed turbine blades and is under repair. The pump has been unavrilable for 6b days and may possibly be returned to service within 24 hours. Operations Management had decided to initiate a plant shutdown about 2 hours ago, to ensure compliance with the Technical Specification ACTION statement.

I

2) Channel "C" Tht/LP trip bypassed at 0235 for troubleshooting.

Surveillances due: 12 BAST is currently on recirculation IAW OI-2C, section 6.3 for another 30 minutes for planned rampling. Instructions for shift:

1) Continue with downpower to HOT STANDBY conditions. A decision will then be made concerning continuing cooldown to HOT SHUTDOWN.

2) 12 B AST may be taken out of recirculation after 30 minutes.

SCENAR-3.RTF 1 10/14/9711:11 AM

Lvent Malf. Lsent Lvent No. No. Type

DescripHon Preload 018 I ailure of automatic reactor trip (ATWS)

(Irps005) MT ALL 019 Failure of MANUAL reactor trip (ATWS) (Irps006 i N/A R RO Contmu; normal plant shutdown to Hot Standby. N BOP 2 182,4, 5 % l BOP Approximately 5 minutes after commencmg the power decrease and with at least (vfw015_02) 5% load shed, a malfunction in the hydraulic system of 12 Steam Generator Feed Pump Governor System occurs causing ptimp speed to change that results in 5% closure of SGFP control valve FROM CURRENT position, ne cand.idate is expected to recognize that a problem exists with the selected SGFP, ne candidate should attempt to gain manual control of the SGFP, The candidate is exper.ed to implement AOP 30. 3 082,O C RO Approximately 2 minutes after completing the required actions of AOP 3G, the (Icscsol4,01) 12 Boric Acid Pump trips. De candidate is expected to recognize that the Boric Acid Pump has failed, and should stop any operations involving use of boric acid. Upon diagnosing the cause, the candidate may select the attemate Boric Acid Pump for operatl 1. The candidate is expected to comply with Technical Specifications 3.1.2.8,3.1.2.2 and 3.1.2.6. 4 077, LOW I RO _ Approximately 5 minutes after placing the alternate Boric Acid Pump in (levcs009) operation, VCT level transmitter 1 LT 1.7 fails low, rest.lting in an autamatic realignment of Charging Pump suction to the RV'T. He candidate is expected to recognize that a problem exists and that the Charging Pump suction has realigned to the RWT. The candidate should either isolate Charging and Letdown and manually control Charging to boration flow, or force realignment of Charging Pump suction to the VCT with valve breakers left in open position, as appropriate. t , 170,1 C BOP Following decision on controlling boration with failed VCT level transmitter,12 (momentary) Steam Generator Feed Pump trips. ne candidate is expected to recognize that a Steam Generator Feed Pump has tripped, and should take immediate action to insure that sullicient feed capuig is available to maintain Steam Generator levels.1 ne candidate is expected to implement AOP-3G. b 127, O C ALL Approximately 5 minutes aller completing the required actions of AOP-30, a (Itgol 3_01) Turbine trip occurs due to an EHC Power Fault. He Reactor does not trip [018 automatically or manually. The candidate is expected to recognize that a

              )                                                                                                          Turbme trip has occurred and that the Reactor failed to trip. He candidate

[(.lrps005) ) should attempt to manually trip the Reactor and upon failure to trip, complete (019 contingency actions required to corppensate for the ATWS. 1 ((lrps006 ) 7 06),90 % MT ALL Subsequent operation of Pressurizer Safety Valves due to ATWS condition, (vrcs022) results in RV 200 failing open. De candidate should implement EOP-5 based on Pressurizer steam space LOCA. Scenario should end following attempts to maintain RCS Subcooling IAW EOP-5, Section M.

   *(N)ormal,                                         (R)eactivity                                             (1)nstrument,     (C)omponent,       (M)r.jor Transient SCENAR-3.RTF                                                                                                                           2 10/14f9711:11 AM l

l

SCENARIO lo3 OVERVIEW From 80% power, a normal pow er decrease at 10%'hr shoald be established IAW OP-3, section 6 4. During the power decrease, a malfunction in the hydraulic system of 12 Steam Generator Feed Pump Governor S) stem occurs causing pump speed to change (drop) due to control valve position change of 5% (closed) from , current position. ne candidate is expected to recognize that a problem exists with the selected SOFP. ne candidate should attempt to gain manual control of the SGFP. De candidate is expected to implement AOP 3G. After completing the required actions of AOP 3G, the 12 Boric Acid Pump trips. The candid.te is expected to recognlic that the Boric Acid Pump has failed, and should stop any operations involving use of boric acid. Upon diagnosing the cause, the candidate may select the attemate Boric Acid Pump for operation. The condidate is expected to comply with Technical Specifications 3.1.2.8,3.1.2.2 and 3.1.2.6. NOTE that Tech Spec 3.1.2.8 may not be applicable if power is less than 80%. Afler placing the alternate Boric Acid Pump in operation, VCT level transtaitter 1 LT 227 fails low, resulting in an automatic realignment of Charging Pump suction to the R%T. He candidate is expected to recognize that a problem exists and that the Charging Pump suction has realigned to the R%T. He candidate should either isolate Charging and Letdown and manually control Cnarging to boration flow, or force realign .cnt of Charging Pump suction to the VCT with valve breakers left in open position, as appropriate. Following decision on controlling boration with failed VCT level transmitter,12 Steam Generator Feed Pump trips due to inadvertent trip signal be generated. The candidate is expected to recognize that a Steam Generator Feed Pump has tripped, and should take immediate action to insure that sufficient feed capacity is available to main'ain Steam Generator levels. The candidate is expected to implement AOP-3G. After completing the required actions of AOP 30, a Turbine trip occurs due to an EHC Power Fault. The Reactor

does not trip automatically or manually. The candidate is expected to recognize that a Turbine trip has occurred and that the Reactor failed to trip. The candidate should attempt to manually trip the Reactor and upon failure to trip, complete contingency actions required to compensate for the ATWS. Subsequent operation of Pressurizer Safety Vah es due to ATWS condition, results in RV 200 failing open. De candidate should implement EOP-5 based on Pressurizer steam space LOCA. Scenario should end following attempts to iaaintain RCS Subcooling IAW EOP 5, Section M.

4 SCEN AR -3.RTF 3 10!!4'9711:11 AM

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

[ Scenano No; l3 Event No. I Page L-2._ of ,,1)

                ' vent

Description:

Normal plant shutdown to llot Standby from 80% power. Time Position Applicant's Actions or Behavior 1 CREW Review Prerequisites and Precautions associated with OP 3 NORMAL POWER OPERATlON 4 SRO Direct load der.rease per OP 3 Section 6.4:

Reviews guidelines for LRNis followed e RPS Delta-T power is primary power indication e Comparisons should be made periodically between the FOUR RPS channels and plant computer for secondary calorimetric
Ni power should be used for trending purposes only e Method of reducing reactor power e Instrtion of control rods.

(NOTE: Boration is NOT available per turnover instructioes as the BAST is set up for direct recirculation)

RO Ensure Pressuriter spray flow;

Energize PZR backup heater banks e

Adjust PZR Pressure Controller setpoint to maintain 2250 psia j Reduce reactor pow er to maintain Tc within 2 'F of program j e insert control rods (NOTE: Boration is NOT available per turnover instructions as the BAST is set up for direct recirculation) i j-BOP Decrease turbine generator load to maintain Tc within 2 'F of program (in LOAD LIMIT) Decrease the load by decreasing the load limit setpoint in small increments AND maintain LOAD SET no higher than 100MWe above actual load OR e (in LOAD SET) Decrease load by momentarily depressing the LOAD SELECTOR DECREASE button AND maintair. LOAD LIMIT no higher than 100MWe above actual load CREW Ensure requirements of APPENDIX D are met e if Tc deviates > 2*F from program Tc, notify CRS AND initiate corrective actions to restore d e Reduce MSR 2 stage pressure in no more than 50 psig increments per Figure 2 (local) e Notify Chemistry to sample RCS if power is changed by > 15% in ONE hour l

Scenario No: 13 Event No. I Page 1:2_ of ll Leent

Description:

Normal plant shutdown to llot Standby from 80*/ power.

  'Isme   Position                                                         Applicant's Actions or Behavior CREW       (APPENDIX D Cont.)

(cont.) e Do NOT exceed turbine limits e 150*F/hr rate of change of 1" stage shell inner metal temperature (Point 6 on TR-4404) 75'F 1" stage shell metal temperature differential (Diff between Points 6 & 7 on TR 4404) e Unloading rate of 10% step change or 5%/ min e Periodically compare all indications of pawer e if unexplained difference exist between Ni, Delta T, or calorimetric power AND plant conditions do NOT require expeditious shutdown, stabilize reactor power until discrepecy is resolved e Periodically ZERO the Voltage Regulator Transfer meter Maintain ASI within limits of COLR e Periodically verify PZR Program Level is within acceptable PZR level band per Figure (3) e Periodically monitor ASl to ensure oscillations will NOT reach the ASI pre trip value ' k IlOP At approximately 575 MWe (65% reactor power) e Ensure NO MORE than TWO Condensate Pumps and TWO Condensate Booster Pumps are running

d Ensure MSR 2 stage liigh Load MOVs are shut

                         . 1 MS-4017 MOV e   I MS-4018-MOV

Scenctio Pi: 13 Event No. 3 Page .A4., of .11 laent

Description:

liydraulic system for 12 SG I ced Pump (SGI P) governor system causes pump speed change by altering control vahe position with control valve ending up shut by 5% from cunent position. hme Position Applicant's Actions or lichavior CUE: Annunciatm alarm 12SGIPI SPD CON 1R SYS 1ROUllLL May have various computer alarms Decreasing 12 SOFP speed increasing 11 SGFP speed Decreasing FW flow flop identify and report failure of 12 SGIP speed control SRO identify / acknowledge failure of 12 SGI P speed control SRO Direct action of AOP.3G h1ALFUNC110N Ol' hiAIN 1 LEDWAlLR SYS1Lh! Section Vll If SG level approaches .50 inches with approval of SS'CRS, Trip the reactor l l 140P Attempt to manually control 12 SGi P speed. I Perform action of AOP 3G e if SOFP controller fails.

Verify SGFP control rm 1. . ins shifled to MAN or DIRET GOVNR VLV at OCS e Adjust SGFP speed to maintain.
Minimum of 50 psid across FhVs SG levels betu een .24 inches and +30 inches e

llalance load between 11 & 12 SGFPs e If a SOFP Speed Controller is erratic in AUTO-e Sh.fi both SGFP SPD CONTRs to MANUAL e- Adjust SGFP speed to maintain.

Minimum of $0 psid across FRVs e

SG lesels betw een .24 inches and +30 inches llOP [AOP 3G Se. tion Vil Cont.) l

acenmo No; 13 Event No. 2 Page 2.-l.of .18 i Lvent Descrintion: il>drauhc system for 12 SG t eed Pump ($GFP) gogemor system causes pump speed char'ge by altering I control valve position with control valve ending up shut by 5% from current position. lime Position Applicant's Actions or Behavior (cont.)

When failed SOFP Speed controller determined.
Place unaffected (11) SGFP SPD CONTR in AUTO.
Match AUTO signal te SOFPT SPD Bld.', ADJUST e

Place 1 111C-451611 SGFPT SPD CONTR in AUTO e lialance load between 11 and 12 SOFPs .

Adjust SGFPT SPD BIAS ADJUST on 11 SOFP(in AUTO) OR e Adjust SOFPT SPD CONTR output in MANUAL on 12 SOFP e

When 50 levels are stabilized slowly adjust SGFPT SPD BIAS ADJUST for 11 SOFP (in AUTO) to obtain setpoint between 4.8 and $.2 SRO Contact OMC/l&C to investigate failure of 12 SOFP speed control' governor system l J

Scenario No: 13 Lvent No. 3 Page1 of .18

1. vent

Description:

1he 12 lloric Acid pump trips. I ilme Position Applicant's Actions or lichavior cub: lloric Acid pump status lights de-energite (IC07) Alarm on IC07 - F.38 Computer alarms will cles for 12 BA Pump running RO identify and report trip of the 12 lloric Acid Pump SRO identify / acknowledge trip of 1211oric Acid Pump. RO Direct operator to locally check pump breaker $2 10406 Align system for makeup from the 11 Baric Acid Pump per Ol.2C SRO Recognite applicability of l echnical Speci0 cations:

3.1.2.8.a . Restore TWO required combinations of sv.irces & Dowpaths within 72 hours e

Verify Dowpatn from BAST 12 via gravity feed operable or e ilAST 11 & its gravity feed nowpa.h is operable e 3.1.2.2. No act!on applicable if e BAST 11 operable and either the ll boric acid pump or its gravity feed Dowpath is operable, and a charging pump is operable AND J e Flowpath from RWT via a charging pump is operable e 3.1.2.6. If > 80% power then restore 12 Doric Acid pump to operable within 72 hours e Illioric Acid pump (per TS 3.1.2.2.a)is required operable and capable of being powered from an operable emergency bus if > 80% power,12 Boric Acid Pump is required operable (per TS 3.1.2.8.a) and capable of being powcred from an operable emergency bus SRO Contact OMC to check breaker $210406 and'or 12 Boric Acid pump. I

_. _ - - - - - _ _ _ . - . . . - - - - . _ _ _ ~ - . - - . - . - . - _ _ = . - - - . - -- ._ - __ . _ - Scenario No: 1 Event No. 4 Page _6 of UI Ls ent

Description:

VC1 level transmitter 1 L1227ti fails LOW. j lime Position Applicant's Actions or 11chavior CUL: Annunciator alarm IC07 i 46 CilO l'P SUC1 iROM RW1 1 CVC 504 MOV RWT CilG PP SUCT valve open light lit 1 CVC 501 MOV VCT OUT valve closed light lit RO Identify and report charging pump suction swap to RWT 1 Diagnose boration of RCS and affect on power (rapid shutdown) 1 SRO identify / acknowledge charging pump suction swap to RWT i Diagnose boration of RCS and affect on power (rapid shutdown) RO Verify VC1 level n , mal on I L1226 Determine and report failure of 1.LT 227 SRO Direct actions to deal with boration, w hich could include: o Rapid power reduction per OP 3 o isolation of charging and letdown, with makeup to RCS only as necessary A o Realign to VCT by deenergizing 1 CVC 501 MOV and manually opening valve; Deenergizing 1 CVC-504 MOV and manually closing valve. (May also take llS 2504 to SilUT and 11S 2501 to OPEN. This uill override the signal from LT 22711) ROilOP Perform actions directed by SRO. SRO Contact OMC/l&C to investigate failurs of I LT 227.

                                                                                                   .-__y              ,,i,w. -.u.- y. - , r   "

w - - " ' ' ' - "'

__ - . - . . ~ . _ . = . _ _ _ - _ _ . .._ - _ . . - _ . . - _ _ . - =_ ~_ _ - _ _ _ - _ . - . - ._ Scen:rio No: I3 Lvent No. 5 Page ,,lIL., of .11 L5cnt Descnption: Inp of 12 SGF P. (NOll: 12 SGI P should still be runnmg from laent 2). Trip was due to momentary top

          ,                                signal generated by SGFP turbine protection finadvertentt lime     Position                                                 Applicant's Actions or llehavior CUL              Annunciator alatm 12 SGI PI 1 RIP Lowering 50 levels Reduced feedwater flow

Trip light for 11 SGFP llOP identify and report trip of 12 SGI P SRO identify / acknowledge inp of 12 SOFP
SRU Direct action of AOP 30 hiALTUNCTION OF MAIN Fl: 1 DWATER SYSTEM If SG level approaches 50 inches OR SG level is < 26 AND Main feedwater is NOT established, Trip the !

reactor if ALL conditions maintained, operatio ith Ohu SGTP above 440 MWE is permitted:

SGFP suction flow rate <l8,000 gpm e SGFP suction pressure > 250 psig e SGI P speed is > $350 rpm l

LIOP Perform action of AOP 30

,                                          e    With approval of SRO, attempt to start tripped SGFP

Verify shut the llP and LP s'ap valves I

e Check the DEMAND MIN indicator is illuminated at OCS

Reset the SOFP Vacuum trip and Turbine trip e Depress DIREC F GOV VLV pushbutton at OCS e Depress and hold the "up" SPEED arrow to obtain governor valve position approx. 3% to 5% above pre-trip gosernor valve position
When SG level approaches ZERO inches, adjust SGFP speed to maintain:
Minimum of 50 psli across FRVs e SG levels betaeen 24 inches and +30 inches I

l Scenario No: 13 Event No. 5 Page _7 8 of L8 la ent Descriptiorn 1 rip of 13 SGI P. (NOIE: 13 SOi P should still be running from Event 2). Trip was due to momentary trip signal pencreted by SGFP turbine prote : tion (inadvertent).

 ,   lime       Position                                                              Applicant's Actions or lichavior liOP       (AOP 30 cont.)

(cont.) e Shift OCS to filC control as desired: e Verify condition causing DIAGNOSTIC MAN light on Lovejoy alarm screen has cleared e Ensure filC (SOFPT SPD CONTR)is in MANUAL e Adjust o;tput of IllC to match OCS demand until XFER PERM indicator is lit e Depress lilC pushbutton on OCS e Check lilC pushbutton is illuminated e Check Demand RPM display on OCS and output oflilt are within 50 rpm i e Control SGFP speed by adjusting SGFPI SPD CONTR in MANUAL e Return controller to AUTO. t SRO Contact OMC/l&C to investigate reason for trip of 12 SOFP.

-.- - - - _ _ _ . _ . _ _ . . . . . - _ _ _ . . _ _ . _ - _ - _ . _ _ _ - _ . - - ~ . . - . _ - . ~ _ Scenario No: 13 Lvent No. 6 Page . 911. of .111 Lvent

Description:

lurbine trip due to LilC power fault caused by loss of 24 volt power supply, The reactor falls to trip automatically or manually. , lime Position Applicant's Actions or lichavior CUL: Annunciator alarm 1C021138 LilC SYS ELEC MALI UNCTION IC021137 TURil TRIP Turbine trip indication lights llOP Identify and report probler'1 wiUi LilC System electrical power. Reports that turbine will trip within 30 seconds if power is NOT restored SRO identify / acknowledge probicm with LCil System electrical power Concurs that turbine will trip in 30 seconds CRLW Dispatch operator to locally check breakers at LilC Cabinet 111I

SRO Directs manually tripping reactor if 30 seconds approaches (NOTE: If turbine trips prior to initiatir.g of manual reactor trip actions remain the same with the sequence of the IlOP reporting the turbine trip occurring first.) 4 RO 1 rips reactor by depressmg manual reactor trip pushbuttons. Identify and report failure of reactor to trip on manual actuation of trip pushbuttons Following determination of turbine trip, report failure of reactor to automatically trip on RPS actuation llOP identify and report turbine trip SRO Direct the implementation of LOP-0 POST TRIP IMMEDI ATE ACTIONS RO Perform Post 1 rip immediate Actions:

Depress ONE set of Manual RX TRIP buttons
Checks reactor tripped-
Prompt drop in Ni power e Negative SUR Determine reactor is NOT tripped and reports condition to SRO

Scenarm No: 13 Lvent No. 6 Page 3;.11 of ll Lsent

Description:

lurbine trip due to LilC power fault caused by loss of 34 volt power supply. The reactor fails to trip automatically or manually. lime Position Applicant's Actions or Behavior RO (LOP-0 cont.) (cont.) e Deenergize CEDM Motor Generator sets-e Open 12A 480V Bus FDR ($21201)

Open 13A 480V Bus FDR ($21301) e Open 12All2il 480V Bus TIE ($21212) e Open 13 All311480V Ilus Tie ($21312) e Check the Reactor has tripped by the following:

e Prompt drop in Ni power e Negative SUR e Reenergize 12A and 13 A 480V iluses by closing ANY breakers opened above

Check ALL CEAs fully insened

e Verify demin water mal-up to RCS is secured e iI & 12 RCMU pumps secured

VCT M'U salve I CVC 512 CV is shut e

if RCS M U is in DIRECT LINEUP, RWT CilG PP SUCT valve 1 CVC.504 MOV is shut ilOp e Check Reactor has tripped e Ensure Turbine has tripped.

Depress U l MAIN TURB TRIP button
Check Turbine Stop Valves shut e Check Turbine speed drops e

Verify Turbine output breakers open (11 GEN BKR,0-CS 552 22 & 11 GEN TIE BKR,0 CS 552 23)

Verify 11 GEN EXCITER FIELD BKR l CS 41E is open e

Verify 11 GEN FIELD BKR l CS-41 is open e Check ll OR 14 4KV Vital Bus energized e Check ALL 12$V DC BUS VOLTS greater than 106 volts e Check ai least ONE set of 120V AC Vital Buses is energized 7 Check at least ONE 208/120V INSTR AC BUS is energized IF ANY RCPs are operating, TilEN verify component cooling flow to the RCPs. l

Dispatch an operator to verify Switchgear Room Vent. operating L ..

d ! Scenario No; 13 Event No. 6 Page .2di_ of .ll

1. vent

Description:

lurbint trip due to EliC power fault caused by loss of 34 volt power supply. The reactor fails to trip q automatically or manually. 4

lime Position Applicant's Actions or Behavior 5

NOl l' Actions of EOP 0 continue in Esent 7 j - i ) 1 4 1 4 4 j r l

Scenctio No; i.3 Lvent No. 7 Page 12 18 of .lli Lvent

Description:

Pressurizer Safety Valve RV.200 fails open to 90%. l lime Position Applicant's Actions or llehavior CUL Annunciator alarm 1C06 E 22 PORV/SAILTY VLV ACOUSllC MON IC06 E.1 QUENCil TK ' TEMP 'LVL ' PRESS IC06 E.6 RXV/PZR VENT LINE TEMP 111 RCS pressure decrease Quench Tank level, pressure and temperature increase RO identify and report RCS pressure decrease and PZK Safety valve open 4 , (EOP 0 cont.) e Ensure PZR pressure stabilizes between 1850 psia and 2300 psia AND is trending to 2250 psia Determine PZR pressure is continuing to drop e Verifies or manually operates heaters and sprays to attempt to restore pressure e When PZR pressure falls to 1725 psia, verify SI AS actuates (May manually actuate SI AS if directed) e Perform RCP Trip Strategy.

When pressure drops to 1725 psia, trips either e ll A AND 1211 RCP3 or 4 e lill and 12A RCPs e if Cis actuates, trips ALL RCPs e

Ensure l'ZR level stabilizes betw een 80 and 180 inches and is trending to 160 inches e if NOT operate charging and letdown to restore

Ensure RCS subcooling GREATER TilAN 30'F e

If RCS temperature and pressure are less than the minimum pump operating limits PER Attachment (I), RCS PRESSURE TEMPERATURE LIMITS, TilEN trip ALL RCPs llOP e Verify turbine bypass valves or ADVs operating to maintain.

SG pressures between 850 and 920 psia e Tcold betw een $25'snd $35'F e Check at least one SG available for controlled heat removal e SG level betw een .170 and +30 inches e Main or Aux Feedwater operating to maintain level e Check at least one RCP operating in loop with available SG

Scenario No: 13 Event No. 7 Page 1218 of _Ul Lvent

Description:

Prenuriter Safety Valve RV 200 fails open to 90%.

                   ' lime  Position                                                    Applicant's Actions or Uchavior e      if any RCP operating, check That minus icold LESS TilAN 10'F in loop w tth available SO CRLW         e      Check Containment pressure less than 0.7 psig e      if pressure exceeds 0.7 psig-e        Verify ALL available C ACs operating e        Open CAC EMERGENCY OUT valves for operating CACs e      if pressure exceeds 2.8 psig, verify actuation e SlAS e        CIS e     if CIS actuated, trip ALL RCPs e     if pressure exceeds 4.25. psig, verify CSAS actuation e       Check Containment terr.perature less than 120'F e     if temperature exceeds 102*F-e        Verify ALL available CACs operating

Open CAC EMERGENCY OUT valves for operating CACs e Check containment radiation monitor alarms CLEAR wi*h NO unexplained trends.

e if alarm received, start the IODINE FILT FANS NOTE: Afg be driven to Rl.EC at this point

Check RMS alarms CLEAR with NO unexplained trends-e 1 RIC 5415 U l wide range noble gas e 1 RI 1752 Condenser Offgas e 1 RI 4014 Unit i SG Dlowdown
I RI 5415 Unit i Main Vent Gaseous SRO e Determine Recovery Procedure per Diagnostic Flowchart-e NO for P.CS press /inv safety function e NO SG pressure (800 psia e NO SG B'D or Offgas RMS alarm e NO to SG level response mismatch e

Consider EOP 5 (LOCA)

NO for Cont Envir safety function
NO SG pressure <800 psia e YES PZR pressure or levellow e

Consider EOP 5 (LOCA) I e Single Event Diagnosis

Scenario No: 13 Event No. 7 Page 121L of .18 Lsent 'Jescription- Pressuriier Safety Valve RV 200 fails open to 90% lime Position Applicant's Actions or Behavior i SRO 1ransition to LOP 5 LOCA e Direct actions per EOP 5 i CREW e Commence SAFETY FUNCllON STATUS CllLCKS

Determine LOCA diagnosia correct l

CREW e if PZR pressure LESS lilAN OR LQUAL 101725 psia OR CNTMT pressure GREATER lilAN 2.8 ) p5lS* e Verify S1AS c:4uation

Determine masimum safety injection flow exists-e 11 and 13 IIPSI pumps running e

llPSI flow per ATTACllMENT (10) when pressure below 1270 psia t i e 11 and 12 LPSI pumps runnin;, e LPSI flow per ATTACllMENT (11) when pressure below 185 psia e All charging pumps running RO e Perform RCP 1 rip Strategy-

When pressure drops to 1725 psia, trip cither e ll A AND 12B RCPs or e llB and 12A RCPs e

if CIS actuates or Component Cooling flow to RCPs CANNOT be verified , trip ALL RCPs e if RCS temperature and pressure are less than the minimum pump operating limits PER Attachment (1), RCS PRESSURE TEMPERATURE LIMITS, T}lEN trip ALL RCPs RO e Attempt leak isolatiori-

                                 . Verify shut 1/D C.iTMT isol e     I CVC 515-CV e     I CVC 516-CV

Check PORY leakage o Quench Tank parameters

Scenario No: 13 Event No. 7 Page .1218 of .11 Ivent

Description:

Pressuriter Salety Valve RV 200 fails open to 90%. Time Pos'tl Applicant's Actions or Behavior I e PORV disch temp, computer points. 1 e T107 e T108

Acoustical Monitor indication NOTE: Crew mayperform Alt. Actiom andisolate the PORVs RO (LOP 5 cont.)

(cont.) e Shut l PS 5464 CV RCS SAMPLE ISOL ' ' l e Shut RXV Vent valves-e I RC 103 SV I e I RC 104 SV e Shut PZR VENT valves-

I RC 105 SV e I RC 106 SV e Determine NO leakage !..tv CC System by-e Clear alarm on rad me titor 1 RI 3819 with NO rising trend e

CCW llEAD TK I *< L alarm (ICl3 K 17) clear Determine leak is inside CNTMT Safety valve on PZR open CREW e Observe CNTMT Sump level rises as RWT level drops RO e With SI AS actuated, verify boration in progress-e 1-CVC 512-CV VCT MU valve shut e 1 CVC 514 MOV BA DIRECT MU valve open e BAST GRAVITY FD valves open-

I CVC 508 MOV e I.CVC 509 MOV e ALL available (1i BA Pump) BA pumps rur.aing e 1 CVC 501 MOV VCT OUT valve shut
ALL available charging pumps running 7 +-r.- -. - - - - . . - - q. ww .y*.yv- -. -

7..-

v

__ . . _ . _ _ _ _ _ _ . _ . _ . . _ _ . _ _ . _ - _ _ . _ _ _ _ _ _ . . ~ _ _ . _ _ _ Scenario No: 13 Event No. 7 Page 121B . of .111 lacat

Description:

Pressuriter Safety Valve RV.200 fails open to 90%.

                   ~ lime              Position                                                          Applicant's Actions or 11ehavior i                                               e     Record time boration staned e     Recor<l flAST levels-e     ll BAST

1211AST l

RO (LOP 3 cont.) (cont.)

Continue boration untilONE condition met-e Shutdown Margin requirements met per NEOPs e llAST level lowered a total of 71 inches I e lloration has been in progress for.

                                                                 .      35 minutes with TilREE charging pumps running e      53 minutes with TWO charging pumps running e      105 minutes with ONE charging pump running i9 llOP            e     if pressure exceeds 2.8 psig, verify actuation

SIAS e CIS
If CIS actuated, trip ALL RCPs
Verify SRW Pump Room Ventilation per 01 15 section e

if pressure exceeds 4.25, psig, verify CSAS actuation and spray Dow is = 1350 gpm per pump-I F1-4148 (11 CS hdr How) ,

I F14149 (12 CS bdr Dow) e Direct Chemistry to place Hydrogen Monitors in service e

if hydrogen conc rises to 0.5%, OR hydrogen conc CANNOT be determined, direct Hydrogen Recombiners be placed in service per Ol 41 A BOP NOTE: M4 be on AFW due to SlAS (No SRW to Turbine Butidmg) l

Scenario No: 13 Event No. 7 Page 1218_. of 3 Event

Description:

Pressurizer Safety Valve RV 200 fails open to 90**.

       , lime      Posillon                                                  Applicant's Actions or 11ehavior I                        e     if Main feedwater available-

Establish shuidown feed system lineup e ONE operating SOFP e ONE operating Cl3P e TWO operating COND Pumps e (Il0TilllDT Pumps stopped)
Ensure feed flow establishing S0 levels between 410 and +50 inches

                 !!OP       (EOP 5 cont.)

(cont.)

When MANUAL control desired OR SO levels between + 10 and 450 inches-
Shift ilYPASS SG FW REG controller to Manual e Depress SG FRV IlYP RESET buttons e Adjust IlYPASS SG FW REO valves to maintain level CREW e With 1 cold GREA I ER lilAN ',00'F.
When SGIS, IlLOCK PERMITTED alarn received, block the appropriate train SGIS e Conduct a rapid cooldown to 300'F using TURIl 13YP valves or ADVs NOT to exceed 100*F in any ONE hour CREW e Evaluate need for llPSI/EPSI Throttlingrictmination e When following conditions can be maintained-
At least 30'F subcooling (CETs) e PZR level > 101 inches [141 inches if CNTMT pressure > 4.25 psig) e At least ONE SO ava!!able for heat removal e RVLMS indicates level > top of hot leg IIPSI flow can be reduced by throttling IIPSI IIDR valves OR stopping ONE ilPSI pump at a time.
Maintain RCS subcooling between 30'F and 140'F (CETs) e f

Maintain PZR level between 101 inches and 180 inches [ 141 and 190 inches} I -

e. n -, , , - e a,e

Scenario No: 13 Lvent No. 7 Page 12 ljL of .lli la ent 1)escription: Pressurarer Safety Vahe RV.200 failti open to 90%. lime Posi* ion Applicant's Actions or lichavior k e if P/R pressure > 200 psia AND either coratant or rising, stop operating LPSI pumps e if criteria CANNOT be maintained after pumps are throttled or secured, restart appropriate pumps and restore full flow CREW e Maintain RCS subcooling and PZR level e if bubble exists in PZR OR reactor vessel head, restore and mainta: subcooling between 30*F and 140'F (CETs)-

halse subco<!!ng by ANY of following.

e Operate PZR heaters

Raise RCS cooldown rate NOT to exceed 100'F in any ONE hour 9 If IIPIt ' low has been reduced, raisc llPSI flow i

e Lower subcooling by ANY of following-

Deenergite PZR heaters e Lower RCS cooldown rate e Throttle or secure llPSI' Charging flow e initiate Aux Spray e

if bubble exist in PZR AND llPS! flow secured, restore and maintain PZR level between 101 and 180 inches (141 and 190 inches) by operating charging and letdown w

Simulation i acility Cah ett Chffs Scenario No.: 4 Op les No.: 1 Examiners: Operators: SRQ ( < EQ y g To evaiua'e the applicants' ability to initiate a plant power decrease; to implement the ALMS. Ols, AOPs, as Objectives: appropriate, trip of a running Containment Spray Pump with loss of ALL Containment Spray systems, a malfunction of automatic control for maintaining the Main Generator hydrogen cooling, failure of CVCS letdown back pressure controller, a trip of the operating CVCS charging pump and a trip of a Circulating Water Pump; and, to execute the EOPs for a reactor trip with a loss of all feed flow to the Steam Generators. Initial Conditions: 1he plant is at 100?6 Power, MOC (IC 13) Danger tag 11 AFW Pp 1MS 3988 ' TRIPPED DO NOT RESLT" Danger tag 12 Containment Spray Pp PTL Danger tag Unit 2 to Unit i AFW Cross connect 2 AFW 4550 CV SilVT j lurnoser: Present plant conditions: 10096 pow er, MOC; Power history: Operating at 10096 power for the past 100 days. Equipment out of smice:

1) 11 AFW Pp has an oil leak on the governor 'md is under repair. The pump has been unavailable since 0500 and may possibly be returned to service within 2 hours.

e Surveillances due: 0-073K 1 CONTAINMENT SPRAY PUMP OPERABILITY TESTjust completed; 11 CS Pump is still running en recirculation per Engineering direction. Should tw ready to shutdown in about 5 minutes.12 CS Pump had failed the STP O-073 K 1 due to failure to develop sufficient flow, instructions for shift: Maintain 10036 power.

SCENAR-4.RTF i 10/14'971:55 PM

Lvent Malf. Event Event No. No. Type' Description Preload 186, 0 & I C ALL lloth trains of Al Ah fail to actuate. (lafw 004,01 (lafw 004_02

              )                                                12 AFW Pump fails to start due to throttWstop valve.

18),4 (5afw 001_02

i 190,O C llOP Running Containment Spray Pump 11 trips, resulting in BOlli CS Pumps out of (1siOO4_01) service. Technical Speci0 cations require placing the unit in llOT STANDBY within the next 7 hours. 2 N/A R RO Load reduction in accordance with Technical Specifications. (NOlE: N BOP Operations Management will contact shift, when informed of Es ent 1, that immediate shutdown should be initiated at 20Whr. 3 144, O I BOP Approximately 5 minutes after commencing the power decrease, Main Generator (Itg030_01) liydrogen Temperature Controller 1 TIC 1608 fails in AUTO isolating Service Water to the hydrogen cooler The candidate is e- ted to recognize that the generator hydrogen controller is malfunctioning aw is expected to take MANUAL control of the controller. The candidate is expected to maintain the generator within the operating limits specified by the pressure vs. load curves. 4 072 i RO Approximately 2 minutes after the Main Generator Temperature Controller is (levcs00h placed in manual and temperature stabilized, Letdown Back Pressure trartsmitter PT 201 fails low causing the back pressure regulating valves to close. The candidate is expected to recognize that a problem exists with the back pressure controller and to take manual control of the contrc,Iler Operation in manual will be complicated by the fact that there is no indication of back pressure available. 5 070,o C RO Approximately 5 minutes af ter Letdown Back Pressure controller is placed in manual and pressure stabilized, the 11 Charging Pump coupling breaks. The candidate is expected to recognize that a charging system abnormality exists and start another pum the candidate should diagnose charging pump problem and not charging It ik. Candidate should verify Technical Speci0 cations for required OPERb E charging pumps. 6 220,3 C DOP Approximately 2 minutes after determination is made that the charging pump is (Icw001_04) not functioning properly and another charging pump is started, the 14 Circulating Water Pump trips. The candidate is expected to recognize that a Circulating Water Pump has tripped and should take immediate action to insure that Turbine limits are not being exceeded. If necessary, the turbine should be manually tripped. 7 153, O M ALL Upon turbmc trip, OR if turbmc limits are serified to be within normal operating (14kv001_01 limits, then 5 minutes following stabilization, a loss of 4KV bus 11 occurs,2

minutes later a spurious SGIS "A" actuates. This results in a Reactor trip. The 244 candidate is expected to recognize the loss of 4KV bus 11 and the spurious SGIS (lesfa013) "A" actuation. The candidate should realize that with spurious SGIS, no S'O Differential Pressure will develop (no faulted S/G). Entry into EOP 0 is made and the loss of power to 4 KV bus 11 is addressed by actions of AOP 71. 8 [186,0 & I) 1 ALL Any attempts to manually initiate AFW flow to the S/G's fail (AFAS will not (183,4 ) C actuate,12 AFW Pump will not start,13 AFW Pump not powered due to low of 4 KV bus 11). This results in a totalloss of feed water flow (Unit 2 cross tie unavailable) and the candidate is expected to implement EOP 3. Scenario should end when once through cooling verified in EOP 3, Section J.

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

1 SCENAR-4 RTF 2 10/14/971:55 PM

SCENARIO l-4 OVERVIM

 < 1hc scenario begins at 100's powcr, with directions to maintain current power level. A surveillance hasjust been completed to test the 11 Containment Spray Pump. The System Engineer has requested the pump be left running for a few minutes following the test because he thought he heard some odd noises from a motor bearing tow ard the end of the te>t. Subsequently, the Containment Spray Pump 11 trip, resulting in DOTil CS Pumps out of service (the 12 CS pump was 005 at beginning of thift). Technical Specification 3.0.3 requires ACTION within ONE hour to place the unit in a MODE where the specification does not apply and to be in at least ilOT STANDilY within the following 6 hours. With Operations Management guidance, when contacted, a unit shutdown at 20* bhr is initiated IAW OP 3. Section 6.4.

After commencing the power decrease, Main Generator liydrogen Temperature Controller ITIC 1608 fails in AUTO, isolating Service Water to the hydrogen cooler. The candidate is expected to recognize that the generator hydrogen control',;;is malfunctioning and is expected to take MANUAL control of the controller. The candidate is expected to maintain the generator within the operating limits speciFed by the pressure vs. load curvts. Following actions to M ANUALLY control the Main Generator Temperature Controller and 112cooler temperatures are stabiliicd, the Letdown Back Pressure transmitter PT 201 fails low causing the back pressure regulating valves to close. The candidate is expected to recognize that a problem exists with the back presture controller and to take manual control of the controller. Operation in manual will be complicated by the fact that there is no indication of back pressure available. After Letdow n llack Pressure controller is placed in manual and pressure stabilized, the 11 Chargi,'g Pump couptmg breaks The candidate is expected to recognize that a charging system abnormality exists and start another pump. The candidate should diagnose charging pump problem and not charging line break. Candidate should verify l 1echnical Specification 3.1.2 4 for required OPERABLE charging pumps. Following determination is made that 'he 11 charging pump is not functioning properly and another charging pump is started,14 Circulating Water Pump trips. The candidate is expected to recognize that a Circulating Water Pump has tripped and should take immediate action to insure that Turbine limits are not being exceeded. If necessary, the turbine should be manually tripped based on the following limitations. If any of the following occur for longer than FIVE seconds:

Condenser vacuum < 25 inches lig AND Gross electricalload is < 270 MWE e

Maximum differential pressure between adjacent hoods is > 2.0 inches lig

Two stopped CIRC WATER Pumps are associated with the same Condenser Then with SS'CRS approval, the reactor should be tripped.

The timing for the next event are based on whether the reactor is tripped due to the Circ Water Pump trip. If the reactar is manually tripped, then the loss of power and SGIS trip and isolation occur immediately with the trip. If the reactor is NOT manually tripped, then the loss of pow er and SGIS trip and isolation occur approximately FIVE minutes following stabilization of unit load following the loss of the Circ Water Pump. Actions taken are the same. A loss of 4kV bus 11 occurs, and SGIS "A" actuates. This results in a Reactor trip. 'Itc candidate is expected to recognlie the loss of 4KV bus 11 and the spurious SGIS "A" actuation. The candidate should realize that with spurious SGIS, no S'O Differential Pressure will desclop (no faulted S!G). Entry into EOP 0 is mede and the loss of power to 4 KV bus 11 is addressed by actions of AOP 71. In addition, any attempts so manually initiate AFW Gow to the S'G's fail (AFAS will not actuate,12 AFW Pump will not start,13 AFW Pump not powered due to loss of 4 KV bus 11). This results in a total loss of feed water flow (Unit 2 cross-tic unavailable) and the candidate is expected to implement EOP-3. Scenario should end when once through cooling 5erified in EOP 3, Section J. SCENAR-4.RTF 3 10/14W 1:55 PM

_ _ _ _ _ . _ _ . . _ _ _ _ . . ~ . _ . 4 J l ' 'cenario No: l4 Event No. I Page L of .12 aent

Description:

'Irip of running i i Containment Spray (CS) Pump. This results in B0111 CS pumps being inoperable.

lime Position ' Applicant's Actions or llehavior CUL: Annunciator alarm ICl8 M 04 U l 4KV ESF MOlOR OVERLOAD IC0911251l CS PP DISCil PRESS lil Clears IC09112911 CS PP 'S!AS BLOCKED ' AUTO START 1l CS Pump indication 1 ilOP identify and report trip of II CS Pump l

SRO identify / acknowledge trip of CS pump i

Recognize NO CS pumps operable l l l IlOP Dispatch an operator to locally check 11 CS Pump breaker 152 1107 I SRO Recognire applicabihty of Icchnical Specifications: e 3.6.2.1 Containment Spray System MODES 1,2 3 with PZR pressure 21750 psia; ACTION for ONE

inoperable only a

e 3.0.3 Within ONE hour take action to place Unit in a MODE in which specification (3.6.2.1) does NOT apply AND be in at least 1100 STANDllY within next 6 hours... 5 NOTE: After plant management contacted, they preside direction to commence an immediate ,, shutdow n at 20%/hr. SRO Contact OMC to check breaker 152 Il07 and'or il CS pump, i i i a e J l l 1

               ,,,..mr..,             -,,%,       ,4~, ...,_.____._.-_.-,_..y__.._              _

m-.. ....., ., , , _ _ ,--w,.,-

                                                                                                                                              .             - .. ..__.._-_,,__.,- - +, ,-c.y   .----w.,   .- - . . - .,.

l [ Scenario No: 14 Event No. 2 Page l of .12 l

       ,         vent

Description:

Normal plant shutdown to llot Standby from 100% power. j lime Position Applio/.t's Actions or Behavior l CREW Review Prerequisites and Precautions associated with 40RMAL POWER OPliRAllON

SRO Direct load decrease per OP 3 Section 6.4: e Reviews guidelines for LRNis followed e RPS Delta T power is primary power indication i e Comparisons should be made periodically between the FOUR RPS channels and plant computer for secondary calorir.;etric e N1 power should be used for trending purposes only e Method of reducing reactor pow er e Adjust RCS Boron concentration OR e Insertion of control rods. i RO En;ure Pressurizer spray flow:

1) Energize PZR backup heater banks

2) Adjust PZR Pressure Controller setpoint to maintain 2250 psia

       ;                                    Reduce reactor power to maintain Tc within 2 'F of program-o insert control rods o Horation llOP         Decrease turbine generator load to maintain Tc within 2 'F of program e     (In LOAD LIMIT) Decrease the load by decreasing the load limit setpoint in small iricrements AND maintain LOAD SET no higher than 100MWe abos e actual load OR e     (in LOAD SET) Decrease load by momentarily depressing the LOAD SELECTOR DECREA' button AND maintain LOAD LIMIT no higher than 100MWe above actual load CREW         Ensure requirements of APPENDIX D are met e     if Tc deviates > 2'F from program Tc, notify CRS AND initiate corrective actions to restore e

d Reduce MSR 2 stage pressure in no more than 50 psig increments per Figure 2 (local) e Notify Chemistry to sample RCS if power is changed by > 15% in ONE hour

Scenario No; l4 Esent No. 2 Page 2 of .12 Lsent

Description:

Normal plant shutdown to ilot Standby from 1009'e power, i lime Position Applicant's Actions or Behavior l CREW (APPENDIX D Cont.) (cont.)

Do NOT exceed turbine limits e 150'F/hr rate of change of 1" stage shell inner metal temperature (Point 6 on TR 4404)
75'F I" stage shell metal temperature differential (Diff between Points 6 & 7 on TR 4404) e Unloading rate of 10% step change or $'Nmin 1

e Periodically compare all indications of power e if unexplained difference exist between NI, Delta T, or calorimetric power AND plant conditions do NOT reoui+ ixpeditious shutdown, stabilia reactor power until discrepancy is resolved e Periodically ZERO the Voltage Regulator Transfer meter e Maintain ASI within limits of COLR e Periodically verify PZR Program Level is within acceptable PZR level band per Figure (3) e Periodically monitor ASI to ensure oscillations will NOT teach the ASI pre trip value e At approximately 615 Mw e (70* 6 reactor power) open ill LVL DUMP valves on LP FW lleaters

   ?
                 !!OP      At approxirr.ately 575 MWe (65?. reactor power) e Ensure NO MORE than TWO Condensate Pumps and TWO Condensate Booster Pumps are running

d Ensure MSR 2 stage liigh Load MOVs are shut e 1 MS-4017 MOV e 1 MS-4018 MOV

__= _ _ _ = = V -

Event No. 3 Page of .11 l Scenarm No: 14 vent

Description:

Main Generator flydrogen Coohng is affected by a loss of Service Water flow due to fa; lure of temperature controller ITIC 1608 in AUTO. Manual control of ITIC 1608 is available, lime Position Applicant's Actions or Behavior CUL: Annunciator alarm IC02 V 03 GlMS lC02 V 0611 2PRESS

PURITY e TEMP IC02 B 21 GEN MON STATUS PANEL l

Rising temperature in flydrogen cooling system

1. TIC 1608 controller indicating CLOOSED demand with temperatures increasing DOP Identify and report rising temperatures for flydrogen Cooling in Main Generator identify and report failure of temperature controller (ITIC 1608)

SRO identify / acknowledge rising temperatures' failure of temperature controller DOP e Reduce load (if desired)

Monitor Cold Gas ternperatures (Channels 073 & 075)-
At 65'C OR within 15 minutes of operation above $1'C-e With concurrence of SS'CRS, trip the reactor SRO implement AOP 7E MAIN TURHINE MALFUNC110N Section XI Determine Section B is appropriate section for conditions llOP
Check proper SWR flow through Ilydrogen and Exciter Air Coolers e Hypass the appropriate temperature control valve (s) by directing local operator action-o 1 SWR 291 EXC AIR TCV IlYP
l SRW 285 II:TCV BYPASS VLV OR e As alternate action, Take controller 1 TIC 1680 to MANUAL and adjust SRW flow to reduce 11 2 temperatures
Verify SRW llX OUT TEMPS are normal e Monitor Cold Gas temperatures (Channels 073 & 073)-

e if $1'C temperature reached-e With concurrence of SS'CRS, reduce turbine load at a rate NOT to exceed the maximum allowable, until the alarm clears

Scenario No: 14 Event No. 3 Page ,of 11 Lvent

Description:

Main Generator flydrogen Cooling is affected by a loss of Sen1ce Water flow due to failure of temperature

 ;.                       controller ITIC.1608 in AUTO. Knual control of ITIC 1608 is available.

ime Position Applicant's Actions or Behavior t l iSOP (AOP.7L cont.) (cont.)

Monitor Cold Gas temperatures (Channels 073 & 07$).
At 6$'C OR within 15 minutes of operation above $1'C.
With concurrence of SS/CRS, trip the reactor l

l l SRO Contact OMC/l&C to investigate failure of temperature controller s

                                                                                    %                     zw

[ Scenario No: 14 Lvent No. 4 Page D ,of .12

   ~ sent

Description:

CVCS Letdown llack Pressure channel PI 201 fails low causing the backpressure regulating valve controller 1.PIC 201 to demand valve closure liigh pressure results in lifting ofletdown relief vahe 1 CVC 354.RV. 1tme Position Apphcant's Actions or lichavior CUL: Annunciator alarm IC07 l 02 L/D 1.CVC.354.RV OPLNLD IC07 F.09 L/D PRESS IC07 F 17110RON/ RAD MON FLOW LO Rising letdown pressure Lowcring letdown flow Letdown pressure controller demanding CLOSE when pressure is high RO identify and report rising pressure in CVC letdown hne and f ailure of I Plc 201 Itack Pressure Controller SRO Identify / acknowledge rising pressure in CVC letdown kncifailure of 1.PIC 201 llack Pressure Controller RO Perform actions of ALM:

Check Letdown flow control valves and back pressure regulators for proper operation l
Place 1 Plc.201 in MANUAL e Maintain letdown pressure = 460 psig e

Monitor RCS leaktate and tail pipe temperature of 1 CVC 345 to ensure relief valve has rescated I e Check low pressure L/D relief 1 CVC 354 RV has revated by alarm clearing,if valve opened SRO Contact OMC/l&C to investigate failure of letdown pressure controller

_ _ _ . . _ _ _ .m- _ _ . _ _ . _ . - _ _ _ _ _ . _ . _ _ _ . . _ . _ _ __ _ _.. _ _. _ . _ _ - ~ _ _ _ - [ Scenario No: 14 L$ent No. $ Page 2 of .12

               ' vent

Description:

ll Charging Pump coupling break with loss of charging flow

l Time position Applicant's Actions or Behavior CUL Annunciator alarm IC07 F-45 Clio liDR

FLOW LO
PRESS LO IC07 F 01 REGEN llX OUT TEMP 111 CVC Charging header flow ZERO CVC discharge header pressure low Pump RUN indication lit Pump amps at no load value !

RO Identify and report loss of charging flow and failure of Charging Pump SRO identify / acknowledge loss of charging flow / failure of running Charging Pump RO Perform action of ALM:

Start an alternate charging pump

RO e Verify normal charging flow restore e Select a backup charging pump l e Dispatch operator to locally check the 11 Charging Pump

Secure 11 Charging Pump motor and place control switch in PULL TO LOCK SRO Recognize applicability of Technical Specifications ACTIONS:

3.1.2.2 lloration Flowpaths operating requires charging pumps of following Tech Spec e 3,l.2.4 Charging Pumps operating TWO required Determines Specification is met without entering ACTION statement SRO Contact OMC to investigate failure of an to repair Ii Charging Pump (shaft)

l Scenario No: 14 Event No. 6 Page h of.H f

   ' 7ent

Description:

1he 14 Circulating Water Pump trips, lime Position Applicant's Actions or lichavior CUL: Annunciator alarin : Should get computer alarm for the 14 CW Pp trip Trip indication for 14 Circ Water pump Decreasing condenser vacuum (due to reduced power low vacuum may not be immediate) l llOP identify and report trip of 14 Circ water pump

SRO Identify /achnowledge trip of 14 Circ water pump BOP Perform actions of A M and 01 14 for trip of pump: e Dispatch operator to check breaker l$21601 e Maintain loading limits for loss of Circ Water Pump-e if any of the following occur for longer than FIVE seconds:

Condenser vacuum < 25 in,hes lig AND Gross electricalload is < 270 MWE e

Maximum differential pressure between adjacent hoods is > 2.0 inches flg

Two stopped CIRC WATER Pumps are associated with the same ConJenser e

j With permission of SS/CRS trip the reactor (turbine) and implement EOP-4 e Lower Turbine Load to obtain.

Temperature differential across the Condensers of < 12'F e Condenser vacuum > 25 inches lig NOTE: SRO may decide to average condenser delta T per 01 14 A based on availability of U2 CW Pps e Monitor condenser vacuum SRO If condenser vacuum is dropping, implement AOP 70 LOSS OF CONDENSER VACUUM llOr' (AOP lO cont.)

(cont.) e if condenser s acuum indication is < 20 inches lig-e Shut the MSlVs e Take I ilS-6622 to CLOSE to shut the UPSTREM DRh VLVs e Secree SG D'D by shutting-

BD-4010-CV 11 SO SURF e 1 BD-40ll CV 11 SG BOT e I BD-4012 CV 12 SG SURF e 1 BD-4013-CV 12 SG BOT

Scenario No: 14 L' <.nl No. 6 Page .JdL of .12 la ent

Description:

1he 14 Circulating Waier Pump trips. f lime Position Applicant's Actions or lichavior e Shift Oland Seal Steam per 01911 SRO contact OMC to investigate failure of Circ Water pumphreaker D m

l Scoarn No: 1-4 Event No. 7 Page 10-11.of 11

  ,      " vent

Description:

Loss of the i14 KV bus occurs. Followed 2 minutes lect by a rpurious SGIS A signal. lime Position Applicant's Actions or Behavier CUL Annunciator alarm ICG8 G09 ACTUATION SYS SGIS A TRIP SGIS A actions Normal SG pressures IC!9 R 03 U-l 4KV ESF FDR E a TRIP Bus 11 deenergized Buss 11 loads NOT operating CREW IC e.ify and report

Reactor trip
SGIS A actuation
Loss of power ori i14KV Bus SRO Upon react- Tip, direct implementation of EOP-0 POST TRIP IMMEDI ATE ACTONS RO Perform Post Trip immediate Actions:
Depress ONE set of Manual RX TRIP buttons
Checks reactor tripped-
Prompt drop in NI power
Negatis e SUR
Check ALL CEAs fully inserted Verify demin water makeup to RCS is secured
11 & 12 RCMU pumps secured VCT fi'U valve 1-CVC 512-CV is shut If RCS M/U is in DIRECT LINEUP, RWT CilG PP SUCT valve I-CVC-504-MOV is shut BOP
Caeck react n has tripped Ensure turbine has tripped-
Depress U l MAIN TURB TRIP button
Check Turbine Main Stop valves shut
Check turbine speed drops

Scenario No: 1-4 Event No. 7 Page _1011 of,12' Event

Description:

Loss of the iI 4 KV bus occurs Followed 2 minutes later by a spurious SGIS A signal. t lime Position Applicant's Actions or Behavior I llOP (LOP-0 cont.) (cont.) e Verify turbine generator output breakers open-e 11 GEN BUS BKR,0-CS 552 22 .- e 1I GEN TIE f1KR,0-CS 552 23 e Verify 11 GEN FIELD BKR l 2-CS-41 is open e Verify 1I GEN EXCITER FIELD IIKR l CS-41E is open BOP e Check 11 OR 14 4KV Vital Bus energized e Check ALL 125V DC BUS \!OLTS greater than 106 volts Check at least ONE set of 120V AC Vital Buses is energized g e e Check at least ONE 208/120V INSTR AC BUS is energized IF ANY RCPs are operating, TilEN verify component cooling flow to the RCPs. Dispatch an operator to verify Switchgear Room Vent, operating

                                  . Verify CC flow to RCPs CREW       e   Dispatch operator to check II 4KV bus RO         e Ensure PZR pressure stabilizes between 1850 psia and 2300 psi. AND is trending to 2250 psia e

Ensure PZR level stabilizes between 80 and 180 inches and is trending to 160 inches

  -a e  Ensure RCS subcooling GREATER Til AN 30'F
                     ;            NOTE: EOP-0 metions continue in Event 8.

9 g -- -

l Scenario No: 1- Event No. 8 Page 12-17 of J.2

   ' ' vent

Description:

With SGIS A actuated, II 4KV bus deenergized and a failure of AFAS and'or AFW pumps to run, a total loss of feedwater condition exists. lime Position Applicant's Actions or Behavior CUL AFW pumps do NOT start NOR run NOTE: If operator dispatched to 114KV bus, report is sotne smoke in area, no fire sisible, Scorch ] BOP marks at main feeder treaker and incoming wiring. Alllockouts tripped. e Verify turbine bypass vahes or ADVs operating to maintain-e SG pressures between 850 and 920 psia

Tcold between 525' and 535'F e

Check at least one SG asallable for controlled heat removal e SG level between -170 and + 130 inches e Main or Aux Feedwater operating to maintain level CREW Identify and report Main feed unavailable ( due to SGSI A) AND AFW not operating!available CREW e Attempt start of an AFW pump Determine AFW NOT available

POP e Check at least one RCP operating in loop with available SG e if any RCP operating, check Thot minus Tcold LESS THAN 10*F in loop with available SG CREW e Check Containment pressure less than 0.7 psig e Check Containment temperature less than 120'F e Check containment radiation monitor alarms CLEAR with NO unexplained trerds-Check RMS alarms CLEAR with NO unexplained trends-I RIC 5415 U l wide range noble gas 1-RI-1752 Condenser OfTgas I-RI-4014 Unit i SG Blowdown e 1-RI-5415 Unit 1 Main Vent Gaseous I

Scenario No: 1- Event No. 8 Page 12-17 of l.2 Event

Description:

With SGIS A actuated, II 4KV bus deenergized and a failure of AFAS and'or AFW pumps to run, a total

 ,                        loss of feedwater condition exists.

Ome Position Applicant's Actions or Behavior SRO e Determine Recovery Procedure per Diagnos'ic Flowchart-

YES for Vital Auxiliaries safety function e YES for at least ONE vital 4KV bus e

Consider EOP 8 (FRP)

NO for Core /RCS II:at Removal safety function e NO One SG with flow l e Consider EOP 3 (LOAF) e YES for Single Event Diagnosis?

SRO Transition to EOP 3 LOAF

i

                          'iOTE: Due to loss of 114KV bus, SRO candidate may dewrmine that EOP 8 Functional Recovery

Procedure may be the correct implementation action. The actions below are for EOP-3. These actions arc NOT distinctly different from the steps performed in EOP-8 on the Recovery actions are identified for the Succe:S Paths. These steps are summarized below in italicized font. SRO Implement EOP-8 FUNCTIONAL RECol'ERY PROCEDURE CREW e Perform RCP Trip Strategy i e Direct Chemistry to sample BOTH SGsfor activity e Direct Chemistry to place Hydrogen Afonitors in service CREW e Identify Success Pathfor all unsatisfiedsafetyfunctions (RESOURCE ASSESSAIENT TABLE)- o l' ital Auxiliaries - eaher l'A 1, l'A-2 or l'A 3 o Core and RCS Heat Removal HR 1 HR-2 or HR-3 implementation will eventually lead to HR-4 ONCE-THROUGH- COOLING sincefeed .s NOTavadable e Commence Recovery Actionsfor identifiedSuccess Paths SRO e Direct performance ofStatus ofSafety Functions CREll' l'A l e ifeither 4Kl' l' ital bus b NOTenergi:ed. then attempt to restorepower concurrentlyper OI-27C SRO Direct implementation of EOP-3 6 1 4 JL

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

, Scenario No. l- Event No. 8 Page 1217 of .11 Ivent

Description:

With SGIS A actuated,114KV bus deenergized and a failure of AFAS and'or AFW pumps to run, a total l 1 loss of feedwater condition exists. ' Time Position Applicant's Actions or Behavior CREW e Commence SAFETY FUNCTION STATUS CHECKS e Determine LOAF diagnosis correct 4 RO + Trip ALL RCPs i I BOP e Shut SG B'D valves

I BD-4010-CV e 1 BD-40ll CV e I BD-4012 CV e I BD-4013-CV 4

RO e Commence RCS boration-

Shut 1 CVC 512-CV VCT M/U a

4 e Open 1-CVC 514-MOV BA DIRECT M/U - 4 i e Open BAST GRAVITY FD - e 1 CVC 508 MOV e 1-CVC-509-MOV e Verify 141S 210 Mil MODE SEL SW is in MANUAL e Start ALL available BA pumps e Shut 1-CVC-501 MOV VCT OUT

Start ALL available charging pumps e Record time boration started e Record BAST levels-e 11 BAST
12 BAST

( , I 4

Scenario No: 1 Event No. 8 Page 1217 of.12 Event

Description:

With SGIS A actuated,114KV bus deenergized and a failure of AFAS and'or AFW pumps to run, a total g loss of feedwater condition exists. Isme Position Applicant's Actions or Behavior RO (EOP 3 cont.) (cont.)

Continue boration until ONE condition met-
Shutdown Margin requite,% nts met per NEOPs e BAST levellowered a total of 71 inches l

a Boration has been in progress For-e 35 minutes with TilREE darging pumos running e 53 minutes with TWO charging pumps running 105 minutes with ONE charging pump n aning

CREW e NOTE requirements for initiating Once-Through-Cooling e Both SG levels are < 350 inches OR I

Teold rises uncontrollably 5*F CREW Commence Natural Circ cooldown-Attempt to reset SGIS (will NOT reset due to SGIS A) e Block SIAS-e When PZR PRESS BLOCK _ PERMITTED alarm received, block the appropriate train SIAS e

Conduct a rapid cooldown to Teold < 465'F using TURB BYP valves or ADVs while maintaining-e Cooldown < 100*F in any ONE hour

Subcooling between 30' and 140*F based on CETs e

PZR level between 50 and 180 inches e Use aux spray to depressurize if subcooling exceeds 140*F

 ;                       e   Verify adequate RCS heat removal-At least ONE SG has wide range level > -350 inches

Scenario No; l- Lvent No. 8 Page 1217 of jl Event

Description:

With SGIS A actuated,1I 4KV bus deenergized and a failure of AFAS and'or AFW pumps to run, a total

   ,                        loss of feedwater condition exists.

I lime Position Applicant's Actions or Behavior

                                  . Tcold stable or lowering l

CREW e Verify 12 CST available-e Leve!> $ feet e I AFW 161 12 C.cT TO UNIT 1 AUX FEEDWATER PUMPS ISOL is open

Es*ablish AFW flowpath by opening SG AFW BLOCK valves
Attempt to establish feed from UNIT 2 AFW-e Shut Onit 2 Motor Train SG AFW BLOCK valves e 2 AFW-4522 CV e 2 AFW 4523 CV e 2 AFW-4532-CV e 2-AFW 4533-CV e Open 2-AFW 4550-CV U 2 TO U l XCONN NOTE: Vah e will NOT open.

5 CREW Check Condensate system available and determines it is available CREW ~ Initiate Once-Through-Cooling-e Shift 1-HIC Il0 L/D THROTTLEVLV Cantroller to MANUAL and shut e I CVC 110P CV e I-CVC Il0Q-CV e Start ALL available charging pumps

                            . Open HPSI MAIN and AUX HDR valves-a    t SI 616 MOV e    1-St-626 MOV e    I St 636-MOV e    I SI-646-MOV e    I SI 617-MOV e     I St 627 MOV e     1-St-637 MOV i                               e     1 SI-647-MOV i

1 1 l _a

                                                                                                                                                                       'l Scenario No: 1                           Event No.                                          8                                                   Page 12-17 of.12 Event

Description:

Wuh SGIS A actuated, iI 4KV bus deenergized and a failure of AFAS and'or AFW pumps to run, a totsi loss of fee <* water condition exists. ( lime Position Applicant's Actions or Behavior e Start available llPSI pumps CREW (EOP 3 cont.) (cont.) e Place ALL PZR llTR handswitches to OFF g

Open CAC EMERGENCY OUT valves
Start ALL available CACs in HIGH l

l e Op n BOTil PORVs-e When PZR PRESS BLOCK _ PERMITTED alarm received, block the appropriate train SI AS e Verify BOTil PORV BLOCK valves open-e 1 RC-401-MOV e 1 RC-405 MOV e Pull TWO liigh Pressurizer Pressure Trip Units out of RPS e Verify N .11 PORVs open When RCS pressure < 120 psia, verify initiation of Once-Through Cooling-e llPSI flow per ATTACllMENT(10) e CET temperatures constant or lowering _ l

l o f, . . . I IV : ) CCNPP LICENSED OPERATOR ? JOB PERFORMANCE MEASURE AOP-1B IN SYSTEM: Cor. trol Element Drive System TASK: 020600301 Recover A Misaligned CEA l PURPOSE: Evaluates an Opermor's Ability to Recover a CEA Misaligned Between 7.5 inches And 15 inches During Performance of AOP-1B I l JOB PERFORMANCE MEASURE CALVERT CLIFFS NUCLEAR POWER PLANT LICENSED OPERATOR TRAINING f PREPARED BY: DATE: REVIEWED BY: DATE: Operations Instructor - Nuc REVIEWED BY: DATE: SRO License Holder APPROVED BY: DATE: Ops Training Supervisor Rev.0 f;

Page 3 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP-1B-IN TASK: 020600301 - Recover A hiisaligned CEA PERFORMER'S NAME: APPLICABILITY: RO and SRO PREREQUISITES: l Completion of the kr.owledge requirement of the Initial License class training program for j the Control Element Drive System. EVALUATION LOCATION: PLANT SIMULATOR CONTROL ROOM EVALUATION METHOD: ACTUAL PERFORMANCE DEMONSTR.sTE PERFORMANCE ESTIMATED TIME ACTUAL TIME TIME CRITICAL TASK: TO COMPLETE JPM: TO COMPLETE JPM: 15 MINUTES MINUTES NO TASK LEVEL: , TRAIN TOOLS AND EQUIPMENT: None REFERENCE PROCEDURE (S): AOP-1B TASK STANDARDS: This JPM is complete when CEA 35 is returned to within i 4 inches ofremaining CEAs in its group.

      . .-. - .-.                 ..                   .-            - - - --.-~.- -.                               .-

Page 3 CCNPP LICENSED OPERATOR ,, JOB PERFORMANCE MEASURE AOP-1B-IN ^ TASK: 020600301 Recover A Misaligned CEA ~ DIRECTIONS TO EVALUATOR:

1. Read the " Directions ta Trainee" to the trainee.

2. Note the time that the task is started. As the task proceeds, indicate completion of each element using the Standard criteria and the lollowing notation:

                               "S" for satisfactory completion "U" for unsatisfactory completion "N" if not observed OR not verifiable Critical elements must be observed or the evaluation is invalid.

1

3. When the Terminating Cue is reached, tell the trainee that no further actions are necessary. Note the completion time.

j 4. Document any instances ofincorrect performance in the Notes area (required for critical steps).

5. Questions should be asked atler completion of the task.

6. Indicate whether the task was completed satisfactorily on the basis of correct performance of all critical elements and completion of the task within the Estimated Time to Complete for Time Critical tasks.

7. This JPM contains the steps, notes, cautions, and standards that are applicable to the initial conditions specified in this JPM. Steps that do not directly relate to this JPM, but appear in the procedure, are not listed here. It is the responsibility of the evaluator and/or observer to become familiar with the procedure prior to use of this JPM.

1 4 k I e -

++

Page 4 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP-1B-IN TASK: 020600301 Recover A Misaligned CEA DIRECTIONS TO TRAINEE: j

1. To complete the task successfully, you must perform each critical element correctly. You must inform the evaluator of the indications you are monitoring.

Where necessary, consider the evaluator to be the CRS.

2. Initial Conditions:

a. The Unit 1 is stabilized at 20 % power.

b. CEA 35 during movement became misaligned by 10 inches from the remaining CEAs in its Group,

c. Actions of AOP-1B have been completed through Section VI. A.

d. The cause of the misalignment has been determined and repaired.

e, The total time for misalignment is 10 minutes.

f. All applicable Tech Spec actions reviewed and required I

actions identified

3. Task Standard: This JPM is complete when CEA 35 is returned to within i 4 inches of remaining CEAs in its group.

4. Initiating Cue: The CRS has directed you to attempt to realign the CEA per AOP-IB, Section VI.B. Are there any qu.:stions? You may begin.

 .                                                                                                                                Page5 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP-1B-1N ELEMENT                                                                                     STANDARD

(* = CRITICAL STEP) TIME START NOTE: Operator may review prior steps of AOP 1 A. l - Identify AOP-1B, Section VI.B Same as element

1.

          -          IF The time the misalviment occurred can                                         Determines time is 10 minutes NOT be determined,                                                               since misalignment occurred AND THEN PROCEED to section V. ,GA                                                   transition is NOT required MISALIGNED BY 15 INCHES OR MORE, Step E, Page 31 [B0124]

l CUE: Reactor Power is stable with boration completed as necessary to maintain stable power during CEA recovery.

2. Realign the CEA within one hour by performing the following actions:

a. Adjust Regulating CEAs OR borate Determines CEA Regulating as necessary to maintain Reactor Group motion or boration NOT Power {B0124]. required.

I

b. Select the desired group. Selects and depresses GROUP l SELECTION - Regulating 5.
c. Select the desired CEA. Selects and depresses INDIVIDUAL CEA SELECTION

                                                                                                       - Regulating 5 "35".

d. Select the Manual Individual CEA Selects and depresses MANUAL control mode. INDIUVIDUAL - MI.

c. IF Ch'l is in effect, TIIEN override Determines CMI is in effect.

CMI as follows: CAUTION Reactor Power shall NOT be allowed to rise when the CEA is being realigned. Turbine load shall NOT be raised until the CEA is within its alignment requirements.

     .. v           u --                                                                                                                o

Page 6 CCNPP LICENSED OPERATOR JOB P' >u KMANCE MEASURE AOP-18-1N ELEMENT STANDARD (* = CRITICAL STEP)

f. IF realigning a Shutdown CEA, Determines NOT applicable.

THEN withdraw it using the " Pull and Wait" method (pull 10 seconds, wait 10 seconds).

g. IF realigning a Regulating CEA, Uses "Puli 10 seconds, Wait 15 THEN withdraw it using the " Pull seconds" method to realign CEA and Wait" method (pull 10 seconds, 35 to withini 4 steps of l wait 10 seconds).

' remaining CEAs in Regulating Group 5. TIME STOP TERMINATING CUE: This JPM is complete when CEA 35 is within 4 steps of remaining CE/,s in Regulating Group 5. No further actions are required, k e .- -

Page 7 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP-1B IN TASK: 02 % 00301 Recover A Misaligned CEA NOTES: ( The operator's wrformance was evaluated against the standards contained in this JPM - and determinec to be SATISFACTORY UNSATISFACTORY EVALUATOR'S SIGNATURE: . DATE: L-

                                                                         -                                                        a

Page 8 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP-1B-IN TASK: 020600301 Recover A Misaligned CEA SIMULATOR INSTRUCTIONS IC - 14% power

1. Have CEA 3510 inches lower than remaining CEAs in GROUP 5.

2. l A Diesel Generator is supplying power to 4 KV bus 11, and 4 KV bus 11 feeder breakers 152-1115 and 152-1101 are open.

3. Unit 1 is in Mode 1 between 19% and 25% power with Main Turbine paralleled,11 SGFP operating and 12 SGFP in standby, and Alarm window C-6 is m alarm.

1

Calvert Cliffs N:: clear P;wer Pl:nt JPM Questi:a (a)

 ,                                                                                 Title Recover A Misaligned CEA K/A 001000A113 [4,0/4.2)

Question a: Given the following information for Unit 2: Reactor Power Teold PZR Pressure Prior to CEA drop 40% 538.4 2250 psia g After CEA drop 37% 537.8 2250 psia llow does the CEA Group Insertion Limits change due to the dropped rod? Answer Prior to CEA drop, limit was Group 4 at 80%[ i3%) insertion (27.2 inches withdrawn); and Group 3 at 20% insertion (108.8 inches withdrawn). Following the CEA drop the limit increases to Group 4 at 86%[i3%) (20 inches withdrawn ); and Group 3 at 26% (100 inches withdrawn) Reference Use Allowed? YES Reference 1 Calvert Cliffs, Cycle 12 COLR Rev. O Figure 3.1.3 2, page 12 Reference 2 Comments: I I Satisfactory l IUnsatisfactory Candidate

   ; l                                                                            14 or 21 JPM #1 Question (a)

Misaligned CEA l Revised 10/17/9740 4 # 97

Calvert Cliffs Nuclear Pccer Plant JPM Questi:n (b) Title Recover A Misaligned CEA K/A 001000A212 [3.6/4.2] Question b: Given the following informatinn (see attached) fer an ECC, complete and evaluate the conditions and provide corrective actions, if applicable. Answer The Excess Reactivity value was incorrect (transpositional error) and did not use the Corrected HZP Inverse Boron Worth per NEOP 302 Section 6.2. A. This could result in the Criticality to occur below PDIL if the RCS is at the Critical Boron Concentation. The ECC will have to be recalculated with the correct values by Section 6.2. A. (note: Section 6.2.B can be used to verify the original calculation) Reference Use Allowed? YES Reference 1 NEOP-302 ESTIMATED CRITICAL CONDITION, Rev.1 Reference 2 Comments: l l l l l l Satisfactory l l Unsatisfactory Candidate l 23 of }} JPM #1 Question (b) Misaligned CEA l Revised 10/17/974WM47 U

Estimated Critical Cendition Units 1 & 2 NEOP-302/RQv.1 Page 20 of 25 Attachment 2A, ESTIMATED CRITICA1. CONDITION Estimated Critical Boron (ECB) Previous Critical Conditions 6.2.A.1.a Unit: 1 Cycle: /2 6.2.A.1.b Date: Time: 6.2.A.1.c Burnup: /3MC MWD /MTU '.', Estimated Critical Condition 6.2.A.2 Excess Reactivity: k.0 % ap # 6.2.A.3 Date: . Time: 6.2.A.4 Time After Shutdown: ') N hrs 6.2. A.5 Xenon Worth: 0 % ap 6.2.A.7 CEA Pogition (Inches) Grp 3: 7/ # Grp 4: O" Grp 5: O' CEA Worth: /. E % ap 6.2.A.8 ' Corrected HZP IBW: /07 opm/%ap g 6.2.A.9

   '              Critical Boron Worth: (6.2.A.2)-[(6.2.A.7)+(6.2.A.5)) = 25 %Ap 6.2.A.10                                                                                 -

Estimated Critical Boron Concentration: (6.2.A.9)*(6.2.A.6) = M ECC Tolerance Band 6.2.A.11 ECC Lower Bound: (6.2.A.7) + (0.5) = %Ap 6.2.A.12 ECC Lower Bound CEA Position (Inches): Grp 3: Grp 4: Grp 5: 6.2.A.14 ECC Upper Bound: (6.2.A.7)-(0.5) = , %Ap 6.2 4.15 ECC Upper bound CEA Position (inches): Grp 3: Grp 4: Grp 5: 6.2.A.17 Prepared by: Date/ Time: / Review and Approval 6.2.A.23 SRO Review: Date/ Time: /

                                                                                          ~
                # NOTE: Obtain a sequence number from the Attachment Log Sheet. Attachment 1.

UNIT 1 TECHNICAL DATA BOOK NEOP 13/REV. 3 PAGE 19 OF 60 FIGURE 1 ll.A.2 INVERSE BORON WORTH vs. BURNUP NO BORON 10 DEPLETION CORRECTION APPLIED Unit 1 Cycle 13 (Page 1 of 3)

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 .                                                              TECHNICAL DATA BOOK                                                                                    NEOP 13/REV,3
                                                                   ! !GURE 1 il.B.1                                                                                             PAGE 32 OF 60 HZP INTEGRAL CEA WORTH WITH OVERLAP 10,000 "*/utu to 16,500 ""/uTu RegW; ting Bank Worth = 3.622 %Ap Unit 1 Cycle 13 (Pa le 1 of 5) 1 O

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CALVERT CLIFFS NUCLEAR POWER PLANT TECHNICAL PROCEDURE Unit 1 and 2 ,;, NEOP-302 i. ESTIMATED CRITICAL CONDITION ) Revision 1 CONTINUOUS USE

i Effective Date: b/2[/97 Safety Related > Non-Safety Related I Writer: M. Todd Kibler

Sponsor: Penney File Approved N ?I Date . 2 97

                                                                                                            - - - - - - - - - - -- J

Estimated Critical Conditi::n Units 1 & 2 NEOP 302/Rev.1 Page 2 of 25 TABLE OF CONTENTS SECTION TITLE PAGE 1.0 PURPOSE............................................................. .4 2.0 APPLICABILITY / SCOPE.. .... .. ........... . ................................ . ...4

3.0 REFERENCES

AND DEFINITIONS. . . . . . . . . .. . . . . . . . . .. .....5

4.0 P R E R E Q UI SITE S . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . ... . . . . . . . . . ... .6 - 5.0 PRECAUTIONS . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ..........e 6.0 PERFORMANCE........ . . . . . . . . . . . . . . . . . . .. . . . .7 6.1 Plant Computer ECC Calculation . . . . . . . . . .. . . .7 6.2 Manual ECC Calculation . . .. . . ... .. . . . . .8 6.2.A Estimated Critical Boron (ECB). . . . , . . . . .8 6.2. B Estimated Critical Position (ECP).. . . . . . . . . . . .. .. . 10 6.3 ECC Adjustment. .. . . . .. . . . . . . . . . .. 13 7.0 POST PER?OP,MANCE ACTIVITIES ... . . . . . . . ...... . . . . . .18 8.0 B A S E S .. .. .... .. . ..... . ... .. . .... . ......... ..'.......... .. . . . . . . . .18 9.0 RECOR DS .... . . . . .. . . . .. . . . . . . . . . . . . 18 ATTACHMENTS Attachment 1, Attachment Log Sheet. . .. . . . . . . . . .... . . . 19 Attachment 2A, Estimated Critical Condition - Estimated Critical Boron (ECB)... . . .. 20 Attachment 28, Estimated Critical Condition - Estimated Critical Position (ECP)... .. . . 21 Attachment 3, Actual Critical Conditions. .. . . . . . . . . . . . . . . . . . . . . .. . .... 22 Attachment 4, Adjusted ECC Worksheet.. . .. . . . . . . .. . .23 Attachment 5, Page Verification.. . . . .. .. .. .. . . . . . . 24 Attachment 6, Feedback Sheet.. . .. . .. .. . . .... .25 O

Estimtted Critical Ccndition Units 1 & 2 NEOP-302/Rsv.1 Page 3 of 25 4 LIST OF EFFECTIVE PAGES Cumulative Changes to this Revision (including ECs) Page No. Rev. /Ch. l Page No. l Rev. /Ch. l Page No. l Rev. /Ch. 1 1/0 24 l 1/0 l l 2 1/0 25 l 1/0 l 3 1/0 l l l d. 4 1/0 l l l l 5 l 1/0 l l l l f 6 l 1/0 l l l l 7 l '1/0 l l l l 8 l 1/0 l l l l 9 l 1/0 l l l l 10 l 1/0 l l l l 11 l 1/0 l l l l i 12 l 1/0 l l l l 13 l 1/0 l l l l I 14 l 1/0 . l l l l 15 t l 1/0 l l *l l 16 l 1/0 l l l l 17 l 1/0 l l l l 18 l 1/0 l l l l 19 l 1/0 l l

l l 20 l 1/0 l l l 21 1/0 l l l 22 1/0 l l l 23 l 1/0 l l l d 9

Estimated Critical Condition Units 1 & 2 NEOP 302/Rev.1 Page 4 of 25 ( 1.0 PURPOSE The purpose of this procedure is to provide a means for determining estimated critical conditions (ECC) and associated reactivity tolerance bands for routine startups. This procedure is used to predict an estimated critical CEA position and a soluble boron concentration, based on reactor conditions prior to shutdown. 2.0 APPLICABILITY / SCOPE 2.1 This procedure is applicable for determining ECC's for Unit 1 and Unit 2. /.', 2.2 This pocedure is only applicable for ECC determinations not controlled by Post Startup Test Procedures or Approved Calculation Packages. An approved PSTP orj Calculation Package may be used in lieu of this procedure. i 2.3 This procedure may be used for determining the predicted critical CEA position referred to in Technical Specification Surveillance Requirement 4.1.1.1.1.c. 2.4 This procedure is not to be used to calculate an ECC if a CEA is immovable or untrippable. - 2.5 In all cases, the ECC's determined by this procedure should agree within 11.0 %Ap of actual critical conditions. This is consistent with Technical Specification 4.1.1.1.2. 2.6 This procedure is not to be used to fulfill the Surveillance Requirements of Technical 4 Specification 4.1.1.1.2. 2.7 Samarium reactivity"is accounted for implicitly within the methodologies of this procedure. 2.8 This procedure must be page checked at the time of initial telease and each time a change is entered in the procedure. Subsequent page checks are documented on Attachment 5. 2.9 This procedure is written by Nuclear Fuel Management for use by Operations. Any comments or suggestions concerning improvement of this procedure should be fonvarded to Nue:aar Fuel Management. Attachment 6, Feedback Sheet, has been provided to help document these comments. Comments or suggestions are not limited to the feedback sheets. 2.10 Multiple attachments generated during the use of this procedure shall be sequentially numbered and recorded on Attachment 1, Attachment Log Sheet. A separate Attachment 1 may be generated for each attachment. 2.11 Section 6.2.A provides direction for determining Estimated Critical Baron (ECB) concentration fr6m a given CFA position. Section 6.2.8 provides direction for determining Estimated Critical Position (ECP) of CEAs from a given RCS boron concentration. 9

Estimated Critical Conditicn Units 1 & 2 NEOP-302/Rev.1 0 Page 5 of 25 (

3.0 REFERENCES

AN1 DEFINITIONS 3.1 Developmental

References:

A. Calvert Cliffs Nuclear Power Plant Unit 1 Technical Specifications, Appendix A to License No. DPR 53. B. Calvert Cliffs Nuclear Power Plant Unit 2 Technical Specifications, Appendix A to License No. OPR-69. C. OI 50A, Revision 0, Plant Computer - D. PR 1-101, Revision 11, Preparation and Control of Calvert Cliffs Teghr)lcal Procedures. E. EN-1-310, Revision 1, Requirements For Use of Nuclear Engineering Procedures 3.2 Performance

References:

A. NEOP-13, Technical Data Book (U-1). B. NEOP 23, Technical Data Book (U 2). C. OP-2, Plant Startup From Hot Standby To Minimum Load. D. OI-50A, Plarlt Computer l 3.3 Definitions: - 1 A. Actual Critical Conditions (ACC) - the actual CEA position, soluble boron concentration and xenon concentration where criticality occurs (power stabilized at 10" % power) during a reactor startup. B. Estimated Critical Conditions (ECC)- the combination of CEA position, soluble boron concentration, fission product poison concentration, and time in cycle considerations that together establish an estimated condition of core reactivity wherein criticality should occur for a specified date and time. C. Excess Reactivity - the total " extra" reactivity available in a reactor core, at any point in cycle life, greater than what is actually required to maintain a critical core. D. ECC Tolerance Band - margin on either side of the ECC within which the ACC should occur. Normally10.5 %Ap. O 1 j

I l Estimated Critical C:nditisn Units 1 & 2 NEOP 302/Rev.1 Page 6 of 25

   ,    4.0    PREREQUISITES 4.1   Personnel Skill Levels Required A.        This procedure can be performed by Reactor Engineers, licensed Reactor Operators, or tralnees under the supervision of a licensed Reactor Operator.

B. It is the responsibility of the Shift SRO to revleiv and approve the ECC. C. It is the Reactor Engineer's responsibility to calculate the difference betweerbhe ACC and the ECC. - D. It is the Reactor Engineer's responsibility to provide the operator with the latest reactivity data available. [B 8) E. It is the responsibility of the Operator to use the latest reactivity data available, as contained in the appropriate Technical Data Book (NEOP-13 for Unit 1; NEOP-23 for Unit 2). ., F. It is the responsibliity of the Reactor Engineer to ensure that the Shift Supervisor and the Senior Control Room Operators are in agreement with the Reactor Engineer before any actions are taken by the Reactor Engineer to resolve questions encountered with the ECC during startup. 4.2 INITIAL CONDITIONS A. This procedu,re has been page checked. Date/ time / initial: / /* 5.0 PRECAUTIONS 5.1 Tiiis procedure provides a means to estimate the combined core conditions where criticality will occur. The ACC of the reactor should be bound by the ECC Tolerance Band. 5.2 Criticality shall be anticipated whenever CEAs are being withdrawn or boron concentration is being reduced in the Reactor Coolant System. 5.3 The CEA position equivalent to the Lower Bound of the ECC Tolerance Band shall be verified to be above or equal to the CEA position equivalent to the Zero Power Dependent Insertion Limits (PDIL). 5.4 The CEA position equivalent to the Upper Bound of the ECC Tolerance Band shall be verified to less than or equal to 135 inches withdrawn on Reg Group 5. 5.5 The actual time of criticality MUST be within four hours of the estimated time,(TS 4.1.1.1.1.c). IF the actual time of criticality WILL NOT be within 4 hours of the estimated time, another ECC MUST be calculated with a more accurate time. IF the actual time of criticality will be within 84 hours of the previous shutdown, the actual time of criticality MUST be within 2 hours of the estimated time. IF the actual time of criticality WILL NOT be w! thin 2 hours of the estimated time for this situation, another ECC MUST be calculated with a more accurate time.

l

Estimated Critical Conditi:n Units 1 & 2 NEOP 302/Rev.1 Page 7 of 25 6.0 PERFORMANCE t 6.1 PLANT COMPUTER ECC CALCULATION

f~ CAUTION: The actual time of criticality MUST be within inur hours of the estimated time (TS 4.1.1.1.1.c). IF the actual time of criticality WILL NOT be within 4 hours of the estimated time, ancther ECC MUST be calculated with a more accurate time. IF the actual tims of criticality will be within 64 hours of the previous shutdown, the actual time of criticality MUST be within 2 houts of the ntir/Med time. IF the actua: time of criticality WILL NOT be within 2 hours of the estimate d# l gme for this si'.uati pn. another ECC MUST be calculated with a more accurate time. ' A. i. SEl.ECT the CORE PHYSICS option from the MAIN MENU. B. SELECT the XENON option from the CORE PHYS lCS MENU. C. SELECT the Estimated Crit! cal Condition option from the XENCa MAIN MENU D. SELECT tiie ECC SINGLE CALCULATION from the ECC MENU. l 3.OTE: } ignore the following message ' WARNING: XENON INPUT POINT PAPCNTPW HAS A NON GOOD QUALITT. If any other warning messages appear on the screen contact P5iWG for 4 9;,sistance. E. ENTER the following data onto the ECC calc 0lation screen. NOTE:

Use the TAB key to move through each field.

NFM will dete'rmine the current Boron 10 concentration in atom percent. i

Estimated time of Start Up Estimated date of Start Up Boron 10 concentration (atom %)

Desired CEA position of Boren Concentration at time of startup F. PRESS the XMIT key. HOTE: The report will be printed on the incore printer in the DAS Room. -- G. VERIFY that the report reflects the data entered. H. IF the Lower CEA Bound is LESS than the Zero Power Dependent Inr.ertion Limit, THEN PERFORM step 6.1.E 6.1.G again with the CEA critical posi::on further out of the core, e u,

Estimated Critical Candition Units 1 & 2 NiiOP 302/Rev.1 Page 8 of 25 t 6.1 Plant Computer ECC (Continued) 1. IF the Upper CEA Bound is GREATER than 135 inches withwawn on Reg t **oup 5, THEN PERFORM step 6.1.E 6.1.H again with the CEA critical position inserted further into the core. J. REVIEW the ECC for acceptability. K. IF the ECC is acceptable, THEN 31GN the ECC form AND SUBMIT the ECC to a Shift SRO for review and approval. /.', . L. VERIFY that the ECC Upper and Lower CEA Pnunds are between 135 inch-;s withdrawn on Reg Group 5 and zero power PDiL, AND that the ECC date and time are within the allowable range. f M. IF an error is found, THEN INSTRUCT the preparer to make the necessary corrections, AND REPEAT the review. N. IF the ECC is acceptable, THEN the reviewing Shiit SRO shall SIGN the print-out and issue it an Attachment 2 sequence number from Attachment 1 , Attachment Log Sheet. i O. CONTINUE the startup PER OP 2. 6.2 MANUAL ECC CALCULATION

                                                            ,          NOTd:

If a procedure step requires an entry on an attachment the entry blank will have the same number asje,, procedure step. A. Es!' mated Critical Boron (ECB)

1. COMPLETE the previous critical conditions section of Attachment 2A.

a. RECORD he unit and cycle numbers.

b, RECORD the date and time the unit shut down.

c. RECORD the current burnup for the cycle from the plant computer point "CEBURNUP".

2. RECORD the excess reactivity from Figure 1 il.A.7 of NEOP-13 (Figure 2-II.A.7 of NEOP 23) on Attachment 2A,

                                 .,                                  CAUTION:

The actual time cf criticality MUST be within four hours of the estimated time (T3 4.1.1.1.1.c). IF the actual time of criticality WILL NOT be within 4 hcurs of the estimated time, another ECC I MUST be calculated with ? n. ore accurate time. IF the actual time of criticality will be within 84 hours of the prev.0us shutdown, the actual time of criticality MUST be within 2 hours of the estimated time. IF the actual time of criticality WILL NOT be within 2 hours of the estimated time for this sitoation, another ECC MUST be calculated with a more, accurate time. _

3. RECORD the' estimated date and time of reactor criticality for the ECC. on ATTACHMENT 2A.

Estimated Critical Conditier. Units 14 2 NEOP 302/Rev.1 Page 9 of 25 6.2.A Estimated Critical Boron (ECB)(Continued) ;

4. RECORD the elapsed time from reactor shutdown to the estimated time of criticality on Attachment 2A.

a. IF the elapsed time is greater than 84 hours THEN USE "> 84" hoers for 6.2.A.4.

5. DETERMINE the post shutdown xenon worth.

a. $.

IF the elapsed time is less than 84 hours, THEN DETERMINE the post -

shutdown xenon worth at the estimated time of criticality using the plant computer OR the XENON RHO Report, AND RECORD on g, #

Atta,chment

b. IF the elapsed time is greater than 84 hours, THEN RECORD the post shutdown xenon worth as zero (9) on Attachment 2A.

6. PLACE the hard copy XENCN RHO Report with Attachment 2A, if used.

7. RECORD the desired CEA criticality position and the associated CEA reactivity inserted using Figure 1 II.B.1 of NEOP 13 (Figure 211.B.1 of NEOP 23) on Attachment 2A.

8. RECORD ine Corrected HZP IBW from the XENON RHO Report on Attachment M.

OR , CALCULATE AND RECORD on Attachment 2A the Corrected HZP IBW using , Figure 1 II.A.2 of NEOP 13 (Figure 2 II.A.2 of NEOP 23) and the formula: Corrected HZP IEW = (HZP IBW)/810 Correction Factor.

9. CALCULATE the Critical Boron Worth by using the formula below AND RECORD on Attachment 2A.

Excess Reactivity - (CEA Worth + Xenon Worth) = Critical Boron Wortin

10. MULTIPLY the C,ritical Boron Worth by the Corrected HZP IBW, AND RECORD on Attachment 2A. This is the Estirnated Critical Boron Concentration.

11. ADD the ECC Tolerance (0.5 %p) to the estimated CEA Worth from step 6.2.A.7 AND RECORD on Attachment 2A. This result will be used to determine the ECC Lower CEA Bound.

12. DETERi.*:NE the ECC Lower CEA Bound by finding the CEA position from Figure 1 11.B.1 of NEOP 13 (Figure 211.B.1 of NEOP 23) associated with the react!vity worth found in tep 6.2.A.11 AND RECORD on Attachment 2A.

                                                                                              .-ym,           - - - - -.-       --
                                                                                                                                        -,,y

'T Estimated Critical Ccnditisn Units 1 & 2 NEOP 302/Rev.1

  ,                                                                                                                                               Page 10 of 25

( 6.2.A Estimated Critical Boron (ECB)(Continued)

13. lF the Lower CEA Buund is LESS than the Zero Power Dependt. it insertion Limit. THEN PERFORM step 6.2.A again with the CEA critical position further out of the core.

14. FUBTRACT the ECC Tolerance (0.5 %Ap) from the estimatt ' ~~ ^ Worth from step 6.2.A.7 AND RECORD on Attachment 2A. This result vvC 4 sed to determine the ECC Upper CEA Bound. ,

15. (. ! DETERMINE the ECC Upper CEA Bound by finding the CEA position from - Figure 1 II.B.1 of NEOP 13 (Figure 2 II.B.1 of NEOP 23), associated with tho reactivity worth found in step 6.2.A.14 AND RECORD on Attachmer}( 2A.

                                                 '6      lF the Upper CEA Bound is GREATER than 135 inches withdrawn on Meg Group 5. THEN PERFORM step 6.2.A again with the CEA critical position inserted further into the core,

17. SIGN the ECC form AND SUBMIT the ECC to a Shift SRO for review and approval. .: 18. VERIFY that the previous critical condition is co:.tet. (B 8]; 19. . VERIFY that the ECC date and time are wt.nin the allowable range.
20. VERIFY that the ECC was calculated correctly.: 21. VERIFY that'the ECC Upper and Lower CEA Bounds were calculated correctly and are between 135 inches withdrawn on R6g Group 5 and zero power PDIL.; 22. IF art error is found, THEN INSTRUCT the preparer to make the necessary corrections, AND REPEAT the revle.v.; 23. IF the cair dation is acceptable, THEN the reviewing Shift SRO shall SIGN the attachment.; 24. CONTINUE the startup PER OP 2.

NOTE:- If a procedure step requires an entry on an attachment the entry blank will have the same numb _er as the procedure step.- B. Estimated Critical Position (ECP)

1. COMPLETE the previous critical conditions section of Attachment 2B.

a. RECORD the unit and cycle numbers,

b. RECORD the date and time the unit shut down.

c. HECORD the current burnup for the cycle from the plant computer point

                                                                 C E BU RNUP".

4 4 w-sqw-- ww .-,.,77- m m. ---p .m 4- .,.

                                                                                                           ---m-+w , ~ -- ,      .y.e

Estimat:d Critical Condition Units 1 & 2 NEOP 302/Rev.1 Page 11 of 25 t 6.2.B Estimated Critical Position (ECP)(Continued)

2. RECORD the excess reactivity from Figure 1 II.A.7 of NEOP 13 (Figure P.-II.A.7

of NEOP 23) on ATTACHMENT 28.

CAUTION: The actual time of criticality MUST be within four hours of the estimated time (TS 4.1.1.1.1.c). IF the actual time of criticality WILL NOT be within 4 hours of the estimated time, another E,CC MllST be calculated with a /nore accurate time.~ IF the actual time of criticality will be withlh44

'                         hours of the previous shutdown, the actual time of criticality MUST be within 2 hours of the . '

estimated time. IF the actual time of criticality WILL NOT be within 2 hours of the estimated time for this situation, another ECC MUST be calculated with a more accurate time./ I l 3. RECORD the estimated date and time of reactor criticality for the ECC, on ATTACHV.ENT 28.

4. RECORD the elapsed time from reactor shutdown to the estimated tima of
criticality on Attachment 28.: a. IF the elapsed time is greater than 84 hours THEN USE "> 84" hours for 6.2.B.4.; 5. DETEPMINE the post shutdown xenon worth.

 '        E

a. IF the elapsed time is less than 84 hours, THEN DETERMINE the post shutdown xenon worth at the estimated time of criticality using the plant

, computer OR the XENON RHO Report, AhD RECORD on Attachment 28.

b. IF the elapsed time is greater than 84 hours, THEN RECORD the post shutdown xenon worth as zero (0) on Attachment 28.

                             , 6.            PLACE the hard copy XENON RHO Report with Attachment 28, if used.

, 7. RECORD the desired Critical Boron Concentration tsn Attachment 28. l 8. RECORD the Corrected HZP IBW trom the XENON RHO Report on Attachment 28, OR i CALCULATE AND RECORD on Attachment 2B the Corrected HZP IBW using Figure 1 ll.A.2 of NEOP-13 (Figure 2 II.A.2 of NEOP-23) and the formula: Corrected HZP IBW = (HZP IBW)/810 Correction Factor. -

9. CALCULATE the Critical Boron Worth by using the formula below AND RECORD on Attachment 28.

( ,. Critical Boron Concentrrition/ Corrected HZP IBW = Critical Boron Worth

Estimated Critical Condition Units 1 & 2 NEOP 302/ Rov.1 Page 12 of 25 6.2.B Estimated Critical Position (ECP)(Continued)

10. CALCULATE the Critical CEA Worth by using the formula below AND RECORD on Attachment 2B.

Excess Reactivity - (Critical Boron Worth + Xenon Worth) = Critical CEA Worth 11. DETERMINE the Critical CEA Position associated with the Critical CEA Worth using Figure 111.B.1 of NEOP 13 (Figure 211.8.1 of NEOP 23) AND RECORD on Attachment 2B. '.

12. ADD the ECC Tolerance (0.5 %Ap) to the Critical CEA Worth from step 6.2.B.10 AND RECORD on Attachment 28. This result will be used to deterniine the ECC Lower CEA Bound.

13. DETERMINE the ECC Lowcr CEA Bound by finding the CEA position from Figure 1 il.B.1 of NEOP 13 (Figure 2 II.B.1 of NEOP 23) associated with the reactivity worth found in step 6.2.B.12 AND RECORD on Attachment 28,

14. IF the Lower CEA Bound is LESS than the Zero Power Dependent insertion Limit, THEN PERFORM step 6.2.8 again with a higher Critical Boron Concentration.

15. . SUBTRACT the ECC Tolerance (0.5 %Ap) from the Critical CEA Worth from step 6.2.B.10 AND RECORD on Attachment 28. This result will be used to determine the ECC Upper CEA Bound.

16. DETERMINE'the ECC Upper CEA Bound by finding the CEA position from Figure 1 11.B.1 of NEOP-13 (Figure 2 II.B.1 of NEOP 23), associated with the reactivity worth found in step 6.2.8.15 AND RECORD on Attachment 28.

17. IF the Upper CEA Bound is GREATER than 135 inches withdrawn on Reg Group 5, THEN PERFORM step 6.2.8 again with a lower Critical Boron Concentration.

                                ~ 18.      SIGN the ECC form AND SUBMIT the ECC to a Shift SRO for review and approval.

19. VERIFY that the previous critics! condition is correct. (B 8)

20. VERIFY that the ECC date and time are within the allowable range.

I 21. VERIFY that the ECC was calcu'ated correctly. l 22. VERIFY that the ECC Upper and Lower CEA Bounds were calcula'ed correctly and are between 135 inches withd. awn on Reg Group 5 and zero power PDIL.

23. lF an error is found, THEN INSTRUCT the preparer to make the necessary corrections, AND REPEAT the review.

24. IF the calculation is acceptable, THEN the reviewing Shift SRO shall SIGN the 4 attachment. '

l .

Estimated Critical Ccnditlen Units 1 & 2 NEOP 302/Rev.1 Page 13 of 2E 6.2.B Estimated Critical Position (ECP)(Continued)

25. CONTINUE the startup PER OP.2.

6.3 ECC ADJUSTMENT NOTE: The Reactor Engineer and Shift Supervisor _ will decide which parameter of the ECC will be modified, and will adjust the ECC. ' ' - A. IF it appears the ACC will fall outside the ECC Tolerance Band, CONTACT the Reactor Engineering Work Group for guidance. t .. B. The Reactor Engineer may DETERMINE if criticality outside the ECC Tolerance Band (as initially calculated)is in fact acceptable, if one of the following conditions exists:

1. IF an error exists in the ECC calculation OR the supporting documentation contained in NEOP-13 (NEOP 23), THEN:

a. COPRECT the error,

b. DETERMINE a corrected ECC and ECC tolerance band

    ,                                      c.                        CONTINUE STARTUP with the corrected ECC and tolerance j                                                                band.

2. IF an erroneous or non stable boron chemistry sample was used to perform the ECC, THEN:

a. CALCULATE a new LOC using a corrected sample,

b. CONTINUE startup with the corrected ECC and tolerance band.

          , C.        IF none of the errors described previously exist, OR IF the ACC still appears to fall outside the ECC Tolerance Band after any errors were corrected. THEN the Reactor Engineer SHALL CALCULATE a new ECC on Attachment 4, MODIFYING the ECC in the direction of the anticipated critical condition.

1. RECORD the unit and cycle number.

I

2. IF it is decided to modify the ECC by changing boron concentration, THEN ADJUST a= follows:

a. RECORD the Corrected HZP IBW from the appropriate source listed below.

Corrected HZP IBW shall be obtained from Attachment 2A or Attachment 28 if the Manual ECC Calculation was used. - 8 Corrected HZP IBW shall be obtained from the XENON RHO Report provided by Reactdr Engineering if the Plant Computer ECC Calculation was used. l

Estimated Critical Cendition Units 1 & 2 NEOP 302/Rev.1

Page 14 of 2S

    ;   6.3.C.2                      F.CC Adjustment (Continued)
                                                                                                                             ,        i 1

b. RECORD the previous calculated critical boron worth from Attar.hment 2A, Attachment 28 OR the pl:nt computer printout.

, c. ECC Adjustment (1) IF the ACC appears to be BELOW the previous lower tolerance bound, THEN ADD 0.5 %Ap to the previous critical boron worth AND RECORD on Attachment 4. i.his is the adjusted critical boron worth. - (2) IF the ACC appears to be ABOVE the previou upper tolerance band, THEN SUBTRACT 0.5 %Ap f.oni the previous critical boron worth AND RECORD on Attachment 4. This is the adjusted critical boron worth, t 4

d. MULTIPLY the adjusted critical boron worth found in step 6.3.C.2.c by the HZP IBW(6.3.C.2.a) AND RECORD on Attachmant 4. This is the adjusted ECC Boron Concentration.

e. RECORD the ECC Tolerance Bounds from Attachment 2A, Attachment 28 OR the plant computer printout.

f. GO TO Step 6.3.C.S.

4 1 3. IF it is decided to modify the ECC by changing the CEA position, THEN ADJUST as follows:

a. RECORD the CEA Worth from Attachment 2A, Attachment 28 OR i the plant compute printout,

b. ECC Adjustment (1) IF the ACC appears to be BELOW the previous lower tolerance bound, THEN ADD 0.5 %Ap to the previous CEA worth AND RECORD on Attachment 4. This is the adjusted CEA worth.

(2) IF the ACC appears to be ABOVE the previous upper tolerance band, THEN SUBTRACT 0.S %Ap from the previous CEA worth AND RECORD on Attachment 4. This is the adjusted CEA worth.

c. ADD the ECC Tolerance (0.5 %Ap) to the adjusted CEA Worth (6.3.C.3.b) AND RECORD on Attachment 4. This result will be used to determine the ECC Lower CEA Bound. ,

d, DETERMINE the ECC Lower CEA Bound by finding the CEA position in Figure 1 il.B.1 of NEOP-13 (Figure 2 II.B.1 of NEOP-23), associated wi'.1 the reactivity worth found in step 6.3.C.3.c

   ,                                               AND RECORD on Attachmer't 4.

e. IF the Lower CEA Bound is LESS than the Zero Power Dependent insertion Limit, THEN PERFORM step 6.3.0.3 again using a reactivity value smaller than 0.5 %Ap.

i Estimat9d Critical Ccnditlen Units 1 & 2 NEOP 302/Rev.1 Page 15 of 25 l 6.3.C.3 ECC Adjustrrent(Continued) f. SUCTRACT the ECC Tolerance (0.5 %op) from the adjusted CEA Worth (from 6.3 C.3.b) AND RECOhD on Attachment 4. This result will be used to deterrnine the ECC Upper CEA Bound.

g. DETERMINE the ECC Upper CEA Bound by finding the CEA position in Figure 1 11.B.1 of NEOP 13 (Figure 2 II.B.1 of NEOP.

23), associated with the reactivity worth found in step 6.3.C.3.f AND HECORD on Attachment 4. '.,

h. IF the Upper CEA Bcund is GREATER than 135 inches withdrawn

! on Reg Group 5, THEN PERFORM step 6,3.C.3 agair) using a reactivity value smaller then 0.5 %Ap. L GO TO Step 6.3.C.5.

4. IF it is decided to modify the ECC by changing the boron concentration AND the CEA position, THEN ADJUST as follows:

a. DETERMINE tne desired CEA position, AND RECORD on Attachment 4. This is the adjusted ECC CEA position.

               .                               b.        DETERMINE the adjusted ECC CEA worth by finding the reactivity worth in Figure 1-11.B.1 of NEOP 13 (Figure 2 II.B.1 of
     ;                                                   NEOP 23), associated with the CEA position found in step I

6.3.C 4.a AND RECORD on Attachment 4.

c. RECORD the previous ECC CEA worth from Attachmont 2A, Attachment 2B OR the plant computer printout. 1

d. SUBTRACT the adjusted ECC CEA worth from the previous ECC CEA worth, AND RECORD the result (include positive or negative sign) on Attachment 4. This is the total change in CEA worth.

e. RECORD the previous ECC boron worth from Attachment 2A, Attachment 2B OR the plant computer printout.

f. ECC Adju.tment (1) IF tht A0C appears to be BELOW the previous lower tolerance bound, THEN ADD 0.5 % to the previous ECC boron worth AND RECORD on Attachment 4.

(2) IF the ACC appears to be ABOVE the previous upper tolerance band, THEN SUBTRACT 0.5 %6p from the previous ECC boron worth AND RECORD on Attachment 4.

g. ADD the total char;ge in CEA worth to the ECC Adjustment AND RECORD on Attachment 4.-This is the adjusted boron worth.

l

                                                              'dstimated Critical Conditlan              Units 1 & 2 NEOP 302/l<ev.1 Page 16 of I'S i  6.3.C.4   ECC Adjustment (Continued) i h.

RECORD the HZP IBW from the appropriate source listed below. HZP IBW shall be obtained from Attachtnent 2A or Attachment 28 if the Manual ECC Calculation wal used. HZP IBW shall be obtained from the XENON RHO Report provided by Reactor Engineering if the Plant Cornputer ECC Calculation was used. I. MULTIPLY the adjusted boron worth found in step 6.3.C.4.g, by ' ( . i the HZP IBW (6.3.C 4.h) AND RECORD on Attachment 4. This is ' the adjusted ECC Boron Concentration, f ., J. ADD the ECC Tolerance (0.5 %Ap) to the adjusted CEA Worth (from 6.3.C.4.b) AND RECORD on Attachment 4. This result will be used to determine the ECC Lower CEA Bound.

k. DETERMINE the ECC Lower CEA Bound by finding the CEA position in Figure 1 II.B.1 of NEOP 13 (Figure 2 II.B.1 of NEOP-23), essociated with the reactivity worth found in step 6.3.C.4.]

AND RECORD on Attachment 4. l. IF the lower CEA Bound is LESS than the Zero Power PDil, THEN PERFORM step 6.3.C.4 again with the CEA critical position

    ,                                                    further out of the core.

m. SUBTRACT the ECC Tolerance (0.5 %Ap) from tne adjusted CEA Worth (from 6.3.C.4.b) AND RECORD on Attachment 4. This result will be used to determine the ECC Upper CEA Bound.

n. DETERMINE the ECC Upper CEA Bound by finding the CEA position in Figure 111.B.1 of NEOP 13 (Figure 2 II.B.1 of NEOP-23), associated with the reactivity worth found in step 6.3.C.4.m

AND RECORD on Attachment 4.

o. IF the Upper CEA Bound is GREATER than 135 inches withdrawn on Reg Group 5, THEN PERFORM step 6.3.C.4 again with the CEA critical position inserted further into the core.

5. MARK steps not used on Attachment 4 with "NOT APPLICABLE" or "N/A".

6. SIGN the Adjusted ECC form (Attachment 4) AND SUBMIT the Adjusted ECC to a Shift SRO for review and approval.

t

h Estimated Critical Condition Units 1 & 2 NEOP 302/Rev.1 Page 17 of 25 g 6.3.C ECC Adjustment (Continued) l i 7. 1 AdjusteC ECC Review and Approval: NOTE: A Shift SRO shall perform all reviews and make approvals. -It is the responsibility of the SRO to check and verify that theJdjusted ECC calculation is correct. '

a. VERIFY that the ECC Upper and Lower CEA Bounds were /

calculated correctly and are between 135 inches withdrawn on' ~ Reg Group 5 and Zero Power PDlk

b. IF errors are found, THEN INSTRUCT the preparer to'make the neces sary corrections AND REPEAT the review, c.

IF the Adjusted. JCC is acceptable, THEN the reviewing Shift SRO shall APPROVE the ECC form AND SIGN it.

d. IF it appears that the ACC will remain outside the tolerance band after performing step 6.3.C, THEN:

(1) PLACE the reactor in MODE 3 OR higher numbered mode until the problem is resolved. (2) AFTER the POSRC reviews and Plant General Manager i (PGM) concurs with Reactor Engineering (NFM) recommendations, RESUME the ap9 roach to critical.

8. CONTINUE the startup PER OP 2.

e 4 _= == == - O s->

Estlmsted Critical Condition Units 1 & 2 NEOP-302/Rev.1 Page 18 of 25

     ,                        7.0       POST PERFORMANCE ACTIVITIES 7.1 Following Criticality and after power is stable at 10" %, RECORD the following actual critical conditions on Attachment 3.

'l NOTE: Do not begin the power ascension until all the following information has been recorded, in the case of the boron sample, confirmation that the sample has been taken is sufficient.

Unit and Cycle numbers at the top of the attachment #*
Date, Time of stabilized reactor critical conditions ,

Power at stabilized conditions

T.y of primary coolant across the reactor core /,

Boron Chem'stry grab sample direct Chemistry to perform a sample of the primary coolant immediately AFTER reaching stabilized conditions.

Boron sample time
Boronometer reading
CEA positions 7.2 PLACE the Shift SRO approved ECC form, the adjusted ECC form if used, the Xenon Rho Calculator report if used, and the Attachment 3 at the back of NEOP 302.

, , NOTE: ReactMty Difference shall be calculated by NFM following criticality. I 7.3 CALCULATE the Reactivity Difference between the ACC and the ECC, AND RECORD the result on Attachment 3. . 8.0 BASES 8.1 [B 8] SOER 88 02 " Premature Criticality Events During Reactor Startup". 9.0 RECORDS

                                 ~ Lifetime Records All Records generated by this procedure, except Attachment 6, shall be retained for the life of the plant. The Procedure Sponsor shall be responsible for thess recorde until they cre transferred to Records Management. Legibility and completeness of the records shall be verified by the Procedure Sponsor prior to transferal.

Radiological Lifetime Records None Non Permanent Records Attachment 6 Feedback Sheet i ! . .

Estime ; 'Itical Condition Units 1 & 2 NEOP 302/Roy,1 Page 13 of 25 4 i # Attachment 1 ATTACHMENT LOG 8HEET Unit: Cycle: i NEOP 302 Copy No. Signature Date Removed Attachment. Initials /Dateg,

/.

9 e

                                                                                                             . .                                                               s
                             . # NOTE: Obtain a sequence number from the Attachment Log Sheet, Attachment 1.

l l I

i Estimated critical Condition Units 1 & 2 NEOP.302/Rev.1 Page 20 of 25 ( 8- , Attachment 2A, ESTIMATED CRITICAL CONDITION . Estimated Critical Coron (ECB) Previous Cntical Conditions 6.2.A.1.a Unit:_ _ Cycle: l 6.2.A.1.b Date: Time: 6.2. A.1.c Burnup: MWD /MTU , Estimated Critical Condition 6.2.A.2 Excess Reactivity:- % op #' 6.2.A.3 Date: _ Time: 6.2.A.4 Time After Shutdown: hrs 6.2.A.5 Xenon Worth:_ % ap e.2.A.7 CEA Position (Ir.ches) Grp 3: Grp 4: Grp 5: CEA Worth: % op 6.2.A.8 ' Corrected HZP IBW: opm/%Ap 6.2.A.9 Critical Boron Worth: (6.2.A.2) [(6.2.A.7)+(6.2.A.5)) = %Ap 6.2.A.10 ppm Estimated Critical Bo'on Concentration: (6.2.A.9)*(6.2.A.8) = ECC Tolerance Band 6.2.A.11 ECC Lower Bound: (6.2.A.7) + (0.5) = %ap 6.2.A.12 ECC i.ower Bound CEA Position (lnehes): Grp 3: Grp 4: Grp 5: 6.2. A.14 ECC Upper Bound: (6.2.A.7) - (0.5) = %Ap 6.2 4.15 ECC Upper Bound CEA Pos don (Inches): Grp 3: Grp 4: Grp 5: 6 2.A.17 Prepared by: Daterrime: / Review and Approval 6.2.A.23 SRO Review: Daterrime: / i

                                  # NOTE: Obtain a sequence humber from the Attachment Log Sheet, At'tachment 1.

i-Estimated Critical Conditlan Units 1 & 2 NEOP 302/Rev.1 ! Page 21 of 25

!            i                                                                                                                                                  #-

Attachment 2B, ESTIMATED CRITICAL CONDITION . Estimated Critical Position (ECP) Previous Critical Conditions

6.2.B.1.a Unit: '

Cycle: ! 6.2.B.1.b Date: Time: 6.2.B.1.c Burnup: MWD /MTU d. l Estimated Critical Condition

6.2.B.2 Excess Reactivity. % ap *

! 6.2.C.3 - Date:_ . l Time: 6.2.B.4 Time After Shutdown: hrs 6.2.B.5 Xenon Worth: % ap 6.2.B.7 Critical Boron Concentration: ppm 6.2.8.8 Corrected HZP IBW: ppm /h p 6.2.B.9 Mp Critical Boron Worth: (6.2.8.7)/(6.2.8.8) = 6.2.B.10 ' Critical CEA Worth: (6.2.B.2)-[(6.2.B.9)+(6.2.B.5)) %p = 6.2. B.11 Critical CEA Position (Inches) I Grp 3: G/p 4: Grp 5: ECC Tolerance Band 6.2.B.12 ECC Lower Bound: (6.2.B.10) + (0,5) = Mp 6.2.B.13 ECC Lower Bound CEA Position (Inches): Grp 3: Grp 4: Grp 5: 6.2,B.15 ECC Upper Bound: (6.2.8.10)-(0.5) = bp 6.2 2.16 ECC Upper Bound CEA Position (lnehes): Grp 3:- Grp 4:_ Grp 5: 6.2.8.16 Prepared by: Date/ Time: / Review and Approval 6.2.B.24 SRO Review: Date/ Time: / '

                       # NOTE: Obtain a sequence number from the Attachment Log Sheet, Attachment 1                                                                                     
   - - . . _ . . . _ ,     _ . - _ - _ _ ,                   ._       _ . - _         _ . - - . _ . _             . _ _ . ~ - , _ . _ _ _ . .               . _ _ . .           . _ _ _ _ _ .

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

Estimated Critical Condition Units 1 & 2 NEOP 302/Rev.1 , Page 22 of 25 i # Attachment 3, ACTUAL CRITICAL CONDITIONS l Unit: Cycle: ' 7.1 Actual Critical Conditions (Completed Following Criticahty at Stabilized Conditions) Date: Time: Power: Percent g' , T., : 'F Boron Sample:- ppm Sample Time: Boronometer: ppm j .. CEA Positions (Inches): Grp 3: . Grp 4: Grp S: Prepared by: Date: 7.3 To be completed by NFM following criticality: ACC ECC Reactivity Difference t l Documented by: Date: ,_.,

                             # NOTE: Obtain a sequenca number from the Attachment Log Sheet, ettachment 1.

G

 ..v-    . - . _ _ _ , , . . - _ _             ~ . _ _ _ _ , . . . _ , . - _ . , -   ..._,_._,-.,,m,                 , . . . - _ . - - . . _ _ . . , _ , , _ . - - _ . . . . , , , . _ . . - _ , . . . . . . - . - _ , _ , ,

_ _ _ . ~ . _ ,

Estimated Critical Cendition Units 1 & 2 i NEOP 302/Rev 1 l Page 23 of 25 i O Attachment 4 , ADJUSTED ECC WORKSHEET

1. Unit:- Cycle:,,,,,_

Adjust' men! Using Bbron Concentration (6.3.C.2) 2.a Corrected HZP IBW: ' opm/%Ap 2.b Previous Critical Boron Worth: /* *

                                                                                                                              %Ap _

2.c Adjusted Critical Boron Worth:(2.b /+ 0.5)

                                                                                                                              %Ap 2.d              Adjusted ECC Boron Concentration:(2.c'2.a)                                          opm 2.e               ECC Tolerance:                                                                                  ( .,

Lower Bound: (CEA Worth) + (0.5) = %An Lower Bound CEA Position (inches): Grp 3: Grp 4: Grp 5:

Upper Bound: (CEA Worth)- (0.5) = %Ap Upper Bound CEA Position (Inc... ..): Grp 3: Grp 4: Grp 5:

Adjustment Using CEA Position (6.3.C.3) 3.a CEA Worth: %Ap 3.b Adjusted CEA Worth:(3.a +/ 0.5): %Ap 3.c Lower Bound: (Adjusted CEA Worth) + (0.5) = %Ap 3.d Lower Bound CEA Position (Inches): Grp 3: Grp 4: Grp 5: 3.f Upper Bound: (Adjusted CEA Worth) . (0.5) = %Ap 3.g Upper Bound CEA Position (Inches): Grp 3: Grp 4: . Grp 5:- Adjustment Using duron Concentration and CEA Position (6:3.C.4) 4.a CEA Position (Inches):Grp 3: Grp 4: Grp 5:- 4.b Adjusted ECC CEA Worth %Ap 4.c Previous ECC CEA Worth %Ap 2 4,d Change in CEA Worth (4.c-4.b) %Ap 4.e Previous ECC Boron Worth %Ap 4f ECC Adjustment (4.e +/- 0.5) %Ap 4.g Adjust;d Boron Worth (4.d+4.f) i: %Ap 4.h Correted HZP IBW opm/%Ap 4.1 Adjusted ECC Boron Concentration (4.g'4.h) opm 4.] Lower Bound: (CEA Worth) + (0.5) = %Ap 4.k Lower Bound CEA Position (Inches):GRP 3: GRP 4: GRP 5:- 4.m Upper Bound: (CEA Worth) - (0.5) = %Ap 4.n Upper Bound CEA Position (Inches):GRP 3: GRP 4: CRP 5: ; ! 6.3.C.6 _ Prepared by: i Date/ Time: /

ECC Review and Approval ~ 6.3.C.7 _ SRO Review: Date/ Time: /

                     # NOTE: Obtain a sequence number from the Attachment Log Sheet, Atfachment 1.

Estimated Critical Canditi:n Units 1 & 2 NEOP 302/Rev.1 Page 24 of 25 i, 1 Attachment 6, PAGE VERIFICATION Reason For Page Check Numbel af Page Check Date . Pages Complete (initials)

r. ,

4 t .. 3 f1 dus

     # NOTE: Obtain a sequence number from the Attachment Log Sheet, Attachment 1.             . .

Estimated Critical Ccnditi:n Units 1 & 2 NEOP 302/R0v.1 Page 25 of 25 t' I Attachment 6 FEEDBACK SHEET Procedure _ From - Recommendation i l l ~ I

l ._ Send to: Principal Engineer ','.; clear Fue: Management,1st Floor, NEF

Estimated Critical Conditisn > f *2 r Units 1 & 2 NEOP 302/Rev.1 Page 20 of 25 Attachment 2A, ESTIMATED CRITICAL CONDITION . Estimated Critical Boron (ECB) Previous CriticalConditions 6.2.A.1.a Unit: / Cycle: /3 6.2.A.1.b Date: Time: 6.2.A.1.c Burnup: /3, tro MWD /MTU d, - Estimated CriticalCondition L 6.2.A.2 Excess Reactivity:- fW % ap # ! 6.2.A.3 Date:- Time: [ 6.2.A.4 Time After Shutdown:_ 7 N hrs i 6.2.A.5 Xenon Worth: O % ap 6.2.A.7 CEA Position (Inches) y Grp 3: kd( Grp 4: O Grp 5: Op CEA Worth: /IW % ap 6.2.A.8 ' Corrected HZP IBW:- // Z d- opm/%Ap

      ;                     6.2.A.9       Critical Boron Worth: (6.2.A.2) [(6.2.A.7)+(6.2.A.5)) = 7dd %ap 6.2.A.10      Estimated Critical Boron Concentration: (6.2.A.9)'(0.2.A.8) = @dAppm ECC Tolerance Band 6.2.A.11 ECC Lower Bound: (6.2.A.7) + (0.5) =                      %ap 6.2.A.12     ECC Lower Bound CEA Position (Inches): Grp 3:          Grp 4:_        Grp 6:

6.2.A.14 ECC Upper Bound: _( 6.2.A.7) - (0,5) = %ap 6.2 4.15 ECC Upper Bound CEA Position (Inches): Grp 3: Grp 4: Grp 5: 6.2.A.17 Prepared by: Date/ Time: / Review and Approval 6.2.A.23 SRO Review: Date/ Time: /

    +                                                                                                                            =
                                       # NOTE: Obtain a sequence number from the Attachment Log Sheet, At'tachment 1.

a

UNIT 1 TECHNICAL DATA BO/# NEOP 13/REV. 3 PAGE 31 OF 60 3 FIGURE 1 II.A.2 INVERSE BORON YlORTH vs. BURNUP NO BORON 10 DEPLETION CORRECTION APPI 'ED Unit 1 Cycle 13 (Pege 3 of 3) Burnup HZP Inverse HFP Inverse HZP Inverse HFP Inverse Burnup Boron Worti. Boron Worth Boron Worth Boron Worth (v lutv) (opm/%Ap) (ppm /%Ap) I, ,"TV) (ppm /%Ap) (ppm /%Ap) 1G200 115 27 ' 120 83 15300 105 49 110 31 10300 115 08 120 63 16400 105 29 110.10 10400 114 90 120 44 155 %

105 10 109 88 ,,

10$00 114 72 120 24 15600

                                                                                            '              104 90       109 67 106b0                               114 53               12004                      ib700      104 71       109 48 10700                              11435                 119 64                     15800      104 51       1D9 25 10800                              114 16                119 65                     15900      104 32       f 09 03 10900                              113 97                119 45                     46000      104 12       108 82 11000                              til79                 119 28                     16100      103 93       108 61 11100                              1'3 60                11ICs                      16200      103 73       108 40 11200                              113 41                118 65                     16300      10354        108 18 11300                       ~113 22                      118 65                     16400      10334        107.97 11400                              1'3 03                118 45                     16500      103.15       107.76 11500                              112 84                118 24                     16600      102 95       107.55 11600                              112 65                118 04                     16700      102 76       107.33 11700                              112 46                11) 64                     16800      102 56       107.12 11800                              ti? 27                117 64                     16900      102 36       106 91 11900                              112 08                117.43                     17000      102.17       106 70 12000                              111 89      .         117 13                     17100      101 97
                                                                                                       ~                106.48 12100                             111.70                 117.02                     17200      101.78       106 27
   $           3                                                      to                          400 111.13 *
                                                                                           ~

12400 116 41 17500 101.19 105 63 12500 110 94 116 21 17600 101.00 105.42 12600 110 74 116 00 17700 100 80 105 21

12700 11055 11660 17800 100 61 105 00 12600 11036 11559 17900 10041 104.78 12900 110 17 115 38 18000 100.21 104.57 13000 109 98 11518 18100 100.02 104.36 13100 109 7P 114 97 18200 99 82 104.14 13200 109 59 114.76 1A300 99 63 103 93 13300 109 39 114 55 16400 9943 103 72

       '- 1                  -

114 33 18500 99.24 103 51 h 1 00 108 81 g 18600 99.04_ 103.29 18700 98 85 103 08 13700 10861 113 70 18800 98 65 _, 102.87 13800 108 42 113 49 18900 98.45 102.65 13900 108 22 113 28 19000

                   ~                                                                                       98 26        102.44 14000                             108 03'                113 07                     19100      98 06        102.23 14100                             107.83                 112 85                     19200      97.87        102.02 14200                              10764                 112 64                      19300      97.67
                                                                                           ~                            101.80 14300                             107.44                 112 43                      19400      97.48        101 59 14400                             107.25                  112 22                     19500      97.28        101.38 14500                                                    $ 12 01                     19600      97.09        101.17 14600                                       e6             s!.79                     19700      96 89        100.95 14700                             106 66                 111.58                      19800      96.70        100.74 14600                             106 47                  111.37                     19900      96 50        100 $3 1(900                             106 27                 111.16                      20000      96 3Q        100.31 15000                             106 08                 110 95                      20012      96.28        100.28 15100     _ _105 88                                      110 73 15200                             10s69                  110 52 w                                          a

UNIT 1

   ,                                                                 TECHNICAt. DATA BOOK                                                                               NEOP.13/REV. 3 PAGE 31 OF 60 FIGURE 1.ll.A.7 EXCESS REACTIVITY vs. BURNUP HZP, ARO, NO XENON, EQUILlBRIUM SAMARIUM Unit 1 Cycle 13 (Page 2 of 2)

Burnup HIP Excess Burnup HZP Excess HZP Excess Ournup Burnup HZP Excess Reactivity Reactivity Ivej"WI (%Ap) I. "WI I.v "WI Reactivity Reactivity (%Ap) (%Ap) I I"tu) (%Ap) 0 15 750 5100 13 5b3 10200 11 129

                   ~                             ~                                                                                                               15300            7 954 100     15 679               6200         13651                       10300                     11 076                              16400            7 925 200     16 608               6300         13 610                      10400                     11 020                              16500            7 867 300     16 637               6400         13 468                      10000                     10'#66                              16600            7 789 400     16 466               6600         13426                       10600                     10 910                              16700            7720 600     16396                5600         13 383                      10700                     10 855                              16800           7 662 i                            600      16 325               6700         13341                       10800                     10 799                              16900r          7 683 700     16 254              6800          13 298                      10900                     10 744                              16000           7 616 800      15 183              6900          13264                       11000                     10 688                              16100           7 446 900      16 112              6000          13 211                      11100                    10 632                               16200           7378 1000      15 041              6100          1;f 10/                     11200                    10 676                               16300           7 309 1100      16 009              6200          13 123 1200     14 979               6300          13 07e 11300            [10620                                       16400           7.240 11400                    10 464                               16500           7.171 1300       14 949              6400          13 033                      11500                    to407                                16600           7.103 1400      14 918               6500         12 988                       11600                    10 351                               16700       ' 7.034 1500      14 888               6600         12 943                       11700                    10 294
                                                                                              ~                                                                 16800           6 965 1600      14 867               6700         12 897                       11800                    10 237                              16900           6 896 1700      14 825               6300         12 851                      11900                     10 180                              17000           6 827 1800      14 794               6900         12 805                      12000                     10.123                              17100           6 769 1900      14 762               7000         12 758                      12100                     10 066
                                                                                      ~                                                                         17200           6 690 2000       14 729               7100         12 712                      12200                     10 009                              17300           6 621
             !           2100       14 697               7200         12 664                      12300                      9 951                              17400           6 $$2
             %           2200       14 664               7300         12 617                      12400                      9 894                              17500           6 483 2300       14 631               700          12 669                      12500                      9 *36                              17600           6 414 2400       14 598               7500         12 621                      12600                     9 779                               17700           6 345 2500       14 664               7600         12 473                      12700                     9 721                               17800           0276 2600       14 531 -            7700          12 424                      17800                     9 663                               17900           6 207 2700       14 496             7800           12 375                      12900                     9 605                               18000
                                                                                      ~                                                                                         6 138 2800       14 462             7900           12 3'6                      13000                     9547                                18100           6 069 2900      *4427               8000           12217                       13100                     9 482                               18200           6 000 3000      14 392              8100          12 227                       13200                     9 416                               18300           5 930 3100      14 357              8200           12 177                      13300                     9 348                               18400           5 861 3200 ==   14 322              8300          12.127                                                 9 28                               18500            $792 3300      14 286              8400          12 076                 4           r 18600            6 723 3400       14 250              8500          12 026                      13600                                                         18700
                                                                                    ~                                                                                          5 654 3500       14 213              8600          11 975                      13700                      9 079                              18800           6 565 3600       14 177              8700          is923                       13800                      9 012                              18900
                                                                                                                                    ~                                          5 616 3700       14 140              8800          11 872                      13900                      8 944                              19000           5447
                                                                                                                                        ~

3800 in 103 8900 11.820 14000 8 877 19100 6.378 3900 14 065 9000 11.768 t4100 8 809 19200 5 308 4000 14 027 9100 11 716 14200 8 742 19300 6239 4100 13 989 9200 11 664 14300 8 674 19400 6.170 4200 13 951 9300 11 611 14400 8 606 19500 5.iOI 4300 13 912 9400 11 559 14500 8 538 '9600 $032 4400 13 873 9500 11 506 14600 8 470 19700 e963 4500 13 834 9600 11.4b2 14700 8402 19800 4 894

4600 13 794 9700 it '99 14800 8 334 19900 4 825 4700 13 755 9800 11 345 14900 8 266 20000 4 756

4800 13 715 9900 11.292 15000 8 198 20012 4 747 4900 13 674 10000 11 238 15100 8.130 5000 13 634 10100 11.183 15200 8 062 *

 . . ~ . ,                                    0. _ _                           ..-      .--               - . , , -                                   - ,, ,                     . - -

UNIT 1 TECHNICAL DATA BOOK NEOP 93/REV. 3 PAGE 35 OF 60 FIGURE 1 II.B.1 HZP INTEGRAL CEA WORTH WITH OVERLAP 10,000 "*/w7u TO 16,500 "*/uvo Regulating Bank Worth = 3.622 %Ap Unit 1 Cycle 13 (Page 4 of 5) Group 5 Group 4 Group 3 '8 ' Group 6 Integral (Inches W/0) (inches W/D)

                                                    "[E          o                                 Group 4          Group 3 CE          orth (Inches W/D)            4.j                 (Inches W/D) (incties WID)           (Inches W/D) 72 00                           0837                                        33 75 l                    123 75      . ' 1.103 71 25 l

0840 l 33 00 123 00 1.13 2 l 7050 0 644 l 32 25 122 25 1.121 1 69 75 . ( '7 31.50 1 121.50 1 130 I 69 00 0850 l 30.75 120 75 1.139 l l 68 25 0 854 30 00 l 120 00 ' 1148 l l 67 50 0 857 29 25 l 119'25' i157 1 66 75 0660 28 50 l 118 50 1.166 l 66 00 0 664 27.75 l 117 75 1.176 1 65 25 0 667 27 00 l 117.00 1.185 l 64 50 0 870 i 26 25

                                                                        ,                                            116 25             1 195          l 63 75                           0 873                                        25 50 1

l .1550 1 205 l 63 00 0 877 24 75 l 114 75

215 l 62 25 61 50 0 680 0 884 1 24 00 114 00 *5.

l l 23 25 113 25 1 235 l 60 75 0 887 22 50 l 112.50 1245 1 60 00 0891 21 75 l 111./5 1 255 l 59 25 0894 l 21 00 111.00 1 265 l SB 50 0 898 20.25 l 110 25 1 276 l 57.75 0 902 19 50 _ l 109 50 1.266 l 57 00 0 9D6 1875 l 108 75 1 296 l k 56 25 . 0910 l 18 00 _ 108.00 1 30S l 55 50 . 0914 .l 17.25 107.25 1.317 I 54 75 0918 16 50 106.50 l 1 327 l 54 00 0 923 15 75 105.75 1 1 337 l

                       $3 25                           0 927                                l       15 00           105 00             1 348         I 52 50                           0 932                                l       14 25           1D4 25             1 358         l 51.75                           0 937                                        13 50           103.50 l                                          1.368         1 51 00                           0 942                                       12.75            102.75
                                                                    ~                      l                                           1 378        l 50 25                          0 947                                l       12.00            102.00            1.388         I 4950                           0 952                                l       11.25            101.25            1.398
               ~                                                                                                                                    1 48 75                          0 958                                l       10.50            100 50            1.407         1 48 00                          0 964                                i        9.75            99 75             1 417         l 47 25                           0 970                                             '

99.00 l 1 426 l 46 50 0 976 45 75 0 S02 L 0__

                                                                                                               . 98.25             1.435        l l                    l    97.50             1 444        l 45 00        135 00             0 988                              i         ~ti 75           9r 75             1 453 l                                   1 44 25        134 25             0 995                              l          6 00            93 00             1 462 l                                   l 43 50        133 50             1 002                              l          5 25       l    95 25             1 470 ,      l 42 75        1'2 75             1 009                              l         4 50             94.50             1 479 l                                   l a2 00        132.00             1 016                              l         3.75        l    93.75             1,487        l 41 25        131 25             1 023                              l         3 00       l     93 00             1 495        1 4     -

4050 13n 8 ) * * ' 4"R1:030 **t '* l 2 25 l 92 25 1 503 1 39 75 129 75 1.038 l .3 l 91.50 1 510 l 36 75 126 75 1 069 l l 88 50 1 539 l 36 00 126 00 1 078 I l 87.75 1 546 1 35 25 125 25 1 086 l l 87 00 1 553 l 34 50 124 50 1 094 l 86 25 1 560 l l i .

 '                                                            Estimated Critical Condition           Units 1 & 2 NEOP 302/Rev.1 Page 21 of 25 s

Attachment 2B, ESTIMATED CRITICAL CONDITION Estimated Critical Posillon (ECP) Previous CriticalConditions 6.2.B.1.s Unit: / Cycle: O 6.2.0.1.b ( te: Time:- 6.2.B.1.c Burnup: /3jC00 MWD /MTU d. , Estimated CriticalCondition 6.2.B.2 Excess Reactivity: <W % ap 6.2.B.3 Date: Time: 6.2.B.4 Time AfteIShutdown:_. N hrs 6.2.B.5 Xenon Worth: O % op 6.2.B.7 Critical Boron Concentration: Okppm 6.2.B.8 Corrected HZP IBW: //7,1 ppm /%ap 6.2.B.9 Critical Boron Worth: (6.2.B.7)/(6.2.B.8) = _6.W3 %ap 6.2.B.10 ' Critical CEA Worth: (6.2.B.2)-[(6.2.B.9)+(6.2.B.5)) = 3 39 %Ap E' < {

   ;       6.2.B.11 Critical CEA Position (Inches)                                                    -'

Grp 3:f.d_._ Grp 4: c0 Grp 5:4O s7 ECC Toleranco Band 0.2.B.12 ECC Lower Bound: (6.2.R.10) + (0,5) = %ap 6.2.B.13 ECC Lower Bound CEA Position (Inches): Grp 3: Grp , Grp 5: ,, 6.2.B.15 ECC Upper Bound: (6.2.B.10) - (0,5) = %4p 6.2 2.16 ECC Upper Bound CEA Position (Inches): Grp 3:- Grp 4: urp5: 6.2.B.18 Prepared by:

Date/ Time: /

Review and Approval 6.2.B.24 SRO Review: ,, Date/ Time: /

          # NOTE: Obtain a bequence number from the Attachmsnt Log Sheet, Attachment 1.

_m

I ,

$ CCNPP LICENSED OPERATOR - JOB PERFORMANCE MEASURE OI 21 A 2M SYSTEM: 4160 VAC Distribution System TASK: 020$20206 Transfer 11/17 4KV Sus Loads from 1 A DG to Offsite Power , PURPOSE: Evaluates an Operator's Ability to Return a Vital 4 KV Bus Being Supplied by a Diesel to Normal Operation JOB PERFORMANCE MEASURE CALVERT CLIFFS NUCLEAR POWER PLANT LICENSED OPERATOR i l ORIGINAL: PREPARED BY: DATE: REVISION: REVISED BY: _. DATE: Operations Instructor Nuc REVIEWED BY: DATE: SRO License liolder t APPROVED BY: DATE: Ops Training Supervisor NRC Exam 11/97 Rev.1

 .                                                                                                                                   Page 2 3

CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE OI 21A 2M TASK: 020520206 Transfer 11/17 4KV Hus Loads from l A DG to Offsite Power

PERFORMER'S NAME: APPLICABILITY: RO and SRO PREREQUISITES: Completion of the knowledge requirement of the Initial License class training program for the 4160 VAC System, EVAL.UATION LOCATION: PLANT SIMULATOR CONTROL ROOM EVALUATION METilOD: ACTUAL PERFORMANCL DEMONSTRATE PERFORMANCE ESTIMATED TIME ACTUAL TIME TIME CRITICAL TASK: TO COMPLETE JPM: TO COMPLETE JPM: 15 MINUTES MINUTES NO TASK LEVEL: l LEVEL 1 TOOLS AND EQUIPMENT: None REFERENCr PROCEDURE (S): OI-21 A IC18 ALM IC188 ALM TASK STANDARDS: This JPM is complete when bus feeder breaker 152-1115 has been paralleled with I A Diesel Generator on 4 KV bus 11 and la Diesel Generator is shutdown, i U

Page 3 CCNPP LICENSED OPERATOR JOli PERFORMANCE MEASURE OI.21 A 2M TASK: 020520206 Transfer 11/17 4KV llus Loads from l A DO to Offsite Power DIRECliONS TO EVALUATOR:

1. Read the " Directions to Trainee" to the trainee.

2. Note the time that the task is started. As the task proceeds, indicate completion of each element using the Standard criteria and the following notation:

S" for satisfactory completion "U" for unsatisfactory completion "N"if not observed OR not verifiable Critical elements must be observed or the evaluation is invalid.

3. When the Tenninating Cue is reached, tell the trainee that no further actions are necessary. Note the completion time.

4. Document any instances ofincorrect performance in the Notes area (required for critical steps).

   ;       5. Questions should be asked after completion of the task.

6. Indicate whether the task was completed satisfactorily on the basis of correct wrformance of all critical elements and completion of the task within the istimated Time to Complete for Time Critical tasks.

7. This JPM contains the steps, notes, cautions, and standards that are applicable to the initial conditions specified in this JPM, Steps that do rot directly relate to this JPM, but appear in the procedure, are not listed here. It is the responsibility of the evaluator and/or observer to become familiar with the procedure prior to use of this JPM.

1

Page 4 CCNPP LICENSED OPERATOR JOH PERFORMANCE MEASURE OI 21 A 2M TASK: 020520206 Transfer 11/17 4KV Dus Loads from 1 A DO to Offsite Power JPM STANDARDS (List of minimum Standard Practices for common evolutions at CCNPP) 1.0 Starting a pump If non emergency condition, dispatches a PO to verify pump is ready to be started. Identify the Control Switch and Indicating Lights, usmg authorized identi0 cation. Operate the Control Switch, to START, and check expected Indicating Light response. Check proper pump operation (as applicabic): Motor amps Pump dischstge pressure System now Activation / Clearing of applicable Annunciators (e.g.: lli Disch Press, Lo lidr Press) 2.0 Stopping a pump identify the Control Switch and Indicating Lights, using authorized identification.

Operate the Control Switch, to STOP, and check expected Indicating Light response.

Check expected system response (e.g.; How, pressure, level) 3.0 Operating Control Valves / Motor Operated Valves / Circuit Breakers i k identify the Control Switch and Indicating Liphts, using authorized identification. Select the Control Switch to the desired position. Check Valve /llreaker position, using position Indicating Lights. Check expected system response (e.g.; How, pressure, level, volts, amps, KW) 4.0 Checking Vah elllreaker position Identify the Valve / Breaker indicating Lights, using authorized identi0 cation. Check the Valve / Breaker is in the correct position.

                   *f Valve / Breaker is not in correct position, report Valve / Breaker position to CRS.

5.0 Verifying valve / breaker position identify the Valve / Breaker Indicating Lights, using authorized identi0 cation. Check the Valve / Breaker is in the correct position, if Valve / Breaker is not in correct position, operates Valve / Breaker to correct position. 6.0 Locally starting a pump Verify the following: Suction Valve open Dischvge Valve position (as applicable) Mininow Valve position (as applicable) Pump and Motor oil levels are normal Adequate Suction Pressure Identify the Control Switch and Indicating Lights, using authorized identification. - Operate the Control Switch, to START, and check expected Indicating Light response. Check for proper Pump operation (as appltcable): i

Page5 CCNPP LICENSED OPEkATOR JOH PERFORMANCE MEASURE OI-21A-2M TASK: 020520206 Transfer 11/17 4KV Bus Loads from 1 A DG to Ofsite Power Smooth, quiet operation consistent with pump hi: tory Oil level remains good Proper seal leakoff Proper discharge preasure Expected system flow v.0 Locally stopping a pump 2 Identify the Control Switch and Indicating Liahts, using authorized identification. Operate the Control Switch, to STOP, and check expected Indicating Light response. { Check expected system response (e.g.; flow, pressure, Ireel). y e J 8.0 Operating a Manual Valve Identify the Valve, using authorized identification. Operate th: Valve and check expected posit;un indication change (e.g.; stem rise, pointer). Check expected System response (e.g.: fluid thy sounds, press' ire changes, tank levels). ) 9.0 Locally cperating Control Valves / Motor Operated Valves / Circuit Breakers identify the Control Switch and Indicating Lights (if applicable), using authorized identitis tion. Operate the Control Switch and check expected Indicating Light response. ( Check expected System respons:(e.g.: flow, pressure, levels, volts, amps). 10.0 Locally checking Valve / Breaker position Identi.} the Valve / Breaker, using authorized identification. Check the Valve /Dreaker is in the correct position, using appropriate position indication (e.g.; pointer, stem rise, f6ags, indicating lights). If Valve / Breaker is not in correct position, report Valve / Breaker position to Control Room. 11.0 Locally verify 8ng Valveelr:aker position Identify the Valve / Breaker, using authorized :dentification. Check the Valve / Breaker is in the correct position, using appropriate positie. it.dication (e.g.; pointer, s;em rise, flags, indicating lights). If Vaive/ Breaker is not in correct position, operates Valve / Breaker to correct position.

      .                                                                                              Page 6 L-CCNPP LICENSED OPERATOR JOB PERFORMANCI' MEASURE OI-21 A-2M TASK:     020520206        Transfer 11/17 4KV Bus Loads from 1 A DG to Offsite Power DIRECTIONS TO TRAINEE:

1. To complete the task successfully, you must perform each critical element correctly. You must inform the evaluator of the indication = you are monitoring, h Where necessary, consider the evaluator to be the CRS.

I F 2. Initial Conditions: l

a. 1 A Diesel Generator is supplying power to 4 KV bus 11.

l

b. 4 KV bus 1I feeder breakers 152-1115 and 152-1101 are open.

c. You are performing the duties of the Unit 1 CRO.

3. Task Standard:

1

4. Initia'ing Cue: The CRS directs you to paralle! bus feeder breaker 152-1115 with h the Diesel Generator in preparetion to shut down the diesel. Are (here any questions? You may begin.

m u L E

P ge 7 CCNPP LICENSED OPERATOR JOB PEltFORMANCE MEASURE OI 21 A-2M ELEMENT STANDARD (* = CRITICA' STEP) TIME START _ CUE: The General Precautions and Initial ronditions have been met. Begin at step

                   . 4.B.I.

Identify and locate 01-21 A, Step Same as element. 6.4.B. l .

1. CIIECK the selected 11/17 4KV Bus (S}

offsit,e power murce is expected to remam available:

                 .          114KV BUS LLT FDR, 152-1101 GR
                 .          114KV BUS NORMAL FDR, 152-1115

2. VERIFY DC cointrol poweris Same as element.

   ,             available by observing the 11/17 4KV i             Bus Normal _OR Altemate Feeder breaker position light being illuminated I

at the control switch I l f CAUTION: Parallel operation of 1 A DG with the 13.8 KV Voltage Regulators in AUTO will cause MW MD KVAR load variations during tap changes.

3. PLACE the 13.8KV Voltage Regulator aligned to 114KV bus in MANUAL as follows:

NOTE- . U4000-11 is normali: aligned to 11,12 and 13 4KV buses U4000-21 is normahy aligned to 14 4KV bus

a. MONITOR 114KV bus Monitors 114KV bus voltage using voltage, appropriate indication.

Page8 CCNPP LICE *' SED OPERATOR JOB PERFORMANCE MEASURE OI-21A-2M ELEMENT STANDARD (* = CRITICAL STEP) CUE: When dispatched, PO reports Voltage Regulator in MANUAL.

b. PLACE the associated Dispatches PO to place the 13.8KV Voltage Regulator MODE Voltage Regulator in MANUAL.

SELECTOR switch in PO directed to place 1HI102 REG in MANUAL at the Load Tap MANUAL. Changer Panel: U4000-11 1HI102 REG U4000-212H2102 REG

4. PLACE l A DG in the TRANSFER MODE by performing the following:

a. DEPRESS lA DG Same as element EMERGENCY START, 1-HS-1707, pushbutton.

b. INSERT the Sync Stick for Inserts Sync Stick for I A DG OUT BKR, 1-CS-152-1703 at 1Cl8A.

1-CS 152-1703.

c. DEPRESS 1 A DG SLOW Same as element START,1-HS-1708, pushbutton.

d. MOMENTARILY PLACE Same as element l A DG SPEED CONTR, 1-CS-1705, to RAISE OR LOWER.

e. MAINTAIN 1 A DG at Same as element approximately 60 Hz using 1 A DG SPEED CONTR, 1-CS-1705.

f. REMOVE the Sync Stick Removes Sync Stick.

from 1 A DG OUT BKR, 1-CS-152-1703. l y v ,- - -

Page 9 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE OI-21 A4M ELEMENT STANDARD (* = CRITICAL STEP) .

g. INSERT the Syne Stick for the riaces sync stick in sync jack next 11/17 4KV Bus NormalDR to control switch for 152-1115.

Altemate Feeder breaker handswitch:

                           .        Il 4KV BUS ALT FDR, 1-CS-152-1101 QR
                           .,       114KV BUS NORMAL FDR,1-CS-152-1115 CUE: Synchroscope and sync lights are operating.

h. CHECK the associated Checks 1C18B c, schroscope.

Synchroscope AND Sync Lights are operating.

   , CUE: Running volts are higher than incoming volts.

8 NOTE: Offsite power voltage indication will be on the INCOMING voltmeter.

i. ADJUST RUNNING VOLTS Lowers running volts to match e.lual to INCOMING VOLTS incoming volts using 1-CS-1704 using l A DG AUTO VOLT (i 100 volts).

CONTR,1-CS-1704. NOTE: The Synchroscope works in the opposite direction from normal when l A DG is the RUNNING power source. CUE: Synchroscope is running counterclockwise fast.

j. ADJUST 1 A DG frequency so Adjusts synchroscope to slowly in.

the synchroscop pointer is fast direction. rotating slowly m the FAST direction using 1 A DG SPEED CONTR,1-CS-1705. CAUTION: To avoid improper paralleling, do NDI start DR stop any large loads on the 11/17 4KV Bus. i {'I -

Page 10 CCNPP LICENSED OPERATOR , JOB PERFORMANCE MEASURE OI-21A-2M ELEMENT STANDARD (* = CRITICAL STEP) CUE: CRS directs to close normal feeder.

k. WHEN the Synchroscope Closes to 1-CS 152-1115 atl5 to pointer is approximately 5 12 o' clock position.

degrees prior to the 12 o' clock position, THEN CLOSE the 11/17 4KV Bus Normal DE Altemate Feeder breaker:

                             .       114KV BUS ALT FDR, 1-CS-152-1101 DE
                             ,       114KV BUS NORMAL FDR,1-CS-152-Il 15.                                    '

1. CHECK 1 A DG c.9d is Same as element approximately 2.0 MW.

j m. REMOVE the Sync Stick AND Same as element i RETURN to Home Base. CUE: 11/17 voltage is 4.2KV.

5. Maintain 11/17 4KV Bus voltage Verifies voltage.

between 3.75 KV and 4.35 KV by one of the following method 2:

                    .        Adjusting 500KV line voltage OR
                    .        Adjusting 1 A DG load and voltage D.R
                    .        Adjusting 13.8KV Voltage Regulator voltage

Page11 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE OI-21 A-2M ELEMENT STANDARD (* = CRITICAL STEP) NOTE TO EVALUATOR: Simulator operator.o input: Annunciator AA05 (LA DG

ENGINE *EXICTER SHUTDOWN) to actuate.

6. Respond to DG 1 A alarm. Directs Plant Operator to identify and locate 1C18A-ALM, Window AA05, a.1 A DG engine or exciter shutdown Dete,rmines DG engine is still runnmg,

b. IF a normal manual DG shutdown Pir. cts Plant Operator to identify has EQI been performed, THEN end locate ICI18A-ALM, Window Respond per IC188-ALM. SL45.

CUE: Local operator calls from 1 A DG local panel. Reports oil being sprayed in room. Panel has numerous alarms and lube oil pressure indication is down to 40 psig and dropping. _7. Determine lube oil pressure is below Same as element. (NOTE: May

   ,               the 1 A DG trip setpoint                                  refer to 1Cl88-ALM SL 64 in 1 A

( DG Building)

8. Trip 1 A DG.

l Depresses l A DG STOP pushbutton on panel 1Cl8 OR Directs operator to take 1 A DG to LOCAL control and depress BOTH Emergency STOP pushbuttons on local control panel. CUE: Report on following when asked: Feeder breaker (152-1703) GREEN light lit; DG voltage , frequency, and KW indicate ZERO. _ _ 9. Verify 1 A DG stopped. Checks: DG feeder breaker - OPEN DG voltage - 0 volts DG frequency - 0 Hz DG load - 0 KW TIME STOP l u

. Page 12 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE OI 21A-2M ELEMENT STANDARD (* = CRITICAL STEP) TERMINATING CUE: This JPM is complete when offsite power is restored to 114KV bus with 11 A DO is shutdown No further actions are required. I i 1 e ___

Page 13 CCNPP LICENSED OPERATOR t JOB PERFORMANCE MEASURE OI-21A 2M TASK: 0205202 % Parallel a bus feeder with 4 KV bus carried by a Diesel Generator NOTES: i

   }
   \

The operator's performance was evaluated against the standards contained in this JPM and determined to be SATISFACTORY UNSATISFACTORY EVALUATOR'S SIGNATURE: DATE:

Page 14 CCNPP LICENSED OPERATOR ( JOB PERFORMANCE MEASURE OI 21 A-2M TASK: 020520206 Parallel a bus feeder with 4 KV bus carried by a Diesel Generator SIMULATORJNST7UCTIONS IC - l l 1. llave CEA 3510 inches lower than remaining CEAs in GROUP 5.

2. 1 A Diesel Generator is supplying power to 4 KV bus 11, and 4 KV bus 11 feeder breakers 152-1115 and 152-1101 are open.

l

3. Unit 1 is in Mode 2,11 SGFP operating and 12 SGFP in standby. .

                                                                                                         . .,_    ,   j i s j . - -.

Crivert Cliffs Ncclear P=/er Plant > JPM Questi:s (a) Title Electrical AC / Transfer 11/17 4KV Bus K/A 062000K102 [4.1/4.4) Question a: Following a Loss of Off Site Power during Mode 5 operations, why is the 1 A diesel preferred over the OC Diesel to supply power? Answer The OC diesel must be manually started and has a pre-labe pump that should be run for 5 min. prior to starting. The l A diesel should receive an auto start signal and load on an undervoltage. (If 07 or 17 Bus has been deenergized for greater than 5 minutes, the pneumatic pump must be used for pre lube). , Reference Use Allowed? Reference 1 AOP-3F design basis document pg.18 Rev.3 Reference 2 Comments: I I Satisfactory l lUnsatisfactory Candidate l D of 14 JPM #2 Question (a) Electrical AC Transfer l Revised 10/17/97!0!!6/97

Calvert Cliffs Nrclear Power Plant JPM Question (bi Title Electrical AC / Transfer 11/17 4KV Bus K/A 064000G112 [2.9/4.0] Question b: Given the following information concerning Fuel Oil tanks for the Unit 1 Emergency Diesel Generators: IAb'E LEVEL IA DG Fuel Oil Day Tank 23 inches IB DG Fuel Oil Day Tank 26 inches 1 A Fuel Oil Storage Tsnk 18' 1" ' 11 Fuel Oil Storage Tank 6' 5" 21 Fuel Oil Storage Tank 17'0" A truck comaining 8,000 gallons of fuel oil hasjust unloaded to the 11 Fuel Oil Storage Tank. y (Chemistry testing is satisfactory.) l' Evaluate the OPERABILITY of the Diesel Generators and any ACTIONS required l Answer (The 11 Fuel oil tank has met the OPERABILITY requirements with the addition of the fuel oil.) Emergency DGs should be operable provided ACTIONS below met. The ACTION now requires :

1. Demonstrate the operability of the other Fuel Oil Storage Tank within I hour AND

2. Verify the flow path from the operable Fuel Oil Storage Tank (11) to the IB Emergency Diesel Generator within I hour .

Reference Use Allowed? YES Reference 11 Calvert Cliffs - Unit 1 Technical Specification 3.8.1.1, Amcndment 214, pages 3/4 8-1 to 3/4 8-5. Action h. I' l Satisfactory l l Unsatisfactory Candidate 9 of 9 l JPM #2 Question (b) Electrical ACTransfer l Revised 10/17/9740/%f97

1, ,, 3',- CCNPP LICENSED OPERATOR JOB FERFORMANCE MEASURE OI-12A XX SYSTEM: Main Feedwater TASK: [02032016] Stroking a main feed reg valve PURPOSE: Evaluates an Operator's ability to manually stroke main feed reg valve JOB PERFORMANCE MEASURE CALVERT CLIFFS NUCLEAR POWER PLANT u LICENSED OPERATOR TRAINING $ PREPARED BY: DATE: REVIE MED BY: DATE: Operations Instructor - Nuc

    .-      REVIEWED BY:                                                   DATE:

SRO License Holder APPROVED BY: DATE: Ops Training Supervisor Rev.0 g ._. . ,

.                                                                                                               Page 2 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE OI-12A-XX TASK:         [020320106] Stroking a main feed reg valve                                                             ,

PERFORMER'S NAME: ,_ APPLICABILITY: RO and SRO PREREQUISITES: Completion of the knowledge requirement of the Initial License class training program for the Main Feedwater System. EVALUATION LOCATION: PLANT __,X_ SIMULATOR CONTROL ROOM EVALUATION METHOD: ACTUAL PERFORMANCE DEMONSTRATE PERFORMANCE

    , ESTIMATED TIME             ACTUAL TIME                                               TIME CRITICAL TASK:

TO COMPLETE JPM: TO COMPLETE JPM: XX MINUTES MINUTES NO _To be velidated TASK LEVEL: i TRAIN TOOLS AND EQUIPMENT: m- r news None 85$i E "'d-REFERENCE PROCEDURE (S): OI-12A TASK STANDARDS: This JPM is complete when the feed water control has been returned to AUTO. REV 0 _ J

0 Page 3 CCNPP LICENSED OPERATOR , , JOB PERFORMANCE MEASURE OI-12A-XX TASK: [020320106] Stroking a main feed reg valve DIRECTIONS TO EVALUATOR:

1. Read the " Directions to Trainee" to the trainee.

2. Note the time that the task is started. As the task proceeds, indicate completion of each element using the Standard criteria and the following notation:

                  "S" for satisfactory completion U" for unsatisfactory completion "N" if not observed OR not verifiable Critical elements must be observed or the evaluation is invalid.

3. When the Terminating Cue is reached, tell the trainee that no further actions are necessary. Note the completion time.

4. Document any instanccs ofincorrect performance in the Notes area (required for i critical steps).

t Questions should be asked after completion of the task. t

6. Indicate whether the task was completed satisfactorily on the basis of correct performance of all critical elements and completion of the task within the Estimated Time to Complete for Time Critical tasks.

7. This JPM contains the steps, notes, cautions, and standards that are applicable to the initial conditions specified in this JPM. Steps that do not directly relate to this JPM, but appear in the procedure, are not listed here. It is the responsib;1ity of the evaluator and/or observer to become familiar with the procedure prior to use of this JPM.

REV 0

 ,                                                                                                      Page 4 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE OI 12A-XX TASK:            [020320106] Stroking a main feed reg valve JPM STANDARDS (List of minimum Standard Practices for common evolutions at CCNPP) 1.0    Starting a pump If non emergency ce ndition, dispatches a PO to verify pump is ready to be started.

Identify the Control C,w.tch and Indicating Lights, usmg authorized identification. Operate the Control Switch, to START, and check expected Indicating Light respcnse. Check proper pump operation (as applicable):

            -        Motor amps Pump discharge pressure System now Activation / Clearing of applicable Annunciators (e.g.; Hi Disch Press, Lo Hdr Press) 2.0    Stopping a pump

, Identify the Control Switch and Indicating Lights, using authorized identification. Operate the Control Switch, to STOP, and check expected Indicating Light response. Check expected system respons:(e g ; Cow, pressure, level) 3.0 Operating Coi. trol Valves / Motor Operated Valves / Circuit Breakers identify the Control Switch and Indicating Lights, using autnorized identification. Select the Control Switch to the desired position. Check Valve / Breaker position, using position Indicating Lights. Check expected system response (e.g.: How, pressure, level, volts, amps, KW) 4.0 Checking Valve / Breaker position Identify the Valve / Breaker Indicating Lights, using authorized identification. Check the Valve / Breaker is in the correct position. if Valve / Breaker is not in correct position, report Valve / Breaker position to CRS. 5.0 Verifying valve / breaker position Identify the Valve / Breaker Indicating Lights, using authorized idenufication. Check the Valve / Breaker is in the correct position. If Valve / Breaker is not in correct position, operates Valve / Breaker to correct position. 6.0 Locally starting a pump Verify the following: Suction Valve open Discharge Valve position (as applicable) Mininow Valve position (as applicable) Pump and Motor oil levels are normal Adequate Suction Pressure REV 0 l l l J

 ,                                                                                                          Page$

CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE OI-12A-XX TASK: [020320106) Stroking a tnain feed reg valve 6.0 Locally starting a pump (cont'd) Identify the Control Switch and Indicating Lights, using authorized identi fication. Operate the Control Switch, to SYART, and check expected Indicating Light response. Check for proper Pump operation (as applicable): Smooth, quiet operation consistent with pump history Oil level remains good Proper seal leakoff Proper discharge pressure Expected system Cow 7.0 Locally stopping a pump identify the Control Switch and Indicating Lig*os, using authorized identification. Operate the Control Switch, to STOP, and check expected Indicating Light response. Check expected system response (e.g.; How, pressure, level). s 8.0 Operating a Manual Valve identify the Valve, using authorized identincation. l Operate the Valve and check expected position indication change (e.g.; stem rise, pointer).

     ,         Check expected System response (e.g.; Guid How sounds, pressure changes, tank levels),

i 9.0 Locally operating Control Valves / Motor Operated Valves / Circuit Breakers identify the Control Switch and Indicating Lights (if apolicable), using authorized identification. Operate the Control Switch and check expected Indicating Light response. Check expected SysteG response (e.g.; How, pressure, levels, volts, amps). 10.0 Locally checking Valve / Breaker position Identify the Valve / Breaker, using authorized identification. Check the Valve / Breaker is in the correct position, using appropriate position indication (e.g.: pointer, stem rise, Dags, indicating lights). If Valve / Breaker is not in correct position, report Valve / Breaker position to Control Room i1.0 Locally verifying Valve / Breaker position Identify the Valve / Breaker, using suthorized identification. Check the Valve / Breaker is in the correct position, using appropriate position indication (e.g.: pointer, stem rise, Dags, indicating lights). If Valve / Breaker is not in correct position, operates Valve / Breaker to correct position. t REV 0

 ,                                                                                             Page 6 CCNPP LICENSED OPERATOR i

JOB PERFORMANCE MEASURE OI-12A-XX TASK: [020320106) Stroking a main feed reg valve DIRECTIONS TO TRAINEE:

1. To complete the task successfully, you must perform each critical element correctly. Yen must inform the evaluator of the indication; you are monitoring.

Where necessary, consider the evaluator to be the CRS.

2. Initial Conditions:

a. Unit 1 is in Mode 2.

b. The Feed and Condensate System is in operation,

c. The Main Turbine is RESET.

d. I1 SGFP operating and 12 SGFP in standby.

c. The FBV are controlling S/O levels.

c. You are performing the dutics of Unit 1 dedicated feed station operator, s

3. Task Standard:

l k This JPM main feed is cotafve havc been completed.lete when actions taken in accor reg va

4. Initiating Cue:

The CRS has directed you to perform stroking i 1 main feed reg valve in accordance with OI-12A Section 6.26. Are there any questions? You may begin, i REV O

    <a                         >

Pege 7 CCNPP LICENSED OPERATOR 4 JOB PERFORMANCE MEASURE OI-12A-XX ELEMENT STANDARD (* = CRITICAL STEP) TIME START 6.26 Stroking The Main Feed REG Valve (Continuous Usel B. Procedure CAUTION in Mode 2, this is a trip sensitive procedure. Failure to closely monitor S/G levels while all feed ' ' controls are in MANUAL and stroking the FRV can cause an :<ematic reactor trip DRESFAS actuation. 1

1 PLACE the controllers for all running SGFPs Operator places the controllers in in HlC MANUAL or OCS MANUAL one of the modes.

Final position is:(check one) { __ HIC MANUAL OCS MANUAL __2 IE the FBVs are controlling S/G levels, Iritial conditions - FBV are THEN- controlling levels a VERIFY that both FBV controllers are in MANUAL. b OPERATE the FBV(s) to maintain S/G level Operator maintains level band durir:e between plus 30 inches and minus 24 inches. entire task. 3 IE the Condensate System is in operation, Given initial conditions THEN: a COMPLETE ONE of the following:

ISOLATE the desired FPd: Initial conditions Sted 11 SGFP in 3

operation.

To isolate FRV,1-FW-1111-CV, SHUT l-FW-131. Directs plant Operator to shut 1-FW-131.

To isolate FRV,1-FW-1121-CV, SHUT l-FW-128. t RSV 0

 ,                                                                                                                     Page 8 CCNPP LICENSED OPERATOR
   ,                             JOB PERFORMANCE MEASURE OI-12A-XX ELEMENT                                                          STANDARD

(* = CRITICAL STEP) DR CAUTION Shutting the S/G FW Isolation MOV will secure feed flow to the affecte.j S/G AND the operator will NOI be able to control S/G level for the affected S/G with the FBV.

SIIUT the S/G lsolation Valve for the desired header: Operator shuts 1IS/G FW Isolation

                           =   11 S/G FW lsolation,1-FW-4516-

valve.

l . MOV.

                           =   12 S/G FW lsolation,1-FW-4517-MOV.                                                                                           '

b COMPLETE the following while stroking l the FRV:

MONITOR S/G levels. Operator maintains level in the band.

ADJUST FBV as necessary.

ADJUST SGFP speed as necessary

IE necessary, THEN: Operator opens the FW lsolation (1) VERIFY the FBV is SHUT valve. (2) OPEN the FW Isolation Valve.

4 STROKE the appropriate FRV as required. Operator strokes the 1IFRV 5 IE desired NOT desired!

THEN REPEAT Steps 3 and 4 as required. 6 WHEN ;troking the FRV is no longer Stroking is complete, required, THEN-a VERIFY the FRV is SM f REV 0

   ,                                                                                                                              Page 9 CCNPP LICENSED OPERATOR JOB '. RFORMANCE MEASURE OI-12A-XX t

ELEMENT STANDARD (* = CRITICAL STEP) b E_ Condensate System is in operation, THEN Given in the initial conditions. OPEN the FRV lsolation valve or S/G isolation MOV that was shut in Step 3. = Operator Opens 1 FW-4516-MOV.

                  '  c E it is EQIdesired to lean the Main                                        it is not desired to leave the main Turbine RESET, THEN PE! WORM the                                          turbine RESET.

following as necessary;

Ejumpers were irutafled on the Main Not installed Turbine trip bgic to diow strcking the FRVs, THEN HAVE thejumpers removed. l

DEPRESS the Main Turbine Trip Operator depress the Trip pushbutton pushbutton.

RESET the FBVs.

d E desired, k' It is desired for the controller to be returned to AUTO.

THEN PLACE the FBV Controllers in AUTO.

e E desired, It is desired for the controller to be returned to AUTO.

THEN PLACE the running SGFP controller (s)in AUTO. TIME STOP TERMINATING CUE: This JPM is complete when the feed water control has been returned to AUTO. 4 REV 0

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

P:ge 10 CCNPP LICENSED OPERATOR , 1 JOB PERFORMANCE MEASURE OI-12A XX i TASK: [020320106] l

!                                                                                     NOTES:

i i

           .l i

The operator's xrformance was evaluated against the standards contained in this JPM and deterndnec to be i j_ l SATISFACTORY l l UNSATISFACTORY 4 EVALUATOR'S SIGNATURE: DATE: i

REV 0 h

C:lvert Cliffs Ntele:r Prier Plant JPM Questi:n (a) Title Main Feedwater K/A 059000K405 [2 5/2/81 Question a: When shifting Main Feed Pump from Aux. Steam to Main Steam, why is the Aux. Steam supply valve closed SLOWLY after the Main Steam supply valve is fully opened? Answer: The Aux. Steam supply valve is closed slowly to allow time for the governor valve to respond to the changing steam flow. Reference Use Allowed? Reference 1 OI-12A pg. 84&85 l l Reference 2 LER 318-95-003 k Comments: I l Satisfactory l IUnsatisfactory Candidate t l of 2 JPM #3 Question (a) Main Feedwater Revised 10/17/97

                                                                                                            . _ _ _ _ _ .         ------   _J

Calvert Cliffs Nuclear P:wer Flant JPM Ques (12:2 (b) Title Main Feedwater K/A 059000A211 [3.0/3/3) Question b: The PDI indication screen indicates as shown the accompanying drawing. What is tb statuvfailure mode of the Main Feed Valve controller? Answer: A Main Feed Valve controller output failure has occurred. Reference Use Allowed? Reference 1 : CRO-103-1-5; OH-15b; LO-1.9 Reference 2 Comments: I 1 I I l l Satisfactory l l Unsatisfactory Candidate

2 of 2 JPM #3 Question (b) Main Feedwater Revised 10/17/97

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O :. CCNPP LICENSED OPERATOR . JOB PERFORMANCE MEASURE EOP-8-1N SYSTEM: Containment Spray TASK: 020010414 CSAS Verification PURPOSE: Evaluates an Operator's Ability to Perform the Actions Associated With Containment Environment Success Path CE-3: Comainment Spray JOB PERFORMANCE MEASURE CALVERT CLIFFS NUCLEAR POWER PLANT LICENSED OPERATOR TRAINING 1 PREPARED BY: DATE: REVIEWED BY: DATE: Operations Instructor- Nuc REVIEWED BY: DATE: SRO License Holder APPROVED BY: DATE: Ops Training Supervisor Rev.O

                                                                      .__..m.         . . - _ _ _ . _ _ _ . - . . _ _ . . - _
 ..                                                                                                   Page 2 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE EOP-8-IN I

TASK: 020010414 CSAS Verification. I .] i PERFORMER'S NAME: APPLICABILITY: ! ' l RO and SRO PREREQUISITES: Completion of the knowledge requirement of the Initial License class training program for Containment. EVALUATION LOCATION: 4 PLANT SIMULATOR CONTROL ROOM EVALUATION METHOD:

                   , ACTUAL PERFORMANCE                   DEMONSTRATE PERFORMANCE ESTIMATED TIME              ACTUAL TIME                   TIME CRITICAL TASK:

TO COMPLETE JPM: TO COMPLETE JPM:

1 10 MINUTES MINUTES NO TASK LEVEL: TRAIN TOOLS AND EQUIPMENT: None REFERENCE PROCEDURE (S): EOP-8, Appendix (5), Success Path CE-3 EOP Attachment (3) TASK STANDARDS: This JPM is complete when the O c . Verification Checklist of Success Path CE-3: Containment Spray is performed ano status reported to the CRS. i

~

 ,.                                                                                                         Page 3 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE EOP-81N TASK:       020010414       CSAS Verification.

DIP.ECTIONS TO EVALUATOR:

1. Read the " Directions to Trainee" to the trainee.

2. Note the time that the tr.sk is started. As the task proceeds, indicate completion of each element using the Standard criteria and the following notation: ,

                    "S" for satisfactory completion                                                                    )
                 - U" for unsatisfactory completion "N"if not observed OR not verifiable Critical elements must be observed or the evaluation is invalid.

3. When the Terminating Cue is reached, tell the trainee that no further actions are necessary. Note the completion time.

4. Document any instances ofincorrect performance in the Notes area (required for ,

critical steps).

5. Questions should be asked after completion of the task.

6. Indicate whether the task was completed satisfactorily on the basis of correct xrformance of all critical elements and completion of the task within the istimated Time to Complete for Time Critical tasks.

7. This JPM contains the steps, notes, cautions, and standards that are applicable to the initial conditions specified in this JPM. Steps that do not directly relate to this JPM, but appear in the procedure, are not listed here. It is the responsibility of the evaluator and/or observer to become familiar with the procedure prior to use of this JPM.

                  ,                                                                                                                                Page 4 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE EOP-8 IN TASK:                                    020010414                               CSAS Verification.

JPM STANDARDS (List of minimum Standard Practices for common evolutions at CCNPP) 1.0 Starting, a pump s if non-emergency condition, dispatches a PO to verify pump is reaoy to be started. Identify the Control Switch and Indicating Lights, using authorized identification.

 =                            Operate the Control Switch, to START, and check expected Indicating Light response.

Check proper pump operation (as applicable): Motor amps Pump discharge pressure System flow Activation / Clearing of applicable Annunciators (e.g.; Hi Disch Press, Lo Hdr Press) 2.0 Stoppin; a pump Identify the Control Switch and Indicating Lights, using authorized identification. Operate the Control Switch, to STOP, and check expected Indicating Light response. Cl.;ck expected system response (e.g.: flow, pressure, level) 3.0 Operating Control Valves / Motor Operated Valves / Circuit Breakers Identify the Control Switch and Indicating Lights, using authorized identification. Select the Control Switch to the desired position. Check Valve / Breaker position, using position Indicating Lights. Cneck expected system response (e.g.; flow, pressure, level, volts, amps, KW) 4.0 Checking Valve / Breaker positior identify the Valve / Breaker Indicating Lights, using authorized identification. Check the Valve / Breaker is in the correct position. If Valve / Breaker is not in correct position, report Valve / Breaker position to CRS. 5.0 Verifying valve / breaker position Identify the Valve / Breaker Indicating Lights, using authorized identification. Check the Valve / Breaker is in the correct position. If Valve / Breaker is not in correct position, operates Valve / Breaker to correct position. 6.0 Locally starting a pump Verify the following: Suction Valve open Discharge Valve position (as applicable) Miniflow Valve position (as applicable) Pump and Motor oil levels are normal Adequate Suction Pressure identify the Control Switch and Indicatmg Lights, using authorized identification.

Page 5 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE EOP-81N TASK: 020010414 CSAS Verification. Operate the Control Switch, to START, and check expected Indicating Light response. Check for proper Pump operation (as applicable): Smooth, quiet operation consistent with pump history

                 -        Oillevel remains good
                 -        Proper sealleakaff Proper discharge pressure Expected system flow 7.0   Locally stopping a pump Identify the Control Switch and Indicating Lights, using authorized c.ification.

Operate the Control Switch, to STOP, and check expected Indicating Light response. Check expected system response (e.g.; flow, pressure, level). 8.0 Operating a Manual Valve identify the Valve, using authorized identification. ' Operate the Valve aad check expected position indication change (e.g.; stem sise, pointer). Check expected System response (e.g. fluid flow sounds, pressure changes, tank levels). 9.0 Locally operating Control Valves / Motor Operated Valves / Circuit Breakers I ldentify the Control Switch and Indicating Lights (if applicable), using authorized identification. I Operate the Control Switch and check expected Indicatmg Light response. Check expected System response (e.g.; How, pressure, levels, volts, amps). 10.0 Locally checking Valve / Breaker position identify the Valve / Breaker, using authorized identification. Check the Valve / Breaker is in the correct position. using appropriate position indication (e.g.; pointer, stem rise, flags, indicating lights). If Valve / Breaker is not in correct position, report Valve / Breaker position to Control Room, 11.0 Locally vtriNm Valve / Breaker position identify the Valve / Breaker, using authorized identification. Check the Valve / Breaker is in the correct position, using appropriate position indication (e.g.; pointer, stem rise, flags, indicating lights). If Valve / Breaker is not in correct position, operates Valve / Breaker 20 correct position. l

   ,                                                                                                                             Page 6 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE EOP-8 IN TASK:       020010414       CSAS Verification.

DIREC fl0NS TO TRAINEE:

1. To complete the task successfully, you must perform each critical element correctly. You must inform the evaluator of the indications you are monitoring.

Where necessary, consider the evaluator to be the CRS.

2. Initial Conditions:

a. A reactor trip and SIAS actuation has occurred on Unit 1.

b. Currently EOP-8 is being performed and Success Path CE-3: Containment Spray has been id. ntified as the appropriate Functional Restoration path.

i b. You are performing the duties of the CRO.

3. Task Standard: This JPM is complete when the CSAS Verification Checklist, as path of Success Path CE-3, is performed and appropriate report made to the CRS.

4. Initiating Cue: The CRS directs you to perform the actions of Success Path CE-3:

Containment Spray. Are there any questions? You may begin.

 -                                                                                                                Page 7 CCNPP LICENSED OPERATOR                                    ^

JOB PERFORMANCE MEASURE EOP-8-1N ( ELEMENT STANDARD (* = CRITICAL STE? TIME START implements CE-3. Identifies and locates EOP-8, Appendix (5), Success Path CE-3 Containment Spray. A. ESTABLISH CONTAINMENT ENVIRONMENT BY CONTAINMENT SPRAY, CUE: When checked or asked: ALL available Containment Air Coolers are operating with SWR 8" CAC EMERGENCY OUT valves open (Red light on, Green light off).

1. Verify ALL available CACs are o xrating Checks all four containment air with their SRW 8 inch CAC EMERGENCY coolers on 1C09/10 to determine OUT valves open, that all available coolers are operating.

Checks valve indication on 1C10

     ,                                                                             and places the valves in open.

2. IF containment pressure exceeds 2.8 PSIG, THEN verify ESFAS actuation of the following:

CUE: When checked c asked: SIAS has actuated. (SIAS alarm actuated,11 & 13 HPSI pumps are operating and HPSI header valves are open; LPSI and CS Pumps are running.)

               . SIAS                                                          Determines that SlAS has actuated by the required               >

components by checking the annunciator, HPSI pump.9 and valves. CUE: When checked or asked: CIS has actuated. CIS alarm " ACTUATION SYS CIS TRIPPED" has actuated, CCW isolations to containment are shut.

CIS Checks CIS alarm " ACTUATION SYS CIS TRIPPED" has actuated, and Containment CCW isolation valves are shut.

Page 8 9 CCNPP LICENSED OPERATOR

 ,                               JOB PERFORMANCE MEASUR2 EOP-8-IN ELEMENT                                                    STANDARD

(' = CRITICAL STEP) CUE: When performed or asked: RCPs are tripped (Red light off, Green light on).

3. IF CIS has actuated, Verifies all RCPs tripped at IC06.

THEN trip ALL RCPs. CUE: When directed to check SRW Pump Room Ventilation, acknowledge and report ventilation is aligned per 01-15.

4. Verify the SRW Pump Room Ventilation is Directs operator to locally verify in service PER the SRW PUMP ROOM operation of SRW Pump Room: VENTILATION section of 01-15 Ventilation per 01 15.

CUE: When checked or asked: CSAS has NOT actuated. CSAS alarm " ACTUATION SYS CSAS TRIPPED" is NOT lit, Containment Spray pumps are operating (Green light off, Red light on with normal running amps) and spray discharge valves are SHUT (Green light on, Red light off).

5. IF containment pressure exceeds 4.25 PSIG, Checks CSAS actuated by CSAS THEN verify CSAS actuation and spray alarm " ACTUATION SYS CSAS flow is approximately 1350 GPM per pump TRIPPED" actuated, Containment by flowindicators: Spray pumps operating, spray discharge valves open and spray header flow is hpproximately 1350 gpm per header.

Determines CSAS NOT actuated. CUE: When checked or asked: Spray flow is ZERO. (11 CS HDR FLOW) 1-FI-4148 Determines NO flowin 1I spray header. CUE: When checked or asked: Spray flow is ZERO. (12 CS HDR FLOW) 1-F1-4149 Determines NO flow in 12 spray header. MsI ^

 ,                                                                                                                 Page 9 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE EOP-8-IN ELEMENT                                                                           STANDARD

(' = CRITICAL STEP) NOTE TO EVALUA TOR: Actions in step A.6 ** ATTACHMENT (2), S1AS VERIFCATION CHECKI IST" willNOT be performed because ofthese actions would have been performed earlier and are NOT germane to the JPMtask. The report of taking Alternate Actions can be made at the discretion of the operator but should be reported as soon as practical NOTE HPSI and LPSI throttle / termination will affect the system lineup in the checklists used in the following step. l CAUTION To prevent uncontrolled system restoration, handswitches should be matched to the checklist positions unless specified otherwise.

   ;          6.               Verify ESFAS equipment is aligned correctly, AND handswitches are matched PER the following checklisi; as appropriate:

CUE: When Attachment (2), SIAS VERIFICATION CHECKLIST is identified: ATTACHMENT (2) was just performed for the prior Safety Function and need NOT be performed again, e ATTACHMENT (2), SIAS VERIFICATION Checks for ATTACHMENT (2) CHECKLIST performance. CUE: When Attachment (3), CSAS VERIFICATION CHECKLIST is identified: ATTACHMENT (3) is to be performed by you, e ATTACHMENT (3), CSAS Locates ATTACHMENT (2), VERIFIC ATION CHECKLIST, CSAS VERIFICATION CHECKI IST.

 .                                                                                                        Page 10 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE EOP-8-1N t

ELEMENT STANDARD (* = CRITICAL STEP) 1CO3 CUE: When checked or asked: 11 and 12 MSIVs are shut (Green light on, Red light off).

a. I1 and 12 MSIVs: Determines that BOTH MSIVs are closed AND places control

                                   .       1-MS-4043-CV                        switch for each MSIV to the SHUT position.

1-MS-4048 CV CUE: When checked or asked: 11 and 12 SG FW ISOL valves are shut (Green light on, Red light off).

b. I1 and 12 SG FW ISOL valves:

Determines that BOTH SG FW ISOL valves are closed AND e 1-FW-4516-MOV places control switch for each l l valve to the SHUT position, e 1-FW-4517 MOV CUE: When checked or asked: 11 and 12 SG B/D valves are shut (Green light on, Red light off). t c. I1 and 12 SG B/D valves: Determines that all FOUR SG B/D valves are closed. f

l-BD-4010-CV e 1-BD-40ll-CV e 1-BD-4012-CV e 1-BD-4013-CV CUE: When checked or asked: 11 and 12 SOFPT TRIP RESET indicates tripped (White light on, Red light off), SOFP Turbine low pressure and high pressure stop valves closed (Green light on, Red light off), and SGFP TURBINE STOP VALVES TRIPPED alarms actuated (C-26 &C-30 lit).

d. I1 and 12 SGFP TRIP RESET Determines that BOTH SGFPs are tripped.

i

   ,                                                                                                                       Page11 CCNPP LICENSED OPERATOR t

JOB PERFORMANCE MEASURE EOP-8-IN ELEMENT STANDARD (* = CRITICAL STEP) CUE: When checked or asked: 11 and 12 Heater Drain Pumps valves are stopped (Green light on, Red light off),

e. 11 and 12 HTR DRN PPs. Determines that BOTH HTR DRN pumps are stopped.

CUE: When checked or asked: 11,12 and 13 Condensate Booster Pumps are stopped (Green light on, Red light off).

f. I1,12 and 13 COND BSTR PPs Determines that the THREE COND BSTR pumps are stopped.

1CO8.1C09 CUE: When checked or asked: 1-SI-4150-CV is shut (Green light on, Red light off); l-SI-l 4 4151-CV is shut (Green light on, Red light off). CUE: When operation indicated: 1-SI-4150-CV indicates open (Green light off, Red light on); i 1-SI-4151-CV indicates open (Green light off, Red light on).

a. 2 CS HDR control valves: Determines that BOTH CS Header valves are closed e 1-SI-4150-CV AND e- 1-SI-4151-CV Places control switch for each valve to the OPEN position.

1CO3 CUE: When checked or asked: Service Water Supply to 12 Blow Down Heat Exchanger is shut (Green light on, Red light off).

a. SRW SUPP to 12 BD HX,1-SRW-1640-CV Determines that 1 SRW-1640-CV is shut.

1

Page 12 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE EOP-8 IN 1 ELEMENT STANDARD (* = CRITICAL STEP) CUE: When checked or asked: 11 Spent Fuel Pool Heat Exenanger Service Water inlet and Outlet valves are shut (Green light on, Red light off).

b. I1 SFP HX SRW INIJOUT valves: Determines that BOTH SFP HX SRW INIJOUT valves are closed.

1-SRW-1597 CV
l SRW 1596-CV i

TIME STOP TERMINATING CUE: The JPM is complete when the CRS is informed of the status of the CSAS Verification Checklist. No further actions are required. i i

                                                                                                                                           ._______J

Page 13 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE EOP 8 IN TASK: 020010414 CSAS Verification. NOTES: NOTE TO EVALUATOR: The report of taking Alternate Actions can be made at the discretion of the operator but should be reported as soon as practical. i The operator's wrformance was evaluated against the standards contained in this JPM and determinec to be SATISFACTORY UNSATISFACTORY EVALUATOR'S SIGNATURE: DATE:

Calvert Cliffs Nrclear Pc,wer Plant JPM Questi:a (a) Title i Conuinment Spray K/A 026000G132 [3.4/3/8] Question a: liow is valve operability assured in safety related MOVs associated with the contalement emergency sump following an accident and prior to RAS. Answer: A procedure is performed that fills the containment sump piping to provide a thermal barrier to prevent valve heatup following an accident. Reference Use Allowed? Reference 1 OI-3A - Basis pg.62 Rev.3 Reference 2 I, Comments: l l l l Satisfactory l l Unsatisfactory Candidate 1 of 2 JPM #4 Question (a) Containment Spray Revised 10/17/97

Calvert Cliffs Nuclear P;wer PI nt JPM Qresti:s (b) Titie l Containment Spray K/A 026000G409 [3.3ra,9] Question b: When aligning Containment Spray Pumps for SDC, what is the purpose of the following limits? RCS pressure <l70 psia

   -  RCS temperature <120 F Answer:

RCS pressure <l70 - prevent overpressurizing ECCS pump suction headers to the spray pumps. RCS temperature <l20 F - prevent overheating spray pump motor bearing. Reference Use Allowed? k Reference 1 CRO-7-1-8, Pg 78. LOl6.8 ATT. 3 Reference 2 AOP-3B pg.21 Rev. 3 Comments: R l l l I Satisfactory l l Unsatisfactory Candidate 2 0f 2 JPM #4 Question (b) Containment Spray Revised 10/17/97

CCNPP LICENSED OPERATOR o JOB PERFORMANCE MEASURE 0135 SYSTEM: Radiation Monitoring TASK: Respond to UNIT 1 ECCS PP RM VENT alarm PURPOSE: Evaluates Operator's Ability to respond to Radiation Alarm JOB PERFORMANCE MEASURE CALVERT CLIFFS NUCLEAR i'OWER PLANT LICENSED OPERATOR TRAINING PREPARED BY: DATE: REVIEWED BY: DATE: Operations Instructor - Nuc REVIEWED BY: DATE: SRO License Holder APPROVED BY: DATE: Ops Training Supervisor i Rev.O

Page 2 CCNPP LICENSED OPERATOR

,,                                            JOB PERFORMANCE MEASURE OI 35-XX TASK:                      Respond to UNIT 1 ECCS PP RM VENT alarm PERFORMER'S NAME:

l APPLICABILITY: RO and SRO , PREREQUISITES: Completion of the knowledge requirement of the Initial License class training program for the --- i TVALUATION LOCATION: PLANT _X_ SIMULATOR CONTROL ROO,M EVALUATION METliOD:

                                  /.CTUAL PERFORMANCE                                  DEMONSTRATE PERFORMANCE
       /        ESTIMATED TIME                    ACTUAL TIME                                  TIME CRITICAL TASK:

4- TO COMPLETE JPM: TO COMPLETE JPM: MINUTES MINUTES NO TASK LEVEL: TRAIN TOOLS AND EQUIPMENT: None REFERENCE PROCEDURE (S): 1C22-ALM (WINDOW B-5.1)

              . TASK STANDARDS:

This JPM is complete when the alarm has been determined to be valid & Chemistry has been requested to determine RCS activity, 1 REV O , j

Page 3 CCNPP LICENSED OPERATOR 1 JOB PERFORMANCE MEASURE 0135 TASK: Respond to UNIT 1 ECCS PP RM VENT alarm DIRECTIONS TO EVALUATOR:

1. Read the " Directions to Trainee" to the trainee.

2. Note the time that the task is started. As the task proceeds, indicate completion of each element using the Standard criteria and the following notation:

                   "S" for satisfactory completion "U" for unsatisfactory completion l

l - N" if not observed OR not verifiable Critical elements must be observed or the evaluation is invalid.

3. When the Terminating Cue is reached, tell the trainee that no further actions are necessary. Note the completion time.

! 4. ' Document any instances ofincorrect performance in the Notes area (required for critical steps).

    ,       S. Questions should be asked after completion of the task.

6. Indicate whether the task was completed satisfactorily on the basis of correct xrformance of all critical elements and completion of the task within the istimated Time to Complete for Time Critical tasks.

7. This JPM contains the steps, notes, cautions, and standards that are applicable to the initial conditions specified in this JPM. Steps that do not directly relate to this JPM, but appear in the procedure, are not listed here, it is the responsibility of the evaluator and/or observer to become familiar with the procedure prior to use of this JPM.

REV 0

.                                                                                                      Page 4 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE OI 35-XX TASK:                    Respond to UNIT 1 ECCS PP RM VENT alarm JPM STANDARDS (List of minimum Standard Practices for common evolutions at CCNPP) 1.0   Starting a pump if non emergency condition, dispatches a PO to verify pump is ready to be started.

Identify the Control Switch and Indicating Lights, usmg authorized identification. Operate the Control Switch, to START, and check expected Indicating Light response. Check proper pump operation (as applicable): Motor amps Pump d scharge pressure

          -         System How Activation / Clearing of applicable Annunciators (e.g.; Hi Disch Press, Lc Hdr Press) 2.0   Stopping a pump identify the Control Switch and Indicating Lights, using authorized identification.

Operate the Control Switch, to STOP, and check expected Indicating Light response. Check expected system response (e.g.; Gow, pressure, leve!) 3.0 Operating Control Valves / Motor Operated Valves / Circuit Breaken 1 Identify the Control Switch and Indicating Lights, using authorized identification. Select the Control Switch to the desired position. Check Valve / Breaker position, using position Indicating Lights. Check expected system response (e.g.; flow, pressure, level, volts, amps, KW) f 4.0 Checking Valve / Breaker position Identify the Valve / Breaker Indicating Lights, using authorized identification. Check the Valve / Breaker is in the correct position. If Valve / Breaker is not in correct position, report Valve / Breaker position to CRS. 5.0 Verifying valve / breaker position Identify the Valve / Breaker Indicating Lights, using authorized identification. Check the Valve / Breaker is in the correct position. If Valve / Breaker is not in correct position, operates Valve / Breaker to correct position. 6.0 Locally starting a pump Verify the following: Suction Valve open Discharge Valve position (as applicable) Miniflow Valve position (as applicable) Pump and Motor oil levels are normal Adequate Suction Pressure REV O s

Page5 CCNPP LICENSED OPERATOR i JOB PERFORMANCE MEASURE 0135 TASK: Respond to UNIT 1 ECCS PP RM VENT alarm 6.0 Local y starting a pump (cont'd) Identify the Control Switch and Indicating Lights, using authorized identification. Operate the Control Switch, to START, and check expected Indicating Light response, Check for proper Pump operation (as applicable): Smooth, quiet operation consistent with pump history Oillevel remains good Proper sect leakoff Proper discharge pressure Expected system Cow 7.0 Locally stopping a pump Identify the Control Switch and Indicating Lights, using authorized identification. Operate the Control Switch, to STOP, and check expected Indicating Light response. > Check expec' i system response (e.g.; flow, pressure, level). 8.0 Operating a Manual Valve i identify the Valve, using authorized identification. Operate the Valve and check expected position indication change (e.g.; stem rise, pointer).

      .       Check expected System response (e.g.; fluid flow sounds, pressure changes, tank levels).

i 9.0 Locally operating Control Valves / Motor Operated Valves / Circuit Breakers identify the Contral Switch and Indicating Lights (if applicable), using authorized identification, i ' Operate the Control Switch and check expected Indicatmg Light response. Check expected System response (e.g.: flow, pressure, levels, volts, amps). 10.0 Locally checking Valve /Bre ker position Identify the Valve / Breaker, using authorized identification. Check the Valve / Breaker is in the correct position, using appropriate position indication (e.g.; pointer, stem rise, flags, indicating lights). If Valve / Breaker is not in correct position, report Valve / Breaker position to Control Room. 11.0 Locally verifying Valve / Breaker position Identify the Valve / Breaker, using authorized identification. Check the Valve / Breaker is in the correct position, using appropriate position indication (e.g ; pointer, stem rise, flags, indicating lights). If Valve / Breaker is not in correct position, operates ValveE freaker to correct position. s REV 0 m

 -                                                                                                             Page 6' CCNPP LICENSED OPERATOR 1

JOB PERFORMANCE MEASURE OI-35-XX TASK: Respond to UNIT 1 ECCS PP RM VENT alarm DIRECTIONS TO TRAINEE:

1. To complete the task successfully, you must perform each critical element.

correctly. You must inform the evaluator of the indications you are monitoring. Where necessary, consider the evaluator to be the CRS.

2. Initial Conditions:

a. Unit 1 is in Mode 1 at 73 % power.

b. Pressurizer level trend is decreasing.

c. Containment vent is NOT in progress.

d. Containment Sump Drain Valves are OPEN.

c. You are performing the duties of Unit 1 CRO.

2. Task Standard:

This JPM is complete when Chemistry is requested to determine RCS activity.

3. Initiating Cue:

During Normal 31 ant o respond to the a arm. peration. Alarm 1C-22 B-5.1 is received. You are to Are there any questions? You may begin. REV 0

Pege 7 CCNPP LICENSED OPERATOR 4

  ,                           JOB PERFORMANCE MEASURE OI-35-XX ELEMENT                                          STANDARD

(* = CRITICAL STEP) TIME START POSSIBLE CAUSES 1 RCS leakage i High background at detector 1 1 Containment Normal Sump Drain Valves open 1 RMS failure l RCS Leakage ! 1 PERFORM the following:

     ,            IE a containnient vent is not in progress,               Initial conditions stated vent t'                                                                     was not in progress and the

a TilEN CHECK the Containment Normal Sump Containment Normal Sump Drain Valves are shut. Drain Valves are OPEN.

Operator is to check drain valves shut. Operator takes l handswitches to the CLOSE position and verifies the valves are shut. The indication for the salve position changes from Red to Green CUE Initially RED open light is lit for Containment Normal Sump valves. After operation, GREEN closed lights lit.

b PLACE the charcoal filter senice by placing ECC ^ Qperator places switch to PP RM EXH FILT,1-HS-5408 (IC34), to FlLTER. FILTER.

c IE the filter cannot be placed in senice,IIIEN Not applicable. STOP the fans. CUE If asked, the SS determines a significant deviation from normal conditions has occurred. REV 0

Page 8 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE OI 35-XX ( ELEMENT STANDARD (* = CRITICAL ST,EP)

d IE the RMS alarm is valid ABLn the Shill Operator determines alann Supervisor determines that a significant deviation to be valid. ( checks device from normal conditions has occurred, THEN: 1-RI 5406)

(1) EVACUATE the ECCS Pump Rooms. Operator orders rooms evacuated. (2) RECOMMEND Radiation Safety post area. Operator makes recommendation.

CUE The SS will evaluate ERPIP 3.0

l (3) REFER to ERPIP 3.0 for evaluation. Operator notes requirement j to evaluate ERPIP 3.0.. I CUE Chemistry personnel acknowledge request. l

                .e   IE sample analysis is required,111EN have                                                 Operator request additional Chemistry DETERMINE the RCS activity,                                                     analysis by Chemistry.

' i TIME STOP TERMINATING CUE: This JPM is complete when Chemistry is requested to determine RCS activity. 9 REV 0

Page 9

                                                                       - CCNPP LICENSED OPERATOR "i                                                  JOH PERFORMANCE MEASURE OI-35-XX TASK:-                   [ assign task noj              Respond to UNIT 1 ECCS PP RM VENT alarm i

i- NOTES: e i i' i 'I 1 l l l i

-i 3

The operator's xrformance was evaluated against the standards contained in this JPM i and determinec to be' l l SATISFACTORY _l l UNSATISFACTORY a-EVALUATOR'S SIGNATURE: DATE: 4 s REV 0

           +:"'e.  -.                            M  . Kgt. u _e a m..i.:.a m    .m        s6..-_ 4         m Calvert Cliffs N cle:r Prcier Platt JPM Q:estio3 (a) 1                                                       Title Process Rad Monitoring K/A 073000A403 l3.1/3.2l Question a:

The Wide Range Noble Gas Monitor (WRNGM) performs a "self check" every eight hours. Describe the indications you have of this process and the indications of a self-check malfunction. Answer: Every eight ho'.as each pen would yJckly rise and then return to the previous value. This process takes about one minute. A malfunction would be indicated by the check source pushbutton being back light during the test. This indicates the indication is not greater than 85% , of the source value. Reference Use Allowed? No Reference 1 LP CRO-122-1-6, page 31, LO 4.3a . Reference 2 Comments: l l SATISFACTORY l l UNSATISFACTORY l of 3 JPM #5 Question (a) Rad Monitoring Revised 10/16/97

7- , , l Calvert Cliffs Nucle:r Po.7er Plant JPM Questin (b) l Title ( Process Rad Monitoring K/A 073000K401 [4.0/4.3] j Question b: l There are numerous automatic functions generated by the Radiation Monitoring System. For the i below listed instruments, identify the their control functions.

1. RE-5316 ABCD Containment Area Alarms

2. RE-2191 Waste Gas Discharge

3. RE 5350 Control Room Ventilation Answer

1. RE-5316 ABCD Interface = Shut respective H2 Purge Valves

2. RE-2191 Interface = Shuts Gaseous Waste Discharge control valve

3. RE-5350 Interface = Shuts outside air dempers Start Post-LOCI filter fans Opens Post-LOCI filter dampers Stops the kitchen & toilet area exhaust fan I Reference Uso Allowed? NO Reference 1 LP CRO-122-1, page 42, #3.0 Comments:

l l SATISFACTORY l l UNSATISFACTORY 2 of 3 JPM #5 Question JO Rad Monitoring Revised 10/17/97

                                                                                           ,s,,,,      ,

Calved CilNs Nreleer Peer Plait JPM Q:est103 (h) Title Candidate Handout for Question b Question: There are numerous automatic functions generated by the Radiation Monitoring System. For the below listed instruments, identify their control functions. , 1. RE-5316 c r!CD Containment lii Range

2. RE-2191 Waste Gas Discharge

3. RE-5350 Contro! Room Ventilation i

j 3 of 3 JPM 85 Question (b) Rad Monitoring Revised 10/1697

                                                                                                   ,,-._  7 .

CCNPP LICENSED OPERATOR O JOH PERFORMANCE MEASURE AOP 3H.XX

,           SYSTEM:        Reactor Coolant System                                                               !

TASK: Respond to a Loss of RCS Inventory While SDC is in use { Fill with Containment Spray Syst m PURPOSE: Evaluates an Operator's Ability Respond to a loss of shutdown cooling due to a loss of RCS level. I i e v 1 JOB PERFORMANCE MEASURE CALVERT CLIFFS NUCLEAR POWER PLANT LICENSED OPERATOR TRAINING 1 ORIGINAL: PREPARED HY: DATE: REVISION: REVIEWED BY: DATE: Operations Instructor - Nuc REVIEWED BY: DATE: SRO License Holder APPROVED BY: DATE: Ops Training Supervisor Rev.0 1of12

                                                                     -                                        i

CCNPP LICENSED OPERATOR

, JOH PERFORMANCE MEASURE AOP 3H TASK: RESPOND TO A LOSS OF RCS INVENTORY WillLE SDC IS IN USE Fill with Containment Spray System ELEMENT STANDARD

                      * = Critical S'ep PERFORMER'S NAME:

APPLICADlLITY: RO and SRO PREREQUISITES: I ' Completion of the knowledge requirement of the initial License class training program. EVALUATION LOCATION: ) ; PLANT X SIMULATOR CONTROL ROOM EVALUATION MET 110D: ACTUAL PERFORMANCE DEMONSTRATE

j'ERFORMANCE ESTIMATED TIME ACTUAL TIME TIME CRITICAL TASK

, TO COMPLETE JPM: TO COMPLETE JPM: MINUTES MINUTES NO TASK ',EVEL: RETRAIN TOOLS AND EQUIPMENT: 11and held digital thermometer REFERENCE PROCEDURE (S): E0P-30 TASK STANDARDS: - Rev.0 2 0fl2

CCNPP LICENSED OPERATOR

,,                                                JOH PERFORMANCE MEASURE AOP.3H                                                                           '

i TASK: RESPOND TO A LOSS OF RCS INVENTORY WillLE SDC IS IN USE i i Fill with Containment Spray System 1 ELEMENT STANDARD 4

                       * = Critical Step This JPM is complete when RCS level has been restored using the containment spray system.

I [ 't i 1 Rev.0 3 of 12- --

_ . _ . _ .._- _ __. _ _ _ _ _ ._ . _ _ _ _ ___ _ _ _ _ _ _ . . ~ . . _ _ _ _ _ _ _ e CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP 3H t TASK: RESPOND TO A LOSS OF RCS INVENTORY WHILE SDC 1 IS IN USE

Fill with Containment Spray System

., ELEMENT STANDARD

                         ' = Critical Step DIRECTIONS TO EVALUATOR:

1 1

1. Read the " Directions to Traince" to the trainee.

4

2. Note the time that the task is started. As the task proceeds, indicate completion of each e'ement using the Standard criteria and the following notation:

                                                         -    "S" for satisfactory completion 4
                                                              "U" for unsatisfactory completion "N" if not observed OR not verifiable Critical elements must be observed or the evaluation is invalid.

3. When the Term:natin actions are necessary.g Note the completion Cue is reached, time. tell the trainee that no further

~

4. Document any instances ofincorrect performance in the Notes area (required for critical steps).

5. Questions should be asked after completion of the task.

6. Indicate whether the task was completed satisfactorily on the basis of i

correct perfonnance of all critical elements and completion of the task within the Estimated Time to Complete for Time Cntical tasks. i

7. This JPM contains the steps, notes, cautions, and standards that are applicable to the initial conditions specified in this JPM Steps that do ncet directly relate to this JPM, but appear in the procedure, are not listed here, it is the responsibility of the evaluator and/or observer to become familiar with the procedure prior to use of this JPM.

1 Rev.0 4 of 12

           ---..n -       - - , - , . -                             . , . - , -       . - , - - - - - - - . . - - < - - , . ~          c. - , - - - , - , , - - . .            ,,,,-,r.--~                  - - - .--

CCNPP LICENSED OPERATUR I JOli PERFORMANCE MEASURE AOP 3tl i TASK RESPOND TO A LOSS OF RCS INVENTORY WillLE SDC IS IN USE Fill with Containment Spray System ELEMENT STANDARD

                   * = Critical Step 1

JPM STANDARDS (List of minimum Standard Practices for common evolutions at CCNPP) 1.0 Starting a pump If non emergency condition, dispatches a PO to verify pump is ready to be started. Identify the Control Switch and Indicating Lights, using authorized identincation. Operate the Control Switch, to START, and check expected Indicating Light response. Check proper pump operation (as applicable);

                           -               Motor amps
                           -               Pump discharge pressure
                           -               System Dow
                           -               Activation / Clearing of applicable Annunciators (e.g.; lli Disch Press, Lo lidt Press) i            2.0     Stopping a pump identify the Control Switch and Indicating Lights, using authorized identl0 cation.

Operate the Control Switch, to STOP, and check expected Indicating Light response. Check expected system response (e.g.; How, pressure, level) 3.0 Operating Control Valves / Motor Operated Valves / Circuit Hreakers identify the Control Switch and Indicating Liphts, using authorized identification. Select the Control Switch to the desired position. Check Valve / Breaker position, using position Indicating Lights. Check expected system response (e.g.; How, pressure, level, volts, amps, KW) 4.0 Checking Valve /Hreaker position identify the Valve / Breaker Indicating Lights, using authorized identification. Check the Valve / Breaker is in the correct position. if Valve / Breaker is not in correct position, report Valve / Breaker position to CRS. 5.0 Verifying valve /bevaker position identify the Valve / Breaker Indicating Lights, using authorized identification. Check the Valve / Breaker is in the correct position. if Valve / Breaker is not in correct position, operates Valve / Breaker to correct position. 6.0 Locally starting a pump Rev.0 5of12

CCNPP LICENSED O/ERATOR

 .                                       JOH PERFORMANCE MEASURE AOP 3H t

TAShi RESPOND TO A LOSS OF RCS INVENTORY WillLE SDC . IS IN USE Fill with Containment Spray Systern ELEMENT STANDARD

           * = Critical Step Verify the following:

Suction Valve open Discharge Valve position (as applicable) Minluow Valve position (as applicable) Pump and Motor oil levels are normal

                   .         Adequate Suction Pressure Identify the Control Switch and Indicating Lights, using authorized identincation.

09erate the Control Switch, to START, and check expected Indicating Light response. Cbeck for proper Pump operation (as applicable): Smooth, quiet operation consistent with pump history Oil level remains Food Proper sealleakoff Proper discharge pressure Expected system Dow 7.0 Locally stopping a pump identify the Control Switch and Indicating Lights, using authorized identincation. Operate the Control Switch, to STOP, and check expected Indicating Light response. Check expected system response (e.g.t now, pressure, level). 8.0 Operating a Manual Valve Identify the Valve, using authorized identincation. Operate the Valve and check expected position indication change (e.g.t stem rise, pointer). Check expected System response (e.g.; Huid now sounds, pressure changes, tank levels). 9.0 Loestly operating Control Valvea/ Motor Operated Valves / Circuit Breakers identify the Control Switch and Indicating Lights (if applicable), using authorized identincation. Operate the Control Switch and check expected Indicating Light response. Check expected System response (e.g.t Dow, pressure, levels, volts, amps). 10.0 Locally checking Valve / Breaker position identify the Valve / Breaker, using authorized identincation. Check the Valve / Breaker is in the correct position, using appropriate position indication (e.g.t pointer, stem rise, Dags, indicating hghts), if Valve / Breaker is not in correct position, report Valve / Breaker position to Control Room. Rev 0 6ofl2

CCNPP LICENSED OPERATOR JOH PERFORMANCE MEASURE AOP 38 TASK: RESPOND TO A LOSS Ol' RCS INVENTORY WillLE SDC IS IN USE Fill with Containment Spray System ELEMENT STANDARD i

     * = Critical Step 11.0    Loenity vedfylag Valve / Breaker position identify the Valve / Breaker, using authorized identification.

Check the Valve / Breaker is in the correct position, using appropriate position indication (e.g.: pointer, stem rise, flags, indicating lights). If Valve / Breaker is not in correct position, operates Valve / Breaker to correct position. l Rev.0 ( 7 of l2

CCNPP LICENSED OPERATOR JOH PERFORMANCE MEASURE AOP 3H 1 TASK: RESPOND TO A LOSS OF RCS INVENTORY WillLE SDC IS IN USE Fill with Containment Spray System ELEMENT STANDARD ,

    * = Critical Step DIRECTIONS TO TRAINEE:

1) To complete the task successfully, you must grform each critical element correctly.

You must inform the evaluator of the indications you are monitoring. Where necessary, consider the evaluator to be the CRS. j

2) Initial Conditions: )

a) Unit 1 is in Mode 5 for maintenance. b) RCS pressure is 143 PSIA. c) The RCS was being maintained at 38'. d) SDC is aligned for service and RCS tempera'ure is 105 F. I c) The reactor has been shutdown for 15 days, f) A valve mis msitioning event occurred which lowered RCS level io 36', and resulted in a . oss of SDC. The valve has been retumed to the correct position. g) The operating 1. PSI pump has been secured and AOP 3B has been implemented. h) The llPSI system is unavailable, i) You are perfomiing the duties of the Unit 1 CRO.

3) Initiating Cue: The CRS has directed you to restore SDC, per AOP 3B Step Vill G.

4) Task Standard:

s This JPM is complete when you have taken the actions, per AOP-3B Step Vill.O. to restore RCS level. Rev.0 8 of12

CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP 3H i TASK: RESPOND TO A LOSS OF RCS INVENTORY WillLE SDC IS IN USE Fill with Containment Spray System ELEhiFNT STANDARD

         * = Critical Step TlhiE START            _

VIII.G.

1. IF it is detemtined that the loss ofinventory is Detennines step is applicable i associated with a lineup change or maintenance, TilEN perform the identified actions:

1

a. Restore the identified systems to a lineup Completed (

that supports SDC. conditions) given in initial

b. IF the leak has not been isolated AND SDC Determines step is N/A and was NOT secured, goes to ALTERNATE i ACTIONS.

b.l. IF the leak has been isolated AND SDC Determines step is has been secured due to RCS low level, applicable. TilEN perform the following actions: (1) Refill the RCS to the desired level PER Refers to Attachment (7) ATTACilhiENT(7), FILLING Tile RCS. ATTA;.'llMETN (7) NOTE The following methods of filling the RCS (IISPI PP fill, Containmeat Spray PP fill, and gravity fill) are arranged in order of priority. The method with the highest priority should be employed first, based on equipment availability. l CUE CRS directs tilling the RCS with #11 CS PP to a level of 38'. l 2.a. Ensure RCS pressure is less than 170 PSIA. Given in initial conditions,

b. Verify the MINI FLOW RETURN TO RWT Operator checks and verifies ISOL valves are open: valves are OPEN.

l SI 659 MOV

1-SI 660 MOV

c. Place the S1 PP RECIRC LOCKOUT hand Operator places switches in switches in LOCKOUT. LOCKOUT.

l llS 3659A

1 ilS 3660A Rev.0 9 of 12

CCNPP LICENSED OPERATOR JOH PERFORMANCE MEASURE AOP 3H t TASK: RESPOND TO A LOSS OF RCS INVENTORY WHILE SDC IS IN USE Fill with Containment Spray System El.EMENT STANDARD

                   * = Critical Step

d. Verify open the SilUTDOWN CLO FLOW Operator verifies open the CONTR valve,1 SI 306 CV OR SD SilUTDOWN CLO FLOW COOLING TEMP CONTR valve,1 SI 657 CONTR valve,1 SI 306 CV CV. OR SD COOLING TEMP CONTR valve,1 SI 657 CV.

l CUE 11 CS PP is to be used to fill the RCS. l e, if 11 CS PP is to be used to fill the RCS, TilEN com

                    *       (1) Open 11 R%plete T OUT valve,1   the SIfollowing:

4142 MOV. Operator ogns valve (2) Verify open 1! CS PP Suction valve,1 SI 311 Operator checks suction . valve (3) Crack open 11 CS PP Discharge valve, Operator cracks open valve f 1 SI 314. 1 (4) Start 11 CS PP. Operator start 11 CS PP Note The S11UTDOWN COOLING TEMPERATURE RECORDER,1 TR 351, will NOT indicate actual RCS temperature during the refill. Caution Do NOT exceed the following cooldown limits in any one hour :[H0053l

gregter than '70"F 1 'F/hr a a 184 F to 270 F 2 F/hr less than 184 F 1 F/hr (5) Monitor CET temperature Operator monitors temperatures. __ (6) Throttle 11 CSPP Discharge valve 1 SI-314 as Operator controls the necessary to control the cooldown rate, cooldown rate at 10 F/hr

g. IF performing Once Through Cooling, Not being performed.

CUE After the operator has established a " controlled" cooldown rate & a

                                 " controlled" fill, inform the operator the RCS level indicates 38'.

Rev.O 10 of12

j CCNPP LICENSED OPERATOR JOH PERFORMANCE MEASURE AOP 3H

1 TASK RESPOND TO A LOSS OF RCS INVENTORY WlilLE SDC IS IN USE Fill with Containment Spray System ELEMENT STANDARD

            * = Critical Step                                                                                         1

h. When filling is NO lon complete the following:ger desired, THEN

Secure the 11 SC PP and slace the (1) Operator secures SC PP handswitch in PULL TO LOCK.
Lock chut the CS PP Discharge Valve (2) Operator Shuts discharge 1 SI.14

                                    .                                               valve i

TIME STOP TERMINATING CUE: This JPM is complete when the operator shuts the discharge valve. Rev,0 11 of12

CCNPP LICENSED OPERATOR , JOH PERFORMANCE MEASURE AOP-3H TASK: RESPOND TO A LOSS OF RCS INVENTORY WHILE SDC IS IN USE Fill with Containment Spray System I i Ehn,HT STANDARD

       * = Critical Step NOTES:

i The operator's xrformance was evaluated against the standards contained in this JPM and determinec to be l l SATISFACTORY l l UNSATISFACTORY EVALUATOR'S SIGNATURE: DATE: Rev.0 12 of12

(< ( , Calvert Cliffs Nuclear Paner Plant JPM Question (s) Title RCS K/A 006000K406 [2.7/3.0) Question at Why are the St PP Recirc Lockout hand switches placed in Lockout? (Step 2.c on page 9 of this JPM.) Answer: Prevent an inadvertent closure of the valves which could darnage the running pump due to loss of pump recirculation flow. Reference Use Allowed? Reference 1 FSAR

   ,  Reference 2 i

Comments: l l Satisfactory l IUnsatisfactory Candidate ( l of 2 JPM #6 Question (a) Reactor Coolant Revised 10/17/97

C:lvert Cliffs Nzclear P=ler Plant JPM Question (b) Title RCS K/A 002000A103 [3,7/3,8] Question b: Why does recorder 1.TR.351 not Indicate RCS temperature in this condition? (note on page 10 of this JPM) l l Answer: The suction to the pumps is from the RWT. Ref: .:ce Use Allowed? I Reference 1 Reference 2 , Comments: j l l I I I i l l Satisfactory l IUnsatisfactory Candidate 2 of 2 JPM #6 Question (b) Reactor Coolant Reviuxi 10/17/97 i _ _ _ _ _ _ _ _ _ _ . _ . _ . _ J

(s;.e< ~ CCNPP LICENSED OPERATOR la Jolt PERFORMANCE MEASURE AOP 31s TASK: Commence Shutdown Cooling per EOP 5 AE i JOH PERFORMANCE MEASURE CALVERT CLIFFS NUCLEAR POWER PLANT LICENSED OPERATOR TRAINING ORIGINAL: PREPARED BY: DATE: REVISION: REVIEWED BY: DATE: Operations instructor - Nu REVIEWED BY: DATE: SRO License Holder APPROVED BY: DATE: Ops Training Supervisor 1ofil Rev 0.

.j

CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP 3H t TASK: Commence Shutdown Cooling per EOP 5 AE PERFORMER'S NAME: APPLICABILITY: RO and SRO PREREQUISITES: > l Completion of the knowledge requirement of the Initial Litense class training program for the - EVALUATION LOCATION: l PLANT __,, X _ SIMULATOR CONTROL ROOM EVALUATION METilOD:

ACTUAL PERFORMANCE DEMONSTRATE PlikFORMANCE ESTIMATED TIME ACTUAL TIME TIME CRITICAL TASK:

TO COMPLETE JPM: TO COMPLETE JPM: MINUTES MINUTES No f TASK LEVEL: TRAIN TOOLS AND EQUIPMENT: lland held digital thermometer REFERENCE PROCEDURE (S): EOP 5 TASK STANDARDS: This JPM is complete when SDC flow has been established as described in EOP-5 Step AE. 2 0fil Rev0.

CCNPP LICENSED OPERATOR Jolt PERFORh1ANCE h1EASURE AOP 311 TASK: Commence Shutdown Cooling per EOP.S AE DIRECTIONS TO EVALUATOR:

1. Read the " Directions to Trainee" to the trainee.

2. Note the time that the task is started. As the task proceeds, indicate completion of each element using the Standard criteria and the following notation:

             -   "S" for satisfactory completion "U" for unsatisfactory completion "N" if not observed OR not verifiable Critical clernents must be observed or the evaluation is invalid.

3. When the Terminatin actions are necessary.g Cue is reached, Note the completion time. tell the trainee that n ' mher

4. Document any instances ofincorrect performance in the Notes area (required for critical steps).

5. Questions should be asked after completion of the task.

6. Indicate whether the task was completed satisfactorily on the basis of correct performance of all critical elements and completion of the task within the Estimated Time to Complete for Time Cntical tasks.

7. This JPhi contains the steps, notes, cautions, and standards that are applicable to the initial conditions specified in this JPM. Steps that do not directly relate to this JPM, but appear in the procedure, are not listed here, it is the responsibility of the evaluator and/or observer to become familiar with the procedure prior to use of this JPM.

3 0f il Rev0.

4 CCNPP LICENSED OPERATOR JOH PERFORMANCE MEASURE AOP 3B TASK: Commence Shutdown Cooling per E0P 5 AE JPM STANDARDS (List of minimum Standard Practices for common evolutions at CCNPP) 1.0 Starting a pump If nonmacrgency condition, dispatches a PO to verify pump is ready to be started. Identify the Control Switch and Indicating Lights, usma authorized identincation. Operate the Control Switch, to START, and check expected Indicating Light response. Check proper pump operation (as applicable);

         -        Motor amps Pump discharge pressure
         -        System Dow Activation / Clearing of applicable Annunciators (e.g.t lli Disch Press, Lo Ildr Press) 2.0   Stopping a pump Identify the Control Switch and Indicating Lights, using authorized identincation.

Operate the Control Switch, to STOp. and check expected Indicating Light response. Check expected system response (e.g.t Dow, pressure, level) 3.0 Operating Control Valves / Motor Operated Valvea/ Circuit Hreakers t identify the Control Switch and Indicating Liphts, using authorized identincation. Select the Control Switch to the desired position. Check Valve / Breaker position, using position Indicating Lights Check expe:ted system response (e.g.t now, pressure, level, voits, amps, KW) 4.0 Checking Yalve/Hreaker position identify the Valve / Breaker Indicating Lights, using authorized identincation. Check the Valve / Breaker is in the correct position. If Valve / Breaker is not in correct position, report Valve / Breaker position to CRS.

   $.0   Verifying valve / breaker position Identify the Valve / Breaker Indicating Lights, using authorized identincation.

Check the Valve /Breake is in the correct position, if Valve / Breaker is not in correct position, operates Valve / Breaker to correct position. 6.0 Locally starting a pump Verify the following: Suction Valve open Discharge Valve position (as applicable) Mininow Valve position (as applicable) Pump and Motor oillevels are normal Adequate Suction Pressure identify the Control Switch and Indicating Lights, using authorized identification. 4 0f il Rev0.

_ _ __ - _ _ ~ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ __ _ ___ -_ _ _ _ _ _ _ _ _ _ .______ CCNPP LICENSED OPERATOR JOH PERFORMANCE MEASURE AOP 3H 4 i TASK: Commence Sht:tdown Cooling per EOP S AE Operate the Control Switch, to START, and check expected Indicating Light response. Check for proper Pump operation (as applicable): Amooth, quiet op ration consistent with pump history

                                     -        Oil level remains good
                                     -         Prcper rcal bakoff proper discharfe pressure Expected system Cow 1.0    E.J,etig tiafhg a poinp identify the Control Switch and Indicating Lights, uslag anhorized identincation.

Operate the Control Svikh, to STop, and check expected Indicating Light response. Check expected system response (e.g.; flow, pressure, itvel). 8.0 Operating a Manual Valve Identify the Valve, using authorized identification. Operate the Valve and check expected position indication change w.g.; stem rise, pointer \ Check expectw System response (e.g.; Duid now sounds, pressure changes, tank levels). 9.0 !acally operating Control Valves / Motor Operated Valves /Clreult Hreakers , { identify the Control Switch and Indicating Lights (if applicable), using authorized ident!0 cation. Operate the Control Switch and check expected Indicating Light response. Check expected System response (e.g.: Dow pressure, levels, volts, amps). 10.0 Locally checking Valve / Breaker position identify the Valve / Breaker, using authorized identification. Check the Valse /llreaker is in the correct position, using appropriate position indication (e.g.; pointet, stem rise, Dags, indicating hghts), if Valve /llreaker is not in correct position, report Valve /Ilreaker position to Control Room, 11,0 localiperif) lag Valve /Hreaker position Identify the Valve / Breaker, using authorized identincation. Ch;ck the Valve /llreaker is in the correct position, using appropriate position indication (e.g.; pointer, stem rise, Hags, indicating lights), if Valve / Breaker is not in correct position, operates Valve / Breaker to correct position. S ofil Rev0.

CCNPP LICENSED OPERATOR 4 JOB PERFORMANCE MEASURE AOP 3B t TASK: Commence Shutdown Coo!:ng per EOP 5 AE DIRECTIONS TO TRAINEE:

1) To complete the task successfully, you must perform each critical clernent correctly.

l You must inform the evaluator of the indications you are monitoring. Where necessary, consider the evaluator to be the CRS.

2) Initial Conditions:

l a) You are performing the duties of the Unit 1 CRO. b) A Loss of Coolant Accident has occurred. c) RCj pressure in approximately 153 PSIA with CETs indicating approximately 2901 d) Containment pressure is approximately 15 PSIO. c) Pressurizer injection is in progress, f) SIAS actuated 9 hours ago. g) EOp.5 has been implemented. I h) EOP.5, Section AC has been completed, charging flow is 100 GPM. l i) PRESSUR17.ER LEVEL <101" j) RWTlevel 0.3' k) Containment water level is 35" I) Containment Cooling is available

3) Task Standard:

This JPM is com 31ete when you have tEken the actions, per EOP 5 step AE to establish s iutdown cooling.

4) Initiating Cue: The CRS has directed you to establish shutdown cooling per EOP.5 step AE Are there any questions? You may begin.

_ = 6ofil Rev0. ______--_J

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

9, CCNPP LICENSED OPERATOR

 '                                                             JOH PERFORMANCE MEASURE AOP 3B                                                  l

( i TASK: Commence Shutdown C,nling per EOP 5 AE ELEMENT STANDARD

                             * = Critical Step TIME START                 .

AE Commence Shutdown Cooling 1.1 IF CET temperature are less than 300'F AND the following conditions exist: Conditions for establishing shutdown cooling can NOT be met RWT level is less than 0.5 feet CNTMT WR WATER LVL indicator 1-LI-4146, or 1 LI 4147 indicates at least 28 inches Component Cooling system is available as a heat sink. TilEN commence attemate shutdown cooling as follows: 4

CUE When asked, the radiation levels are low enough to allow valve repositioning.

a Conta:t the Operational Support Center to Operator simulates this check radiation levels are low enough to allow communiention to the OSC, valve repositioning. b Verify RCS pressure minus containment Given in initial conditions pressure is less than 160 PSID, c IF the plant computer is NOT operating, The plant computer is TilEN record the following information: available,

d Shut i1 CS PP DISCll valve,1 SI 314 Directs Plant O operate valve, perator to
e Shut 12 CS PP DISCli valve,1 SI 324 Directs Plant Operator to 4

operate valve.

f Shut 11 SDC llX OUT TO CS valve,1-SI- Directs Plant O 319. operate valve, perator to
g Shut 12 SDC llX OUT TO CS valve,1 SI- Directs Plant O 329 operate valve, perator to 7 of 11 -

Rev0.

CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP 3B TASK: Commence Shutdown Cooling per EOP-5 AE ELEMENT STANDARD

         * = Critical Step

h Open 11 SDC llX INLi'T XCONN valve, l- Directs plantOperator to SI 452 operate valve.
i Open 11 SDC 11X OUTLET TO LPSI!!DR Directs plant O l valve,1 SI-456. operate ve.lve. perator to

         * ~~j  Open 12 SDC llX INLET XCONN valve,                     Directs Plant Operator to 1S1 453,                                        operate valve.

t

k Open 12 SDC llX OUTLET TO LPSIIIDR l ~~ Directs Plant O l

vr.tve,1 Sl-457. operate valve. perator to l

        ]E!            When asked by opirator, i 1 CC llX is in service                             j' I
     ,            1    Place a second CC llX in service as follows:

_ (1) Open the appropriate CC llX CC OUT valve: Operator opens 1CC 3826-1 CC 3824 CV CV.

l CC 3826-CV (2) Tiirottle open the appropriate Saltwater CC Operator opens 1 lilC-5508 IlX OUT VLV:
1lilC-5206
l lilC-5208
m Start a second CC PP. Starts CC Pump
Open 11 SDC IIX CC OUT valve,1 CC.

                 .n                                                    Operator operates valve.

3828 CV. __o Oper,12 SDC IIX CC OUT valve,1 CC- Operator operates valve. 3830 CV. p Open SDC IIX LPSIINL valve,1 SI 658- Operator operates valve. MOV. l q Place the keyswitch for SDC FLOW CONTR, Operate operates keyswitch. 1 SI 306-CV in AUTO Sofil Rev0.

CCNPP LICENSED OPERATOR JOH PERFORMANCE MEASURE AOP 3H TASK: Commence Shutdown Cooling per EOP S AE ELEMENT STANDARD

       * = Critical Step                                                                                                       I

r Shif) 1.FIC 306 to MANUAL with a 95% Operator shifts controller to output signal, manual and adjust output signal.

i s IF 110t Leg injection is being used for core Not being used. flush,

t IF Pressurizer injection is being used for core Operator opens valve.

flush, TilEN open 12A LPSI liDR valve,1-SI 635 MOV

u Open LPSIIIDR valves:

          --~                                                                                  Operator verifies valves.

l-SI 615 MOV e 1 SI 625 MOV

1 SI 645 MOV

y Open CNTMT SUMP DISCl{ valves: Operator verifies valves.

l SI 4144 MOV k = 1 SI-4145 MOV

w Shut MINI FLOW RETURN TO RWTISOL Operator operates valves, valves:

l SI 659 MOV e 1 SI 660 MOV

CAUTI DN The possibility of envitation rises when taking suction from the Containment sump. l CUE If ask, NO LPSI PP are operating l x IF the LPSI PPs are NOT operating then clear RAS for ONE operable LPSI PP and start as follows: (1) Place the selected LPSI PP RAS OVERRIDE Operator switch in OVERRIDE. override. places switch in __(2) Start the selected pump. Operator starts pump CAUTI DE _ The cooldown limit changes from 100"F in agy one hour period to 20"F in any one hour period when RCS temperature are below 270 F. 9 0f il Rev0. A

CCNPP LICENSED OPERATOR JOH PERFORMANCE MEASURE AOP 3H : 1 TASK: Commence Shutdown Cooling per EOP S AE l ELEMENT STANDARD

   * = Critical Step                                                                          I

y Adjust the signal on I FIC 306 to raise flow Operator adjust signal to to 3000 GPM, while maintaining cooldown increase flow to 3000 GPM rate within limits. & does not exceed limhs.
z Place the keyswitch for S/D COOLING O xrator places keyswitch in TEMP CONTR, ISI 657 CV,in AUTO. A JTO.

CAUTI DE The heatup rate limit for Shutdown Cooling lleat Exchangers is 14"F/m.

aa Agust 1 SI 657 CV to obtain less than Operator malptains heatup 14 F/m heatup rate at Exchanger Outlet,1 TI- within the 14 F/ minute limit 030X and 1 TI 303Y.

CUE If gsked, instruct operator to establish a 50 F/ hour cooldown. ab IF desired RCS cooldown rate can NOT be Rate is to be such that an maintained with one LPSI PP, additional LPSI PP is not ' needed.

ac Adjust S/D COOLING TEM CONTR valve, Operator controls cooldown

                ' SI 657 CV, to obtain the desired cooldown   rate, rate.

TIME STOP

TERMI The task is complete when operator has NATIN established a cooldown. O CUE: 10 cf l1 Rev 0.

4 CCNPP LICENSED OPERATOR i4 JOH PERFORMANCE MEASURE AOP 3H

TASK: Commence Shutdown Cooling per EOP 5 AE ,

ELEMENT STANDARD

                            * = Critical Step NOTES:

s d i J l f f 7 i 4 1 The operator's wrformance was evaluated against the standards contained in this JPM and deteiminec to be j i SATISFACTORY [ l UNSATISFACTORY EVALUATOR'S SiONATURE: DATE: ll ofil Rev 0.

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

Calvert Cliffs Nrclear P wer Plant JPM Question (a) Title i Commence SDC per EOP 5 K/A 006000A202 p.9/4.3] Question at .

        . Why does the possibility of pump cavitation rise when taking suction from the containment sumps?

l . 1 Answer Insufficient water level and high water temperature may cause pump cavitation. Reference Use Allowed? NC , Reference 1 LOCA bases document page 64, rev 3; FSAR Reference 2 Comments: - i 1 I I Satisfactory l IUnsatisfactory Candidate v-l of 2 JPM #7 Question (a) Core Flush Revised 10/17/97

Calvert Cliffs Nuclear P:wer Plant JPM Q:est1:2(b) Title Commence SDC per EOP 5 K/A 006000A107 [3.3/3.6] Question b Why must the RCS pressure minus the containment pressure be less than 160 PSID? ! Answer LPSI pump head limitations 1 Reference Use Allowed? NO Reference I LOCA bases document page 64, rev 3 Reference 2

 't Comments:

I I I I I I Satisfactory 1 IUnsatisfactory Candidate i 2 of 2 JPM #7 Question (b) Core Flush Revised 10/17/97

ip , , + : a > CCNPP LICENSED OPERATOR w a JOB PERFORMANCE MEASURE AOP-911 IN SYSTEM: Main Steam TASK: 010190409 Locally Operate the MSIVs PURPOSE: Evaluates an Operator's Ability to Locally Close an MSIV During Performance of AOP 9H JOB PERFORMANCE MEASURE CALVERT CLIFFS NUCLEAR POWER PLANT LICENSED OPERATOR TRAINING ' PREPARED BY: DATE: 09/02/97 REVIEWED BY: DATE: Operations Instructor - Nuc REVIEWED BY: DATE: SRO License Holder APPROVED BY: DATE: Ops Training Supervisor Rev.0

                                                        ,                             - - - - - - _ - - - - - - - -   J

Page 2 h CCNPP LICENSED OPERA TOR

  ,                              JOB PERFORMANCE MEASURE AOP-9H IN TASK:         010190409    Locally Operate The MSIVs PERFORMER'S NAME:

APPLICABILITY: RO and SRO PREREQUISITES: Completion of the knowledge requiremer t of the Initial License class training program for the Main Steam System. EVALUATION LOCATION: _.X_ PLANT SIMULATOR CONTROL ROOM EVALUATION METilOD: ACTUAL PERFORMANCE .X DEMONSTRATE PERFORMANCE ESTIMATED TIME ACTUAL TIME TIME CRITICAL TASK: TO COMPLETE JPM: TO COMPLETE JPM: 10 MINUTES MINUTES NO TASK LEVEL: NO TRAIN TOOLS AND EQUIPMENT: 7/16 inch wrench REFERENCE PROCEDURE (S): AOP-9H OI8E TASK STANDARDS: This JPM is complete when 11 MSIV has been closed. t. L .. ..

e Page 3 CCNPP LICENSED OPERATOR c - JOB PERFORMANCE MEASURE AOP-9H-IN TASK: 010190409 Locally Operate The MSIVs DIRECTIONS TO EVALUATOR:

1. Read the " Directions to Trainee" to the trainee.

2. Note the time that the task is started. As the task proceeds, indicate completion of each element using the Standard criteria and the following notation:

                             "S" for satisfactory completion "U" for unsatisfactory completion "N" if not observed OR not verifiable Critical elements must be observed or the evaluation is invalid.

3. When the Terminating Cue is reached, tell the trainee that no further actions are necessary, Note the completion time.

4. Document any instances ofincorrect performance in the Notes area (required for critical steps),

j 5. Questions should be asked after completion of the task, j 6. Indicate whether the task was completed satisfactorily on the basis of correct performance of all critical elements and completion of the task within the Estimated Time to Complete for Time Critical tasks.

7. This JPM contains the steps, notes, cautions, and standards that are applicable to the initial conditions specified in this JPM. Steps that do not directly relate to this JPM, but appear in the procedure, are not listed here. It is the responsibility of the evaluator and/or observer to become familiar with the procedure prior to use of this JPM.

 .                                                                                                                    Page 4 CCNPP LICENSED OPERATOR
 .                                         JOB PERFORMANCE MEASURE AOP-9H IN TASK:                     010190409                    Locally Operate The MSIVs JPM STANDARDS (List of minimum Standard Practices for common evolutions at CCNPP) 1.0              Starting a pump if non-emergency condition, dispatches a PO to verify pump is ready to be started.

Identify the Control Switch and Indicating Lights, usmg authorized identification. Operate the Control Switch, to START, and check expected Indicating Light response. Check proper pump operation (as applicable): Motor amps Pump discharge pressure System flow Activation / Clearing of applicable Annunciators (e.g. Hi Disch Press, Lo Hdr Press) 2.0 Stopping a pump Identify the Control Switch and Indicating Lights, using authorized identification. Operate the Control Switch, to STOP, and check expected Indicating Light response. Check expected system response (e.g.; flow, pressure, level) 3.0 Operating Control Valves / Motor Operated Valves / Circuit Breakers t Identify the Control Switch and Indicating Lights, using authorized identification. Select the Control Switch to the desired position. Check Valve / Breaker position, using position Indicating Lights. Check expected system response (e.g.; flow, pressure, level, volts, amps, KW) 4.0 Checking Valve / Breaker position Identify the Valve / Breaker Indicating Lights, using authorized identification. Check the Valve / Breaker is in the correct position. If Valve / Breaker is not in correct position, report Valve / Breaker position to CRS. 5.0 Verifying valve / breaker position Identify the Valve / Breaker Indicating Lights, using authorized identification. Check the Valve / Breaker is in the correct position. If Valve / Breaker is not in correct position, operates Valve / Breaker to correct position. 6.0 Locally starting a pump Verify the following: Suction Vaive open Discharge Valve position (as applicable) Miniflow Valve position (as applicable) Pump and Motor oil levels are normal Adequate Suction Pressure identify the Control Switch and Indicating Lights, using authorized identification. I

                                                                                                                          .  .. __ _a

Page5 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP-911-IN TASK: 010190409 Locally Operate The MSIVs Operate the Control Switch, to START, and check expected Indicating Light response. Check for proper Pump operation (as applicable): Smooth, quiet operation consistent with pump history Oillevel remains good

              -        Proper seal leakoff Proper discharge pressure Expected system How 7.0   Locally stopping a pump Identify the Control Switch and Indicating Lights, using authorized identincation.

Operate the Control Switch, to STOP, and check expected Indicating Light response. Check expected system response (e.g.; How, pressure, level). 8.0 Operating a Manual Valve Identify the Valve, using authorized identification. ' Operate the Valve and check expected positian indication change (e.g.; stem r:se, pointer). Check expected System response (e.g.; fluid How sounds, pressure changes, tank levels). i 9.0 Locally operating Control Valves / Motor Operated Valves / Circuit Breakers k Identify the Control Switch and Indicating Lights (if a licable), using authorized identification. Operate the Control Switch and check expected Indica 7ng Light response. Check expected System response (e.g.: flow, pressure, levels, volts, amps). 10.0 Locally checking Valve / Breaker position Identify the Valve / Breaker, using authorized identification. Check the Valve / Breaker is in the correct position, using appropriate position indication (e.g.; pointer, stem rise, Dags, indicating lights), if Valve / Breaker is not in correct position, report Valve / Breaker position to Control Room. 11.0 Locally verifying Valve / Breaker position Identify the Valve / Breaker, using authorized identification. Check the Valve / Breaker is in the correct position, using appropriate position indication (e.g.; pointer, stem rise, flags, indicating lights). If Valve / Breaker is not in correct position, operates Valve / Breaker to correct position. t

 ,                                                                                               Page 6 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP-911-1N TASK:     010190409                             Locally Operate The MSIVs DIRECTIONS TO TRAINEE:

1. To complete the task successfully, you must perform each critical element correctly. You must inform the evaluator of the indications you are monitoring.

Where necessary, consider the evaluator to be the CRS.

2. Initial Conditions:

a. A severe Hre has been reported and confirmed in the Unit 1 CC PP Room (Room 228).

] b. You are performing the duties of the ABO.

3. Task Standard: This JPM is complete when the MSIVs and MSIV Bypass MOVs are shut.

4. Initiating Cue: The CRO has directed you to locally close the MSIVs and MSIV Bypass MOVs per AOP-9H, Step AD. Are there any questions? You may begin.

l 4

                                                                                               -        _ _ - - - - - J

 ,                                                                                                                                    Page 7 CCNPP LICENSED OPERATOR o

JOB PERFORMANCE MEASURE AOP-9H IN ELEMENT STANDARD (* = CRITICAL STEP) TIME START NOTE TO EVALUA TOR : Supply the operator with a copy ofAOP-9A. AD. (ABO) Verify MSIVs and MSIV Bypass MOVs are SHUT. Identify AOP-9H, Step AD. Same as element. Proceed to Unit 1 Main Steam Penetration Room.

1. Secure 11 and 12 MSIV Hydraulic Pump:

CUE: When checked or asked: Instrument Air Isolation valve 1-1A-1069 is open. i CUE: When operation indicated: Instrument Air Isolation valve 1-IA-1069 is shut. i a. Shut Instrument Air Isolation to 11 MSIV Check 'msition of 1-IA-1069 Hydraulic Pump,1-IA-1069. AND slut valve. CUE: When checked or asked: Instrument Air Isolation valve 1-IA-1070 is open. CUE: When operation indicated: Instrument Air Isolation valve 1-IA-1069 is shut.

b. Shut Instrument Air Isolation to 12 MSIV Check msition of1-IA-1070 Hydraulic Pump,1-IA-1070. AND s lut valve.

CUE: When checked or asked: 11 MSIV is o closed (Stem position, local indication) pen (stem position, loc:0 indication); 12 MSIV is

2. IF 11 (12) MSIV is open, Determine 1I MSIV is open AND THEN:

12 MSIV is shut.

a. Remove one Dump Solenoid Valve cap on:

                                      .                 1I (12) MSIV Dump SV Channel A,                     Locate appropriate solenoid valve, IMSH-4042A-SV (1-MSH-4047A-SV).                      either IMSH-4042A-SV or OR                                                                                             IMSH-4042B-SV AND remove e                 11 (12) MSIV Dump SV Channel B,                     cap.

1MSH-4042B-SV (1-MSH-4047B-SV). l

Page 8 CCNPP LICENSED OPERATOR . JOB PERFORMANCE MEASURE AOP-9H-IN ELEMENT STANDARD (* = CR.lTICAL STEP) NOTE TO EVALUA TOR : The designation ofa 7/16 inch wrench is NOTaddressed in AOP-9/I. OI-8E MSIV ACTUATOR SYSTEM. sections 6.10 and 6.11 do specify the use of this size wrench.

b. Place a wTench on the stem nut. Place 7/16 inch wTench on stem nut for solenoid valve chosen in previous step.

CUE: When operation indicated: Stem nut rotates.

c. Rotate the wrench in the clockwise direction Indicate rotation of the wTench in a (ap aroximately three turns) to bleed clockwise direction for hyc raulic fluid back to the reservoir, approximately three turns.

3. Shut MSIV Bypass MOVs:

CUE: When checked or asked: MSIV Bypass MOV l-MS-4045-MOV is shut (stem position; local indication),

a. 11 MSIV BYP,1-MS-4045-MOV. Check position of'l-MS-4045-MOV AND determine valve is shut.

CUE: When checked or asked: MSIV Bypass MOV l-MS-4042-MOV is shut (stem position; local indication).

b. 12 MSIV BYP,1-MS-4042-MOV. Check position of 1-MS-4042 MOV AND determine valve is shut, CUE: When notification indicated: Acknowledge report for position of MSIV and MSIV Bypass valves.

4. Notify the Control Room that the MSIVs and Contact control room and make MSIV Bypass MOVs are shut, report on valve positions.

TIME STOP TERMINATING CUE: This JPM is complete when the MSIVs and MSIV Bypass MOVs are shut. No further actions are required. l l

Page 9 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP-9H IN TASK: 010190409 Locally Operate The MSIVs NOTES: i l I The operator's wrformance was evaluated against the standards contained in this JPM and determinec to be SATISFACTORY UNSATISFACTORY EVALUATOR'S SIGNATURE: DATE:

C;lvert Cliffs Nuclear Prer Plant JPM Q:estita (a) Title t Main Steam K/A 013000A202 [4.3/4.5] Question a: After a Steam Generator SGIS signal is blocked using the keyswitch, how is the SGIS AUTOMATICALLY unblocked? Answer: The signal is automatically unblocked when 2 out of 4 steam generator pressure detectors sense greater than 785 psia.(T.S. value) Reference Use Allowed? Reference 1 : Alarm Manual Window C-59 "SGIS "" BLOCKED" l Reference 2 : Technical Specifications l 4 Comments: l I Satisfactory l l Unsatisfactory Candidate 1 of 2 JPM #8 Question (a) Main Steam Revised 10/17/97 l

                                                                                                         -- J

e Calvert Cliffs Nuclear P:wer Plant JPM Questi:n (b) Title ( Main Steam K/A 039000K408 [3.3/4.0) Question b. During the performance of a partial stroke test of the MSIV (per STP-0-47), a time limit of 120 sec, is imposed. The procedure states that a plant trip may occur, What signal will cause the reactor trip? Answer: The trip signal that may cause a reactor trip is "S/G Azimuthial" or "ASGT', Reference Use Allowed? Reference 1 i Reference 2 Comnients: I I I I l l Satisfactory l l Unsatisfactory Candidate 2 of 2 JPM #8 Question (b) Main Steam Revised 10/17/97

o-7 CCNPP LICENSED OPERATOR o JOB PERFORMANCE MEASURE AOP 9A-XX t SYSTEM: Safety injection & Containment Spray TASK: [insen task #) Manually Control LPSI Temperature PURPOSE: Evaluates an Operator's Ability to Manually Control LPSI Flowffemperature During performance of AOP-9A. 9 JOB PERFORMANCE MEASURE CALVERT CLIFFS NUCLEAR POWER PLANT l LICENSED OPERATOR TRAINING i ORIGINAL: PREPARED BY: DATE: REVISION: REVIEWED BY: DATE: Operations Instractor -Nuc REVIEWED BY: DATE: SRO License Holder APPROVED BY: DATE: Ops Training Supervisor Rev.0 1of9 l 1

       ~                                                                                                                   )

e . .

                                      . CCNPP LICENSED OPERATOR a.

JOB PERFORMANCE MEASURE AOP-9A i- TASK: Manually Control LPSI Temperature PERFORMER'S NAME: APPLICABILITY: RO and SRO

        - PREREQUISITES:

Completion of the knowledge requirement of the Initial License class training program for the EVALUATION LOCATION:' X_ PLANT SIMULATOR CONTROL ROOM. ! l EVALUATION METHOD: ACTUAL PERFORMANCE DEMONSTRATE PERFORMANCE , ESTIMATED TIME ACTUAL TIME TIME CRITICAL' TASK: TO COMPLETE JPM: TO COMPLETE JPM: MINUTES MINUTES NO

TASK LEVEL:

               -TRAIN l

TOOLS AND EQUIPMENT: Hand held digital thermometer REFERENCE PROCEDURE (S): , AOP-9A TASK STANDARDS: This JPM is complete when the 11 LPSI pump has been started and the temperate is being controlled within the limits identified in step DM. -- 2 of 9 Rev.0 l

C CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP-9A i TASK: Manually Control LPSI Temperature DIRECTIONS TO EVALUATOR:

1. Read the " Directions to Trainee" to the trainee.

2. Note the time that the task is started. As the task proceeds, indicate completion of each element using the Standard criteria and the Iollowing notation:

                   "S" for satisfactory completion "U" for unsatisfactory completion "N" if not observed OR not verifiable Critical elements must be observed or the evaluation is invalid.

3. When the Terminating Cue is reached, tell the trainee that no further actions are ! necessary. Note the completion time. 1

4. Document any instances ofincorrect performance in the Notes area (required for '

i critical steps).

5. Questions should be asked after completion of the task.

   ,(       6. Indicate whether the task was completed satisfactorily on the basis of correct wrformance of all critical elements and completion of the task within the istimated Time to Complete for Time Critical tasks.

7.- This JPM contains the steps, notes, cautions, and standards that are applicable to the initial conditions specified in this JPM. Steps that do not directly relate to this JPM, but appear in the procedure, are not listed here. It is the responsibility of the - evaluator and/or observer to become familiar with the procedure prior to use of this'JPM. i 3 of 9 < Rev.O

CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP-9A

 *i  TASK:                                       Manually Control LPSI Temperature JPM STANDARDS (List of minimum Standard Practices for common evolutions at CCNPP) 1.0   Starting a pump If non-emergency condition, dispatches a PO, to verify pump is ready to be started.

Identify the Control Switch and Indicating Lights, usmg authorized identification. Operate the Control Switch, to START, and check expected Indicating Light response. Check proper pump operation (as applicable):

           -        Motor amps Pump discharge pressure
           -        System i ow Activation / Clearing of applicable Annunciators (e.g.; Hi Disch Press, Lo Hdr Press) 2.0   Stopplag a pump identify the Control Switch and Indicating Lights, using authorized identification.

Operate the Control Switch, to STOP, and check expected Indicating Light response. Check expected system response (e.g.; flow, pressure, level) l 3.0 Operating Control Valves / Motor Operated Valves / Circuit Breakers i identify the Control Switch and Indicating Lights, using authorized identification. Select the Convol Switch to the desired position. l Check Valve / Breaker position, using position Indicating Lights. Check expected system response (e.g.; flow, pressure, level, volts, amps, KW) 4.0 Checking Valve / Breaker position identify the Valve / Breaker Indicating Lights, using authorized identification. Check the Valve / Breaker is in the correct position. If Valve / Breaker is not in correct position, report Valve / Breaker position to CRS. 5.0 Verifying valve / breaker position Identify the Valve / Breaker Indicating Lights, using authorized identification. Check the Valve / Breaker is in the correct position. If Valve / Breaker is not in correct position, operates Valve / Breaker to correct position. 6.0 Locally starting a pump Verify the following: Suction Valve open Discharge Valve position (as applicable) Miniflow Valve position (as applicable) Pump and Motor oil levels are normal Adequate Sucifon Pressure Identify the Control Switch and Indicating Lights, using authorized identification. Operate the Control Switch, to START, and check expected Indicating Light response. Check for proper Pump operation (as applicable): 4 of 9 Rev.0

CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP-9A ( TASK: Manually Control LPSI Temperature Smooth, quiet operation consistent with pump history Oillevel remains good

            -        Proper seal leakoff Proper discharge pressure
            .        Expected system Co>v 7.0     Loenlly stopping a pump Identify the Control Switch and Indicating Lights, using authorized identification.

Operate the Control Switch, to STOP, and check expected Indicating Light response. Check expected system response (e.g.; How, pressure, level). 8.0 Operating a Manual Valve Identify the Valve, using authorized identification. Operate the Valve and check expected position indication change (e.g.; stem rise, pointer). Check expected System response (e.g.; Ouid How sounds, pressure changes, tank levels). 9.0 Locally operating Control Valves / Motor Operated Valves / Circuit Breakers identify the Control Switch and Indicating Lights (if applicable), using authorized identincation. Operate the Control Switch and check expected Indicatmg Light response. Check expected System response (e.g.; How, pressure, levels, volts, amps). ( 10.0 Locally checking Valve / Breaker position Identify the Valve / Breaker, using authorized identification. Check the Valve /Bresker is in the correct position, using appropriate position indication (e.g.; pointer, stem rise, Dags, indicating lights). If Valve / Breaker is not in correct position, report Valve / Breaker position to Control Room. 11.0 ' Locally verifying Valve / Breaker position Identify the Valve / Breaker, using authorized identi0 cation. Check the Valve / Breaker is in the correct position, using appropriate position indication (e.g.; pointer, stem rise, Dags, indicating lights). If Valve / Breaker is not in correct position, operates Valve / Breaker to correct position. ( 5of9 Rev.O

CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP 9A '

     -(    TASK:             Manually Control LPSI Temperature DIRECTIONS TO TRAINEE:

1. To complete the task successfully, you must perform each critical element '

correctly. _ You must inform the evaluator of the indications you are monitoring. Where necessary, consider the evaluator to be the CRS.

2. Initial Conditions:

a. A fire has resulted in a control room evacuation,

b. Preparations have been made for the initiation of shutdown l cooling.

c. You are the performing the duties of the Unit 1 ABO.

1. Task Standard:

This JPM is complete when the 11 LPSI pump has been started and the . temperature is being controlled within the identified limits.

2. The CRO at IC43 has directed you to open the shutdown cooling return isolation valve [ step Dl], open the shutdown flow control valve [ step DJ], & after the pump is started - control temperature [ step DJ thru DM).

( 9 6 of 9 Rev.O

CCNFP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP 9A I TASK: Manually Control 1. PSI Temperature ELEMENT STANDARD

            * = Critical Step TIME START CUE:

Supply the operator with a copy of AOP-9A. Identify AOP-9A, step DI. Same as element. Step D1

1. Obtain a hand held digital thermometer to Retrieves thermometer measure the Shutdown Cooling Heat Exchanger Outlet temperature.

CUE When asked or checked: 1-SI-651-MOV is SHUT. You are instructed to OPEN the SDC HDR RETURN ISOL valve 1 SI-651-1 MOV.

2. Operator opens MOV manually Operator simulates opening

        '                                                                the SDC HDR RETURN ISOL valve.

CUE The SDC HDR RETURN ISOL valve is f OPEN - (stem position) ! 3. Notify 1C43 that the Shutdown Cooling Operater makes notification. Header Retum Isolation,1-SI-651-MOV, is open

4. Go to the Component Cooling Room Operator goes to CC toom.

Step DJ

1. Manually throttle open the Shutdown Cooling Operator locates valve and Flow Control Valve,1-SI-306-CV, to obtain a simulates opening tol inch of 1 inch stem rise, stem rise.

l CUE The Shutdown Cooling Flow Control Valve has a 1-inch stem rise. I

2. Notify IC43 that the Shutdown Cooling Flow Operator makes notification Control Valve is throttled. Have the IC43 and request.

notify the RO to START 11 LPSI PER Step DK. CUE The 11 LPSI pump has been started per step DK. Notify the ABO to operate 1-SI-306-CV. 7 of 9 Rev.0

CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP 9A t TASK: Manually Control LPSI Temperature ELEMENT STANDARD

       * = Critical Step Step DL

1. Then slowly open Shutdown Cooling Flow Operator simulates opening Control Valve,1-SI 306-CV, until the total shutdown cooling flow stem rise is one and one-halfinches, control valve until the total stem rise is one and one-half inches. l CUE The Shutdown Cooling Flow Control Valve,1 SI-306 CV, stem rise is one and one-halfinches.

l 2. Notify 1C43 that Shutdown Celing flow has Operator makes notification. been established. Step DM .

1. Establish communications with IC43. Operator simulates communications with IC43.

Should locate equipment that would meet this need.

2. Manually adjust the Shutdown Cooling Operator locates shutdown Temperature Control Valve,1 pl 657-CV, to cooling temperature control approach, but NOT exceed,14 F per minute valve and monitors heatup rate on the inlet side of 1-SI-657-CV temperamre, as determined by the hand held Digital Operator should have Thermometer, equipment /means to establish the heatup rate. [ watch]

TIME STOP TERMINATING CUE: This JPM is complete when the operator takes two sets of temperature readmgs i 8 of 9 Rev.0

CCNPP LICENSED OPERATOR

   ,                                                                    JOhi PERFORMANCE MEASURE AGP 9A
       - TASK:                                                           Manually Control LPSI Temperature ELEMENT                                                                                            STANDARD l
           ' = Critical Step I

l NOTES: i The operator's wrformance was evaluated against the standards contained in this JPM and determinec to be l l SATISFACTORY [~ l UNSATISFACTORY EVALUATOR'S SIGNATURE: DATE: 90f9 Rev.0

                                                                                                                                 . - _ J

                                                                                       ;    i        ,i Calvert ClllT: Nrcle:r P:ner Plant JPM Q:esti:a (a)

Title i Safety Injection K/A 0005000A101 [3.5/3.6] Question a: Why is the heat up limited to 14'F per minute? Answer Limit is bases on the heat exchanger design, Reference Use Allowed? NO Reference 1 AOP-3A Reference 2 i Comments: I l Satisfactory l IUnsatisfactory Candidate

   ,                                                l of 2 JPM #9 Question (a)

Safety Injection Revised 10/17/97 i

C:lvert Cliffs Nuclear Prier Plant JPM Q:esti:2(b) ., Title Safety Injection K/A 191004K104 p.3/3.4) Question b: Why does step DJ l have you ope'ning 1-SI-651-MOV [ Shutdown Cooling Flow Control Valve) to obtain 1 inch of stem rise? Answer Prevent the LPSI Pump from operating against a shutoff head. Reference Use Allowed? NO Reference 1 AOP-9A/ Bases, page 11, DJ Reference 2 i Comments: I I I I l l Satisfactory l l Unsatisfactory Candidate i 2 of 2 JPM #9 Question (b) Safety Injection Revised 10/17/97

w , . . 7 CCNPP LICENSED OPERATOR

   ,v                       JOB PERFORMANCE MEASURE AOP 1 A-1N f-SYSTEM:   Chemical and Volume Control System TASK:     020060308      Respond to Innovertent Dilution While Critical PURPOSE:  Evaluates an Operator's Ability to Respond to an inadvedent Dilution and Isolate Potential Dilut5n Paths.

JOB PERFORMANCE MEASURE l CALVERT CLIFFS NUCLEAR POWER PLANT . LICENSED OPERATOR TRAINING I, PREPARED BY: DATE: REVIEWED BY: DATE: Operations Instructor - Nuc REVIEWED BY: DATE: SRO License Holder ( APPROVED BY: DATE: Ops Training Supervisor Rev.0

                                                                                                          . .-. . J

Page 2 O CCNPP LICENSED OPERATOR

 ,                         JOB PERFORMANCE MEASURE AOP-1 A-IN TASK:         020060308      Respond to Inadvertent Dilution While Critical PERFORMER'S NAME:

APPLICABILITY: RO and SRO PREREQUISITES: Completion of the knowledge requirement of the Initial License class training program for the Chemical and Volume Control System. EVALUATION LOCATION: l

            ,_X       PLANT                     SIMULATOR                       CONTROL ROOM i

EVALUATION METHOD: ACTUAL PERFORMANCE DEMONSTRATE PERFORMANCE ESTIMATED TIME ACTUAL TIME TIME CRITICAL TASK: TO COMPLETE JPM: TO COMPLETE JPM: 15 MINUTES MINUTES NO j TASK LEVEL: LEVEL 1 TOOLS AND EQUIPMENT: None REFERENCE PROCEDURE (S): AOP-1 A TASK STANDARDS: This JPM is complete when the potential dilution paths are verified isolated and a report is made to the control room. ( I

o Page 3 CCNPP LICENSED OPERATOR i JOB PERFORMANCE MEASURE AOP-I A-IN TASK: 020060308 Respond to inadvertent Dilution While Critical DIRECTIONS TO EVALUATOR:

1. Read the " Directions to Trainee" to the trdnee.

2. Note the time that the task is started, As the task proceeds, indicate completion of each element using the Standard criteria and the lollowing notation:

                                       "S" for satisfactory completion "U" for unsatisfactory completion i
                                       "N" if not observed OR not verifiable Critical elements must be observed or the evaluation is invalid.

3. When the Terminating Cue is reached, tell the trainee that no further actions are necessary Note the completion time.

l 4. Document any instances ofincorrect performance in the Notes area (required for ' critical steps). j 5. Questions should be asked after completion of the task.

6. Indicate whether the task was completed satisfactorily on the basis of correct xrformance of all critical elements and completion of the task within the 3stimated Time to Complete for Time Critical tasks.

7. This JPM contains the steps, notes, cautions, and standards that are applicable to the initial conditions specified in this JPM. Steps that do not directly relate to this JPM, but appear in the procedure, are not listed here. It is the responsibility of the evaluator and/or observer to become familiar with the procedure prior to use of this JPM.

i

. Pige 4 CCNPP LICENSED OPERATOR o JOB PERFORMANCE MEASURE AOP-1 A 1N i TASK: 02006030S Respond to Inadvertent Dilution While Critical JPM STANDARDS (List of minimum Standard Practices for common evolutions at CCNPP) 1.0 Starting a pump if non-emergency condition, dispatches a PO to verify pump is ready to be started. Identify the Control Switch and Indicating Lights, usmg authorized identification. Operate the Control Switch, to START, and check expected Indi:ating Light response. Check proper pump operation (as applicable): Motor amps Pump discharge pressure System How Activation / Clearing of applicable Annunciators (e.g.; Hi Disch Press, Lo Hdr Press) 2.0 Stopping a pump Identify the Control Switch and Indicating Lights, using authorized identification. Operate the Control Switch, to STOP, and check expected Indicating Light response. Check expected system response (e.g.; Dow, pressure, level) 3.0 Operating Control Valves / Motor Operated Valves / Circuit Braakers i Identify the Control Switch and Irdicating Lip, hts, using authorized identi6 cation. Select the Control Switch to the desired position. Check Valve / Breaker position, using position Indicating Lights. Check expected system response (e.g.; Dow, pressure, level, volts, amps, KW) 4.0 Checking Valve / Breaker position Identify the Valve / Breaker Indicating Lights, using authorized identification, Check the Valve / Breaker is in the correct posit! n. If Valve / Breaker is not in correct position, report Valve / Breaker position to CRS. 5.0 Verifying valve / breaker position Identify the Valve / Breaker Indicating Lights, using authorized identification. Check the Valve / Breaker is in the correct position. if Valve / Breaker is not in correct position, operates Valve / Breaker to correct position. 6.0 Locally starting a pump Verify the following: Suction Valve open Discharge Valve position (as applicaMe) Mininow Valve position (as applicable) Pump and Motor oil levels are normal Adequate Suction Pressure g identify the Control Switch and Indicating Lights, using authorized identification. Operate the Control Switch, to START, and check expected Indicating Light response.

Pcge 5 D CCNPP LICENSED OPERATOR

JOB PERFORMANCE MEASURE AOP-1 A IN i

TASK: 020060308 Respond to inadvertent Dilution While Critical Check for proper Pump operation (as applicable): Smooth, quiet operation consistent with pump history

           -         Oillevel remains good
           -         Proper sealleakoff Proper discharge pressure Expected system flow 7.0   .meally stopping a pump identify the Control Switch and Indicating Lights, using authorized identincation.

Operate the Control Switch, to STOP, and check expected Indicating Light response. Check expected system response (e.g.; flow, pressure, level).

8.0 Operating a Manual Valve Identify the Valve, using authorized identification.

Operate the Valve and check expected position indication change (e.g.: stem rise, pointer). Check expected System response (e.g.; Ouid flow sounds, pressure changes, tank levels). 9.0 Locally operating Control Valves / Motor Operated Valves / Circuit Breakers identify the Control Switch and Indicating Lights (if applicable), using authorized identification. 1 i' Operate the Control Switch and check expected Indicatmg Light response. Check expected System response (e.g.; flow, pressure, levels, volts, amps). 10.0 Locally checking Valve / Breaker position identify the Valve / Breaker, using authorized identification. Check the Valve / Breaker is in the correct position, using appropriate position indication (e.g.; pointer, stem rise, Dags, indicating lights). If Valve / Breaker is not in correct position, report Valve / Breaker position to Control Room. 11.0 Locally verifying Valve / Breaker position identify the Valve / Breaker, using authorized identificaC *n, Check the Valve / Breaker is in the correct position, using appropriate position indication (e.g.: pointer, stem rise, flags, indicating lights), if Valve / Breaker is not in correct position, operates Valve / Breaker to correct position. I o

 ,                                                                                                     Page 6 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP-1A-1N I

TASK: 020 % 0308 Respond to inadvertent Dilution While Critical DIRECTIONS TO TRAINEE:

1. To complete the task successfully, you must perform each critical element correctly. -You must inform the evaluator of the indications you are monitoring.

Where necessary, consider the evaluator to be the CRS, 2, Initial Conditions:

a. Unit 1 is in Mode I at 100% power.

b. Regulating CEAs are fully withdrawn.

c. Reactor power unexpectedly begins to increase,

d. RCS boron concentration indicated on the boronometer has dropped.

! c. Operator actions as directed in AOP-I A, INADVERTENT l BORON DILUTION, Section V have been completed through Step C.l.a. t

e. You are performing the duties of an extra RO on shii).

l 3. Task Standard: This JPM is complete when actions have been taken check and isolate potential dilution paths in the plant.

4. Initiating Cue: The CRS directs you to locally verify the CVCS Lineup and Isolate any potential dilution paths per AOP-1 A, Section V.C, Operations actions only. Notify the Control Room if any actions taken. Are there any questions?

You may begin.

Pcge 7 CCNPP LICENSED OPERATOR JOB PERFORMANCE MEASURE AOP 1 A 1N i l ELEMENT STANDARD (* = CRITICAL STEP) TIME START NOTE TO EVALUA TOR : Supply the operator with a copy ofAOP !A. V. C. DETERMINE POSSlHLE SOURCES OF DILUTION

1. Verify correct lineup of the CVCS CUE: The Unit I CR0 has correctly aligned the VCT Makeup Control Valve Centrollers,

a. Ensure VCT M/U Control Valve Determines action has been Controllers are in MANUAL and 0% performed. .

output: e 1 FIC-210X

l FIC 210Y l

NOTE TO EVALUA TOR : Report ofconditl~ns m; r be made at any time during performance ofs ctions. The last step in JPMprovidesfor summary ofthese reports. CUE: The inservice purification IX has been in its current alignment for the hst 10 months. It does NOT contain deborating resin.

a. Ensure that any PurHication IXs Dete: mines action is NOT with deborating resin or unborated resin required, are removed from service PER Ol 2D PURIFICATION SYSTEM OPERATION.

h CUE: When checked or asked: 0 DW 190 is shut (Stem position, local indication),

a. Ensure IX FLUSH ISOL valve,0- Locates valve behind the 11 DW 190 is shut. Boric Acid Batching Tank and determines valve is shut.

2. Isolate any chemical additions.

4 _ _ = _ = _ _ - J

Page 8 CCNPP LICENSED OPERATOR . .. JOH PERFORMANCE MEASURE AOP.l A IN l ELEMENT STANDARD (* = CRITICAL STEP) _ CUE: When checked or asked: The Chemical Addition Metering Pump is NOT running (Control to STOP, Motor / shaft not rotating).

a. Verify that the Chemical Addition Locates Chemical Addition Metering Pump is secured. Pump in NW BAST room

[ BAST room S Wall and determines pump is s]ecured. 1 CUE: When checked or asked: __l CVC 300 is partially open (Stem position, local indication, ' handwheel rotates in BOTil directions) !

b. Verify shut RCMW TO CliO PP J

Locates valve at NE BAST RM SUCTION 1 CVC 308. [ BAST RM E WALL], detemtines valve is NOT shut.

CUE: When checked or asked: ._l CVC 258 ' , shut (Stem position, local indication).

( c. Verify shut CliEM ADD TK Locates valve at NW BAST RM INLET 1 CVC 258. [ BAST RM S WALL] and determines valve is shut. , CUE: When checked or asked: ._l-CVC 338 is shut (Stem position, local indication).

c. Verify shut CHEM ADD & Locates valve at NE BAST RM MTRO TK COMB DISCH 1 CVC 338, [ BAST RM S WALL] and determines vahe is shut.

CUC: When notification indicated: Acknowledge report.

4. Notify the Control Room of action taken to Contact control room and make close.1 CVC 308, report on valve operations. ;

TIME STOP TERMINATING CUE: This JPM is complete when the chemical addition components are in there correct conditions. No further actions are reqmred, i

l' Page 9 CCNPP LICENSED OPERATOR i JOH PERFORMANCE MEASURE AOP 1 A lN TASK: 020060308 Respond to inadvertent Dilution While Critical t NOTES: i i The operator's xrformence was ovaluated against the standards contained in this JPM-and detenninec to be SATISFACTORY UNSATISFACTORY EVALUATOR'S SiONATURE: DATE: m.,--,me -m,esere-.ee-+-,-.-r--,- . . , , , - - , - , ,.~,,,,,m,--,.-,--, -.w,-- - - - , _ . -e.-- .--, . , , . .v.,. .,,n, -cm ,.~r,4a- . - - - -~-

                                                                                                 . . . ld

. !i u Calve:1 Cliffs Nrclear Power Pla:t JPM Q:esti:3 (a)

Title ( CYC K/A 004000A110 [3.7/3,9] Question at Unit 1 is in Mode 5 and the current count rate is 800 cps. The shutdown monitor ALARM SETPOINT RESET is depressed at this Indicated count rate. At what value (count rate) would the shutdown monitor alarm is a slow dilution event occurred? Answen 1200 cps, (800 x 1,5) Reference Use Allowed? NO

                    !!crerence 1 Lesson Plan CRO 57-1 11, LO #3.1 & 3.2, page 32 Reference 2 i

Comments: I I Satisfactory l IUnsatisfactory Candidate l of 2 JPM #10 Qiestion (a) CVC Revised 10/17/97

7 Calvert Cliffs N:: clear P:wer Pla:t JPM Q:esti:3(b) Title ( CVC K/A 010000G132 l3.4/3.8) Question b: When perfonning a plant shutdown from ilot Standby to Cold Shutdown, why is the lowering of RCS pressure done as a constant evolution instead ofin steps? ! Answer Continuous cycling of the valves (whether normal spray or Aux Spray) may result in excessive thermal transients on the PZR spray nonles and piping. Reference Use Allowed? YES Reference 1 OP.5 Rev. 34/ Unit 1 Precaution 5.0.11, page 13 I Comments: I I I I I I Sadsfactory I IUnsatisfactory Candidate ( 2d2 JPM #10 Question (b) CVC Revised 10/17/97

.)

7 , 11/97 NRC EXAM ADMIN Initial Training Unit 1 T0: Im litiggs, Chicf Examin ~ FROM: R. Niedzielski

'/

SUll3: 3( Followup request for in irmatio DATE: December 4,1997 Attached is additonal infonnation per your request to clarify the post exam comment submittal. The information that is included: SRO Written exam questions 15, 50, 67, 74, 80, 90 and 99 Copy of RO Exam administered on 11/12/97 Scating arrangement for written exams administered on 11/12/97 1 discussed with the Written Exam Proctor (J. Tox)if any questions were asked for funher clarification during the test, lie stated that questions were asked but no additional clarification was given for SRO questions 23,50,67,80 and 100 (RO questions 24,57,72, and 98). The seating arrangement used 3' X 5' tables, one person per table in classroom 7 NOF. The lisam Security agreement will be sent to you separately (including our exam development contractor). If you have any questions, please call me at 410 495 6542. Thanks. cc: C.C.Zapp C. D. Sly m J

? 11/97 NRC EXAM DEVELOPMENT Initial Training Unit TO: L. D. Briggs, Chief Examinor FitOM: R. E. Niedrielski, Supervisor, ITU SUlus 11/97 initial Exam Outlines DATE: September 17,1997 I have attached the required outlines for the 11/97 NRC Initial license Exams at Calvert Cliffs Nuc!:ar Power Plant per Nureg 1021 Interim Revision 8, ES 201. In accordance with Attachment 1 of ES 201, the enclosed materials "shall be withheld frott, public disclosure until the examinations are complete". I have included form ES 201 2 with the test outlines, if you need any additional information , please don't hesitate to call me at: (410)495 6542 I (410)4954542 fax l 2270 Sincerely,

          ,      .x < &

R.E. Ni difelsk '

                                                                                                         ~~' ^
    ~          ~ ~ ~  ~~                                                    ~~      ~ ~ ~         '

l 11/97 NRC EXAM ! Initial Training Unit TO: Mr. L. Briggs, Chief Examiner USNRC Region i FROM: R. Niedzielski SUILI: Written Exam Question Submittal DATE: October 14.1997 The questions for the RO and SRO Written Exams are enclosed. I have submitteed the questions in the review format, one question per page. 'Ihe package also includes the ES 4016 Quality Assurance checklist. The JPMs and Simulator Scenarios will be mailed to you in a separate mailing by Thursday afternoon, to be delivered to you on Friday October 17,1997. If there are any questions, please call me at 410 495 6542 or you can reach me at my e mail address: ROBERT.E.NIEDZIELSKl@BGE,COM Thank You.

CALVERT CLIPPS NUCLEAR POWER PLANT . NRC EXAM 11/17/Iri 3 OPERATING EXAM. SIMULATOR CREW ROTATION CANDIDATES: 3 SRO(l)' 3 SCENARIOS WITH I SPARE 2 SRO(U) 3 RO Ld E94VeNB NdESAf4 $CENARIOS (U$fNG #2

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CALVERT CLIPPS NUCLEAR POWER PLANT . NRC EXAM 11/17/97 h OPERATING EXAM. $1MULATOR CREW ROTATION CANDIDA'lIS: 3 SRO(!) 3 SCENARIOS WITH 1 SPARE 2 SRO(U) 3 RO DAY ONB: 4 SCENARIOS (USING #1 AND #2)

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(2 CANDIDATES,2 IN. PLANT JPM) START ADMIN NOTE: The in plant JPM: into the RCA may best be started ~3PM due to lengthy lines from rad area entry briefs. DAY THREE 48 JPMS (6 CANDIDATES 7 SIMULATOR JPMS) (2 CANDIDATES,3 S!MUlf. TOR JPMS) COMPLETE ADMIN 8 W poen > / Post it" brand fax transmittal memo 7671

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l l l l 11/97 NRC EXAM REVIEW Operations Tralalog Unit poet.it%snd far transmittal memo 7571 8 of m * $

l. & "~ Y Al6 W )3td TOs C.C.Empp "U5W Wl Ed MS1FAO FROMi R. B. Niedzieleki C " 't/s) cMr g i SUBJ:

DATE: Post NRC r.xam r iew January 6,1998 ruep p g =a g gjo i Based on our discussions, I propose the following items for post NRC Exam follow up: i 1. Individual candidate Post Exam review and remediation per LOIT Program

                       ' Manual (Use Supplemental Training Assignments (attachment $). One en One review with each candidate on the NRC Exam results fbr the written test, Op*.atms Tset and walkthough portions as menticond in the letter from Mr. O. W.

Meyer, Chief, NRC Region 1 dstad 12/22/97. RI: D. Taeders ECD: 2/6/98

2. Remediate and prepare SRO(T) for NRC Written Test RI: TBD ECD: 2/27/98

3. Develop and Adnunister NRC Wrinen Test RI: R. Niarbielski ECD: 3/4/98

) 4. Program review end incorporanan of any required chcnges to the LOIT Program per TG.9 (Examinations) for both the written exam and opernung test portion. The post exam reviews have identi5ed the fo'llowing program items: Written Exam Rewrite Questicas: SRO15 ERPIP C!="Mh SR022(R023). CYCS Flowpv.h SR036(RO42b DSS trip SR039(RO47b Cavity Coolms Fan response SRO40(RO48F CS flow response SR067(R072b MCC 10?!aes ofpower R076 PlantresponsetoPZRheaters RI: R. Niedziehki ECD: 2!098 e

e .

        - --                                                                                                                   e Enhance luson plan:                                                                                       1 I

SR043(RO49)IRU flowpaths SRO$6 Dinel Generator Response on Loss of Off-site Power SR080 Two phue Natural Circulation RI: per CRO 97 Class Schedule ECD: t/10/98 NOTE: the above questions wers all newly developed for the 11/97 NRC Exam. De feat test coa 5guration for RO exam was 90% newly dnM quwtions and 97% new questions for the SRO Exam. JPM: Enhance Lesson plan: Raasons for filling Containment Sump MOV Suetion lines RI: per CR0 97 Class Schedule ECD: 8/10/98 Simulator Scenarios: no Program needs identified

5. Assess the NRC Exam Procus :nd provide recommendations to improve the effectiveness and efficiency.

RI: R. Niedzielski ECD: 2/6/98

6. Develop in-hocse NRC Exam development capability.

RI: C, Zapp R. NidrialM ECD: 6/1/98 cc: J.Hornick M. T. Nasin ITU Instructor 'l

                                           .       e 11/97 NRC EXAM Initiallraining Unit TO:               L. litiggs, Chief Examiner          i FROM:            R. Niedzielski                t/

SUILI: Exam Comments i b y 20 p j DATE: November 21.1997 Attached are the comments and additional material as you requested for the 11/97 RO and SRO initial License Exams administered on 11/12/97 end during the week of 11/17/97 at Calvert Cliffs. I have learned and experienced the efTort and complexities of developing and administering a NRC Exam per Nureg 1021. The goal to develop and administer and fair and equitable exam for operators is very labor intensive and requires clear communication between the Licensee and the Region 1 Examiners.1 hope that I met your expectations. De resources required to accomplish this process are much clearer to me now and future exams will benefit from this experience. I will be available next week Monday and Tuesday for any questions or information you need to complete the exam process. Please call me at 410 495 6542 and leave me an Urgent Voicemail to reach me when I am out of the office. Thanks. cc: N. L. Millis C.C.Zapp

NRC WRIT FEN EXAM PROCESS DEVELOP OUTLINE DEVELOP QUESTIONS 132 new questions from CCNPP material (no audit exam duplication) In house Review On shin SRO S.11U Comment resolution by Contractor l'inal review for NRC Submittal On. shift SRO Test Validation 2 hours (no answer validation, with no reference provided) 8M6 comments on 2 questions (16,88)

  '.uDATEEXAM 3 NRC Examiners Contractor S-11U Substitute 10 questions from CCNPP Exam bank due to 6ystem distribution concerns O SRO questions 3 common questions 7 RO questions Major rewrite of 14 questions for clarity, SRO level:

11 SRO questions 3 common questions iRO quastion INCORPORATE COMMENTS ADMINISTER EXAM PER ES 402 2 questions needed clarification Ilackround noise from adjacent classrooms and cafeteria was a concern. COLLECT EXAM l'EED11ACK Individual questions comments and general exam feedback VALIDATE EXAM IW On. shift SRO and RO SRO 8096(I hour w/ exam references) comm:nts on 18 questions RO 8996(1.5 hours w/ exam teferences) comments on 9 qt estions GRADE AND EVALUATE EXAM PER ES-403 INITI AL grade and evaluation: RO EXAM SRO EXAM INDEPENDENT grade and evaluation

I'*, UNITro sT Af ts [d 5 -I n NUCLEAR Hr0ULATORY COMMISSION

Rf GloN i 476 ALLtNDAtt ROAD

            ,'s,                                          AINO or PRUsslA. PENNSYLVANIA 194301416 Mr. Robert Niedzielski                                                   '

Supervisor Initial Training Baltimore Gas & Electric Co. Calvert Cliffs Nuclear Power Plant 1650 Calvert Cliffs Parkway Lusby, Maryland 20057

Dear Mr. Niedzielski:

The purpose of this letter is to inform you of the individual examination results for your applicants on the initial examination conducted on November 12 21,1997, at your facility. This meets the intent of section E.1 of the Examiner Standards (ES 501)in NUREG 1021. This information is considered to be " proprietary" in accordance with 10 CFR 2.700 and it supplements the information contained in the refeted examination report for your f acility which will be issued shortly. Enclosure 1 is the completed ES 5012, Power Plant Licensing Examination Results Summary, and is a summary of overall examination resu'ts.

Enclosure 2 contains the individual results ES 3031 and 303 2, Operator License Examination Report, (NRC Form 157) for each applicant. Contained therein are the deficiencies noted for each applicant. In accordance with your Systems Approach to Training (SAT) Program, we expect that you will review these results and provide appropriate remedial training for these individuals independent of their overall pass status.

Each applicant has authorized the release of this information to your facility by sign!ng Block 19A of NRC Form 398. Enclosure 3 are copies of the licenses issued and letters for those who did not pass the examination. Thank you for your cooperation in this tr.atter. Please refer any questions you have to me at 610 337 5211. In rely, O

'~

f. tenn W. Meyer, Chief W I Operator Licensing and Human Performance Branch Division of Reactor Safety Docket Nos. 50 317/318 _ _ = _ I

Mr. R. iJiedzielski

Enclosures:

1. ES 5012, Power Plant Licensing Examination Results Summary

2. ES 3031 and 303 2, Individual Examination Results

3. Licenses and letters cc w/encls:

P. E. Katz, Plant General Manager PUBLIC

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

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[ 476 ALLFNDALE ROAD e . . . * ,e MNG or PRUsslA. PENNSYLVANIA 194061416 j December 22, 1997 Keith A. Drowii

P. O. Box 181 Lusby, MD 20657

Dear Mr. Drown:

i This letter is to inform you that you have passed the written examination and the operating

test, administered to you on November 12 21,1997, for a senior reactor operator license
for the Calvert Cliffs Nuclear Power Plant, Unit Nos.1 and 2. -

1 However, your license will not be issued at this time. Your grade on the written examination was 80.4% and we are concerned that revisions to correct answers or l deletions of questions from the written examination based on possible appeals from other applicants would result in your grade becoming less than 80.0E NUREG 1021, Interim Revision 8, ES 501, E 1 states: "the region shall delay issuing licenses to those applicants that passed the written examination with a grade of 82 percent or below until any written examination appeals have been reviewed for impact on the licencing decislens". , As the situation regarding possible appeals becomes clearer, wo v.ill evaluate the appropriatenest. cf withholding your license. 4 If you have any questions, please contact me at 610 337 5211. l Sincerely, 3 j N. I Glenn W. Meyer, Chief Operator Licensing and

 !                                                                                                      Human Performance Branch 4

Division of Reactor Safety Docket No. 55 61697 i

cc: R. Niedzielski, Supervisor Initial Training

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476 ALLENDAlt ROAD g....+ KING oF PRU$slA, PENNSYLVANIA iM041416 c 22, W Steven R. Sanders 110 Johnson Drive 1.usby, MD 20057 4

Dear Mr. Sar'ders:

This is to inform you that your grade on the written examination taken on November 12,1997, in connection with your application for a senior reactor oper-ator license for the Calvert Cliffs Nuclear Power Plant, Unit Nos.1 and 2, indicates that you did not pass.that examination. As a result, it is proposed that your application be denled. Enclosed is a copy of the examination results, indicating those areas in which you exhibited deficiencies. A copy of the master answer key is also provided. If you accupt the proposed denial and decline to req'sest either an informal NRC staff review or a hearing within 20 days, as discussed below, this proposed denial will become a final denial. You may then reapply for a license in accordance with Title 10. Section 55.35, of the Code of Federal Regulations, subject to the follow. ing conditions:

a. Because you passed the operating test, administered on November 17 20, 1997, you may request a walver of that portion,

b. Because you did not pass the written examination, administered to you on November 12,1997, you will be required to retake a written.

examination.

c. You may reapply for a license two months from the date of this letter.

A reexamination will be scheduled, upon request by your facility man-agement, shortly after your application is received, e vou do not accept the proposed denial, you may, within 20 days of the date of W3 letter, take one of the following actions: You may request an informal NRC staff review of the grading of your examination. Your written request must be sent to the Director, Divi-slon of Reactor Controls and Human Factors, Office of Nuclear Reactor Regulation, U. S. Nuclear Hegulatory Commission, Washington, D.C. 20555. Your request must identify the portions CERTIFIED MAIL-RETURN RECElPT REQUESTED

                                                                                       =
                                                                                           -U

                            ~- --  -

Steven R. Sanders of your examination that you believe were graded incorrectly or too severely, in addition, you must provide the basis, including supporting documentation, such as procedures, instructions, computer p'Intouts, and chart traces, in as much detail as possible, to support your con-tention that certain of your responses were graded Incorrectly or too severely. The NRC will review your contentions, reconsider your grading, and inform you of the results. If the proposed denialis sustained, you will have the opportunity to request a hearing pursuant to 10 CFR 2.103(b)(2) at that time. You may request a hearing pursuant to 10 CFR 2.103(b)(2). Submit your request, in writing, to the Secretary of the Commission, U. S.. Nuclear Requlatory Commission, Washington, D. C. 20555, with a copy to the Assistant General Counsel for Hearings, Office of the General Counsel, at the same address. Pursuant to 10 CFR 55.35, you maiy not reapply for a license until your license has been finally denied. Failure or'i your part to exercise either of the above options within 20 days constitutes a walver of your opportunity for informal review and your right to demand a hearing. For the purpose of reapplication under 10 CFR 55.35, such walver renders this letter a notice of final denial of your application, effective as of the date of this letter. If you have any questions, please contact me at 610 337 5211. Sincerely. Glenn W. Meyer, Chief Operator Licensing and Human Performance Branch Division of Reactor Safety Docket No. 55 62106

Enclosures:

As Stated cc w/o enclosures: . P. E. Katz, Plant General Manager R. E. Niedzielski, Supervisor, Initial Training r .j

.~

paaes, UNIT ED sTAf ts [ NUCLEAR REGULATORY COMMISSION 5 : MLGloN 1 475 ALLENDAlt ROAD

    *,'g .....                       KING oF PRUS$1A, PENNSYLVANIA iM36-1416 Joseph D. Austin                                         '

46699 Frogs Marsh Road Drayden, MD 20630

Dear Mr. Austin:

This is to inform you that your grade on the written examination taken on November 12,1997, in connection with your application for a senior reactor oper-ator license for the Calvert Cliffs Nuclear Power Plant, Unit Nos.1 and 2, Indicates that you did not pass that examination. As a result, it is proposed that your appli-cation be denied. Enclosed is a copy of the examination results, indicating those areas in which you exhibited deficiencies. A copy of the master answer key is also provided. If you accept the proposed denial and decline to request either an informal NRC staff review or a hearing within 20 days, as discussed below, this proposed denial will become a final denial. You may then reapply for a license in accordance with Title 10, Section 55.35, of the Code of Federal Regulations, subject to the follow-ing conditions:

a. Because you passed the operating test, administered on November 17 20,1997, you may request a waiver of that pcrtion.

< b. Because you did not pass the written examination, administered to you on November 12,1997, you will be required to retake a written examination,

c. You may reapply for a license two months from the date of this letter.

A reexamination will be scheduled, upon request by your facility man-agement, shortly after your application is received. If you do not accept the proposed denlal, you may, within 20 days of the date o' this letter, take one of the following actions: You may request an informal NRC staff review of the grading of your examination. Your written request must be sent to the Directur, Divi-sion of Reactor Controls and Human Factors, Office of Nuclear Reactor Regulation, U. S. Nuclear Regulatory Commission, Washington, D.C, 20555. Your request rnust identify the portions CERTIFIED MAIL-RETURN RECEIPT REQUESTED l

Joseph D. Austln of your examination that you believe were graded incorrectly or too severely. In addition, you must provide the basis, including sewoorting documentation, such as procedures, instructions, computer printouts, and chart traces, in as much detail as possible, to support your con-t,ention that certain of youl responses were graded incorrectly or too severely. The NRC will review your contentions, reconsider your grading, and Inform you of the results. If the proposed denialis sustained, you will have the opportunity to request a hearing pursuant to 10 CFR 2.103(b)(2) at that time. You may request a hearing pursuant to 10 CFR 2.103(b)(2). Submit your request, in writing, to the Secretary of the Commission, U. S. Nuclear Requlatory Comrnission, Washington, D. C. 20555, with a copy to the Assistant General Counsel for Hearings, Office of the General Counsel, at the same address. Pursuant to 10 CFR 55.35, you may not reapply for a license until your license has been finally denied. Failure on your part to exercise one of these options within 20 days constitutes a walver of ynur opportunity for informal review and your right to demand a hearing. For the purpose of reapplication under 10 CFR 55.35, auch waiver renders this letter a notice of final denial of your application, effective as of the date of this letter, if you have any questions, please contact me at 610 337 5211. Sincerely. Glenn W. Meyer, Chief Operator Licensing and Human Performance Branch Division of Reactor Safety Docket No. 55 62102

Enclosures:

As Stated cc w/o enclosures: P. E. Katz, Plant General Manager R. E. Niedzielski, Supervisor, Initial Training

                                        =                                                                     =
                                                                                               -..____m___- -   -

11/97 NRC EXAM Initial Training Unit TO: Mr. L litiggs, Chief Examiner US NRC Region 1 l' ROM: R. Niedziciski SUl1J: Simulator Scenarios and JPM Exam Material Submittal DATE: October 17,1997 The two binders with 4 Simulator Scenarios and ten JPMs (with two questions cach) are c#ncfosed I have enc:osed the ES 3013,3015 and 301-6 Quahty Assurance forms. If you have any questions, please call me at 410 495 6542 or e mail address: RollERT.E NIEDZlELSKigilGE COM. Thank You

EMERGENCY RESPONSE ASSEM11LY Initial Training Unit f f. -- l TO: CRO 96 FROM: R.1. Nied r.iciski k SUlu: ERHP Assembly DATE: November 21,1997 A question came up cencerning the proper location to assemble during Emergency Response Alert or higher declarations. A recem memorandum was distributed (attached) to help clarify the issue for the site, llowever, some additional guidance is in order due to the unique status of License Class candidates who may be scheduled on shin and/or carry the designation as " members of the Emergency Response Organiwlon" by Emergency Planning Unit. ASSEM11LY INSTRUCTIONS: If you are scheduled on shin, assemb' with your assigned shift in the Control Room. if you are in scheduled training, assemble with your class in your assigned classroom. The Class Coordinator will report the results to the AGS 0TU. If you are scheduled with a relief shift, assemble in the SSil Cafeteria with your relief shift. The AGS OTU (or alternate) will take the results and notify security per the ERPIP. I am currently assigned an ERPIP position and will not be in the OTF to perform this function. If you have any questions, please call me. cc: T. E. Forgette (Director, EPU) C.C. Zapp, AGS 0TU W.P.13irney, S RTU J. E. Macklin, S SSU

 ;                                                       MEMORANDUM
                                                                                 . ergency Planning Unit I

l TO: Calvert Cliffs S'u pervisbn FROM Director Emergency Planning SUILI: Site Assembly Accountability DATE: March 13,1997 The followin describes the site assembly / accountability procedures. This information in distributed annuall . Please review it with your personnel at your cons enlence. ASSEMilLY/ACCOUNTABILIIY When site assembly is required, everyone must go to a clesignated assembly area:

1. IF you liave a position in the Emergency Response Organization TIIEN your assembly area is your emergency center (i.e, the Control Room, Technical Support Center, Operational Support Center, South Service Huilding Cafeteria, Nuclea. Security Facility, Nuclear Engineering Facility, Emergency Operations Facility, or the Media Center). Accountability is checked by the center director and reported to security.

2. IF you are not in the emergency organization AND your regular work location is OUTSIDE the Protected Area TilEN your assembly area is your regular work location. The supervisor e his/her designee is responsible for reporting accountability to the Clifi Notes Mailbox, extension 7800.

3. IF you are not in the emergency organization AND your regular work location is INSIDE the Protected Area TilEN your assembly area is the OTF/NEF/NOF hallway. Assembly is in your designated area. itc supervisor or his/her designee is responsible for reporting accountability to the Cliff Notes Mailbox, extension 7800.

4. Contract Workers

a. IF a contractor worker is an integral part of a DGE group (e.g. Kelly Services, etc.) TIIEN they assemble with that group, in accordance with 2 or 3 above,

b. IF a contractor worker is not an integral part of a DGE group (e.g. crafts people, Bartlett, Fluor Constructors, Master 1.ee, etc.) TIIEN they assemble in Warehouse 3. Accountability is reported to ihe Cliff Notes Mailbox, extension 7800 by the Warehouse Assembly Area Leader.

4

  .              5.           Visitors                                                                                                    ,
  ?!                          IF you are a visitor (this includes any DGE employee not perm :ntly assigned 4 '                           to Calvert Cliffs and anyone that is signed in as a visitor) THEN you return to the place where you entered the Owner Controlled Area. At this location you will be en ounted for and asked in leave the site, t

Reports to the Cliff Notes Mailbox should include the six digit .mn ber for your group (depanment, section, unit) and any personnel who are missing. " Missing" people are people that are defmitely on site but not at tiie assembly area. People on vacation, sick leave, travel, etc. are not " missing". The attached flow diagram summarizes the site assembly / accountability procedcres. Accountability reports stauld be completed within 30 minutes. Personnel under your supervision that are in the Emergency Response Organization will nat be assembling with your group. Do not designate these people as alternates for group assembly leader. Thank you for your continuing cooperation in the site assembly / accountability procedures. If you have any questions or comments on this process or any other aspect of the Emergency Response Plan please contact me at extension 4996, i Director-Emergency Planning corresp\sitaccup. doc

ASSEMBLY INSTRUCTIONS

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I k a f, , 7,+ /%, To: Larry Briggs Bob Niedzielski From: Bob Scott

Subject:

Reactivity Manipulations , Date: November 6, 1997 Attached to this- letter is a list of the reactivity manipulations determined by our training unit to meet the intent of the NRC Information Notice 97-67. For power changes of at least 10% or significant reactivity additions associated with CEAs, boration, dilution, or coefficient feedbacks (cooldown/heatup) a candidate's name is indicated during the recent outage for 11B RCP seal outage. Furthermore, two candidates achieved additional reactivity manipulations prior to this outage for a dropped CEA that involved a total change in reactor power of 18% (9% down due to dropped CEA and subsequent recovery-of CEA per applicable plant AOP) , plant shutdown for U-2 Refueling outage, and subsequent startup from U-2 refueling outage.

1. Steve Sanders -- Dropped CEA (total change 18%)

and plant shutdown (CEAs/Boration from 50 to 0% and lower turbine load from 100% to 50%) 2. Joe Austin -- Raised U-2 Turbine Load from 30-40% during plant startup following 1997 U-2 refueling. If you have any questions about these manipulations please call me at 410-495-4957 or Bob Niedzielski at 410-495-6542.

    ' ~ 2Lf/ A Bob' Scott b
                   --m    e          _r       - . , , .                    .-

CONTROL MANIPULATION PLAN FOR UNIT ONE SHUT DOWN 9/12/97 AND SUBSEQUENT START UP There are 28 total manipulations needed for the six candidates, there are approximately 46 possible that meet the criteria for acceptable manipulations, Power Change Mn Turb/ Gen CEAs/Boration (0223A0205) (020600202,020600103)

    ,100% 00%                       A      h            '

B34 lieu u O b (020060466) 90% 80% B hm w@ C hW m M/eguy)(p 0 o 60o 60% 50% D m b E h gugg F , 50% 40 % F 40% 30% f/ D

                                                                         't4a.fnud
                                    ?                               ?

30% 20 % ? ? i 20% - 10% ? ? 10% - 00% ? ? Shut Down Reactor & Borate to S/D Concentration-U"'0600102, 020600103, 020600108) A M Cool Down & Depressurize RCS (020050116) p532Y-3tf'F Alm NS b 532aF - 332aF (020070454 Estab. LTOP) 3 f TV- Isp B (Adj.Stm Flow

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332oF 232aF (022030101 Enter Mode 4) 2320F - 132aF (Enter Mode 5) t 2ee'F- sadD 0201903 Adj, uD M m

   'leat Up & Pressurize RCS (020050116)-

132oF 232PF (022030101 Enter Mode 4) E 232oF - 332aF (022030104,022030105 Enter Mode 3) F 332aF 532oF Withdraw CEAs to Zero Power PDIL - (020600102, 020600103, 020600107)

                                                                    ? g           g h4 Take Reactor Critical (020600105)                                ? gg                   [<=

Enter Mode 1, Raise power to 15% (022030110) ? Atart Up and Load U1 Mn Turb/ Gen (0223A0101)

                                                                    ? Ju< [bvM

Power Change Mn Turb/ Gen CEAs/ Dilution (0223A020p (020600202,020600103) 20% 30% 30% 40% A C [At 380mt.- h (020060466) B A 40% 50% 50% 60% B D-M eh C - CARL 2 [S 60% 70 % F

                                         &MJ                        E DU Q4JA@

70 % 80 % E f F 80% 90% ? ? 09% 100% ? ? Notes:

1. Numbers in parenthesis are the tasks associated with that manipulation.

2. Letters indicate license candidates.

3. Question marks indicate no license candidate assigned.

11/97 NRC EXAM Initial Training Unit TO: Mr. L Briggs, Chief Enminer US NRC Region i FROM: R. Niedzielski SUBJ: Simulator Scenarios .9.nd JPM Exam Material Submittal DATE: October 17,1997 Re two binders with 4 Simulator Senarios and ten JPMs (with two questions each) are enclosed. I have enclosed the ES 3013,301 '. and 3016 Quality Assurance forms. If you have any questions, please c:til me at 410 495-6542 or e-mail address: ROBERT.E.NIEDZIELSKlgBG1COM. Thank You. 4 lf}}

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3.0 REFERENCES

3.0 REFERENCES

References:

References:

Dear Mr. Niedzielski:

Enclosures:

Dear Mr. Drown:

Dear Mr. Sar'ders:

Enclosures:

Dear Mr. Austin: