Text

2010 Monticello Nuclear Generating Plant Initial License Examination Administered Simulator Scenarios
	ML110260275
Person / Time
Site:	Monticello
Issue date:	12/17/2010
From:	Mcneil D; Operations Branch III
To:	; Northern States Power Co, Xcel Energy
References
	50-263/10-301
	Download: ML110260275 (107)
	v • d • e

Monticello NRC EXAM Scenario 1 Appendix D Scenario Outline Form ES-D-1 Facility: Monticello Scenario No.: NRC Scenario 1 Op-Test No.: 2010301 Examiners: __ ___ _______________ Operators: _____________________________

Initial Conditions: 100% Power HPCI is Inoperable

12 CRD Pump Inop Turnover: Shift RBCCW Pumps Event No.

Malf. No.

Event Type*

Event Description 1

None N

BOP BOP shifts RBCCW pumps.

2 NI13C I

ATC/SRO APRM #3 fails upscale. With the updated nuclear instrumentation, a 1/2 scram does not occur. Tech Specs are referenced and APRM #3 is Bypassed. (TS) 3 RC02 02-S17-04 (Ovrd)

C BOP/SRO Inadvertent RCIC start. The trip pushbutton will also fail to shutdown RCIC, requiring an alternate shutdown method (TS) (ABN) 4 04-A2S70-04 (Ovrd)

C BOP/SRO EPR Failure. The MPR starts controlling but must be adjusted lower to maintain Core Thermal Power within limits. (ABN) 5 CH01_65 C

ATC/SRO Rod Drift Out (42-27). The rod is inserted, declared inoperable, and disarmed. (ABN) 6 TU03 G, H, & I R

ATC/SRO Turbine bearing vibrations begin to increase. Rapid Power Reduction is performed in response. (ABN) 7 RR01B M

Crew A small leak begins inside the Drywell. EOP 1200 is performed with no further challenges. EOP 1100 is entered. Alternate Level Control actions are performed when the Feed Pumps and RCIC fail.

Emergency Depressurization is performed and RPV level is restored with low pressure systems.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor ES-301-4 Quantitative attributes:

Total Malfunctions (5-8): 6 Malfunction(s) after EOP (1-2): 1 Abnormal Events (2-4): E3, E4, E5, E6 Major Transient(s) /E-Plan entry (1-2): E7 EOPs (1-2): 1100 & 1200 EOP Contingencies (0-2): 2 (ALC, ED)

Critical Tasks (2-3): 2 ES-301-5 Quantitative attributes:

BOP Normal: E1 ATC Reactivity (1 per set): E6 BOP I/C (4 / set): E3& 4 ATC I/C (4 / set): E2 & 5 SRO-I I/C (4 / set inc 2 as ATC): E2, 3, 4, & 5 SRO Tech Spec (2 per set): E2, E3, E5 ALL Major Transients (2 per set): 1

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SIMULATOR EXERCISE GUIDE (SEG)

SITE:

MONTICELLO SEG #

ILT-SS-11E SEG TITLE:

2010 ILT NRC 1 REV. #

0 PROGRAM:

INITIAL LICENSE TRAINING MT-ILT COURSE:

NRC EXAM M-8119 TOTAL TIME:

1.5 HOURS Additional site-specific signatures may be added as desired.

Developed by:

Instructor Date Reviewed by:

Instructor (Simulator Scenario Development Checklist.)

Date Validated by:

Validation Lead Instructor (Simulator Scenario Validation Checklist.)

Date Approved by:

Training Supervision Date

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Guide Requirements Goal of Training:

ILT NRC Exam Learning Objectives:

1.

Demonstrate the ability to predict and/or monitor changes in parameters associated with operating system controls for the appropriate tasks.

2.

Demonstrate the ability to correctly use procedures to correct, control, or mitigate the consequences of normal and abnormal operations for the appropriate tasks.

3.

Demonstrate the ability to monitor automatic operations of the systems to ensure proper operation for the appropriate tasks.

4.

Demonstrate the ability to manually operate and/or monitor systems in the control room in accordance with approved procedures for the appropriate tasks.

5.

Demonstrate the ability to complete administrative requirements, as necessary, in order to operate the plant for the appropriate tasks.

6.

Demonstrate knowledge of and ability to implement shift supervision duties as they relate to crew operations for the appropriate tasks.

7.

Given a degrading or improving plant condition or event, demonstrate the ability to: (CRS)

a. Evaluate trends that may result in equipment damage or reduction in plant safety.

b. Ensure proper diagnosis of plant problems by monitoring and interpreting data (information from panel indications).

c. Evaluate and diagnose challenges to Critical Plant Parameters.

d. Evaluate events and accidents.

Prerequisites:

1.

Completion of MT-ILT Training Program Training Resources:

1.

Full Scope Simulator

2.

3139 (Control Room Shift Turnover Checklist)

3.

3140 (Shift Supervisors Office Shift Turnover Checklist)

4.

Simulator Driver

5.

Simulator Phone Talker

6.

Operations Representative

7.

Evaluators

References:

1.

B.01.03-05 (CRD)

2.

B.02.05-05 (RBCCW)

3.

B.05.01.02-05 (POWER RANGE NEUTRON MONITORING)

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4.

C.4-B.01.03.C (CONTROL ROD DRIFTING)

5.

C.4-B.04.01.F (LEAK INSIDE PRIMARY CONTAINMENT)

6.

C.4-B.05.09-B (MAIN STEAM PRESSURE REGULATOR FAILURE CAUSING INCREASED PRESSURE)

7.

C.4-A (REACTOR SCRAM)

8.

C.4-F (RAPID POWER REDUCTION)

9.

C.4-G (INADVERTENT ECCS INITIATION SIGNAL)

10. C.4-K (IMMEDIATE REACTOR SHUTDOWN)

11. C.5-1100 (RPV CONTROL)

12. C.5-1200 (PRIMARY CONTAINMENT CONTROL)

13. C.5-2002 (EMERGENCY RPV DEPRESSURIZATION)

14. C.5-3203 (USE OF ALTERNATE INJECTION SYSTEMS FOR RPV MAKEUP)

15. C.5-3204 (RPV MAKEUP WITH CRD)

16. C.5-3502 (CONTAINMENT SPRAY)

17. C.5-3503 (DEFEAT DRYWELL COOLER TRIPS)

18. C.6-004-A-14 (RCIC LOW FLOW)

19. C.6-004-B-35 (DRYWELL-TORUS HI PRESS)

20. C.6-005-A-22 (APRM UPSC/INOP TRIP)

21. C.6-005-A-27 (ROD DRIFT)

22. C.6-007-B-15 (EPR TROUBLE)

23. C.6-007-B-33 (TURBINE VIBRATION HIGH)

24. Tech Specs Section 3.3

25. Tech Specs Section 3.5 Commitments:

1.

None Evaluation Method:

ILT NRC Exam Operating Experience:

Not Applicable / ILT Exam

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Related PRA Information:

Initiating Event with Core Damage Frequency Contribution:

Internal Flood (36.8%)

Station Blackout (27.4%)

Loss of High Pressure Injection (13.4%)

ATWS (11.4%)

LOCA (7.7%)

Loss of Low Pressure Injection (2.0%)

LOCA Outside Containment (0.6%)

Loss of Containment Heat Removal (0.4%)

Important Components:

EDGs HPCI RCIC Scram Feed/Cond SRV (When stuck open)

SRVs Instrument AC Fire System (for RPV Injection) 4160 VAC Important Operator Actions with Task Number:

CR314.101, Emergency Depressurize CR305.108, Recover Offsite Power CR305.105/6, SBO-Recover an EDG CR305.121, Align #13 EDG to Essential MCCs CR314.126, Vent Containment CR259.127, Control Feedwater following a Scram CR314.112, Control Reactor Water Level during an ATWS CR211.106, Inject with SBLC during an ATWS

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TASKS ASSOCIATED WITH SIMULATOR EXERCISE(S):

Shift Manager Tasks:

None SRO Tasks:

SS201.000 Control Rod Drive System Duty Area 6, 7 SS215.000 Nuclear Instrumentation Duty Area 6, 7 SS299.351 Apply administrative requirements for Tech Spec Section 3.3 and Bases to Instrumentation 6, 7 SS299.353 Apply administrative requirements for Tech Spec Section 3.5 and Bases to ECCS and RCIC 6, 7 SS304.193 Implement RPV control 6, 7 SS304.194 Implement primary containment control 6, 7 SS304.198 Implement Emergency RPV Depressurization 6, 7 SS314.106 Supervise use of alternate injection systems for RPV Makeup 6, 7 SS314.107 Supervise RPV Makeup with CRD 6, 7 SS314.119 Supervise Containment Spray 6, 7 SS314.120 Supervise defeat drywell cooler trips 6, 7 SS315.101 Supervise response to a reactor scram 6, 7 SS315.117 Supervise response to a leak inside primary containment 6, 7 SS315.123 Supervise response to increasing pressure caused by main steam pressure regulator failure 6, 7 SS315.159 Supervise rapid power reduction 6, 7 SS315.160 Supervise the response to inadvertent ECCS initiation.

6, 7 SS315.164 Supervise immediate reactor shutdown 6, 7

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RO Tasks:

CR200.146 Perform the procedure for a Reactor Scram 1-5 CR200.162 Perform the procedure for a leak inside primary containment 1-5 CR200.167 Perform the procedure for main steam pressure regulator failure causing increasing pressure 1-5 CR200.203 Perform the procedure for rapid power reduction.

1-5 CR200.204 Perform the procedure for inadvertent ECCS initiation.

1-5 CR200.208 Perform the procedure for immediate reactor shutdown.

1-5 CR201.116 Respond to Inadvertent Control Rod Withdrawal/Rod Drift Out 1-5 CR208.102 Transfer to the standby RBCCW Pump 1-5 CR215.134 Resetting APRM/RBM Trip and alarm indications 1-5 CR215.136 Resetting 2-of-4 Voter Trip Indications 1-5 CR304.102 Perform actions associated with RPV control 1-5 CR304.103 Perform actions associated with Primary containment control 1-5 CR314.101 Perform actions associated with Emergency Depressurization 1-5 CR314.110 Use alternate injection systems for RPV Makeup 1-5 CR314.111 Perform actions associated with RPV Makeup with CRD 1-5 CR314.123 Perform actions associated with Containment Spray 1-5 CR314.124 Defeat Drywell Cooler Trips 1-5 STA Tasks:

None

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QUANTITATIVE ATTRIBUTES (Use this form for Evaluations only.)

Malfunctions:

Before EOP Entry:

1. APRM #3 fails upscale

2. Inadvertent RCIC start.

3. EPR Failure

4. Rod Drift Out

5. Elevated Turbine Vibes After EOP Entry:

1. Both Feed Pumps trip.

2. RCIC cannot be restarted Abnormal Events:

1. Inadvertent RCIC start.

2. EPR Failure

3. Rod Drift Out

4. Rapid Power Reduction for elevated Turbine vibes Major Transients:

1. A small LOCA inside Drywell combined with the loss of most high pressure injection.

Critical Tasks:

1. CT-16: Inhibit ADS to avoid auto initiation that would result in a violation of cooldown rate or a loss of adequate core cooling.

2. CT-22: When RPV water level cannot be maintained >-149, Emergency Depressurize the reactor.

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SCENARIO OVERVIEW:

INITIAL CONDITIONS:

1. IC-281, 100% Power, Normal Operation (Developed from IC 15)

2. The initial plant conditions are:

Normal full power operation

3. The following equipment is OOS:

HPCI due to finding water in a recent oil sample

#12 CRD Pump for repair of damaged electrical leads to the pump motor.

4. The following evolutions are planned for the shift:

Shift RBCCW Pumps due to vibration analysis indicating a slight degradation SEQUENCE OF EVENTS:

Event 1: BOP shifts RBCCW pumps.

The BOP will transfer to the standby RBCCW Pump.

Event 2: APRM #3 fails upscale

APRM Channel #3 will fail upscale causing receipt of a 1/2 vote on all RPS 2 out of 4 Vote Logic channels. The crew will declare APRM Channel #3 inoperable and evaluate associated Tech Specs.

The CRS will determine LCO 3.3.1.1, 3.3.2.1 & TLCO 3.3.2.1 are MET due to three out of four APRMs remain operable. Crew will bypass APRM Channel #3 to clear the alarms and reset the 1/2 vote.

Event 3: Inadvertent RCIC start.

An inadvertent initiation of RCIC will occur. The crew should work together to diagnose this event by watching reactor water level and RCIC controls and indications. The crew should enter the C.4 to secure RCIC and determine Tech Spec requirements. The RCIC Trip pushbutton will fail to work requiring the BOP to secure RCIC using MO-2075 or MO-2080.

When RCIC is needed later in the scenario, it cannot be restarted.

The CRS will determine LCO 3.5.3 is applicable. Condition A is not met because HPCI is inoperable. Conditions B.1 and B.2 then apply. (Be in Mode 3 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and reduce steam dome pressure to psig in 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months ).

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Event 4: Electric Pressure Regulator (EPR) Fails.

The EPR fails. That automatically places the Mechanical Pressure Regulator (MPR) in control.

However, the MPR is set a little too high and must be readjusted to restore reactor pressure and power to normal.

Event 5: Control Rod begins to Drift Out,

Control Rod 42-27 begins to drift out from position 12. The ATC/SRO respond per C.4-B.01.03.C.

Outward rod movement can be stopped by driving the rod in and holding the rod movement switch in that position until the Reactor Bldg Operator disarms the rod.

The CRS must declare the rod inoperable.

Event 6: Rapid Power Reduction for elevated Turbine vibes

Vibrations begin to rise on Main Turbine Bearing #8, followed by Bearings 7 and 9. The crew performs Rapid Power Reduction but the vibration levels continue to rise toward 15 Mils. The crew then manually scrams the reactor and trips the Turbine.

The Crew performs the procedure for Reactor Scram and enters EOP 1100 when RPV water level drops below 9 inches.

Event 7: Small LOCA inside Drywell

During the scram recovery, both Feedwater pumps trip and cannot be restarted. Alternate Level Control Actions are performed due to the loss of high pressure injection systems.

A small leak inside the Drywell also reduces RPV inventory. EOP 1200 actions can be successfully performed to mitigate Primary Containment problems.

Emergency Depressurization must be performed to allow Core Spray and RHR pumps to restore RPV water level.

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NOTE: Table may be modified as needed to include all scenario time-line items SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

1.

INITIAL CONDITIONS (IC):

a. IC: 281

b. Mode: 1

c. Power: 100%

d. Generator: 604 Mwe

e. Xcel system condition is GREEN

f. Plant CDF is YELLOW

g. River temp is 56°F and no towers are in service

h. Outside temp is 60°F

i.

HPCI is out of service due to finding water in a recent oil sample

j.

12 CRD Pump is out of service for repair of damaged electrical leads to the pump motor

k. Possible vibration issue with #11 RBCCW Pump.

2.

SIMULATOR SET UP

a. Set the plant initial conditions per the Initial conditions under the Scenario Overview, Initial Conditions, and Manual Settings.

b. Enter the malfunctions, remotes, overrides and event triggers per the Simulator Input Summary.

c. Control Room and Shift Supervisor turnover checklists should be provided with the scenario IC.

d. Core Damage Frequency (CDF) should be updated on the status board.

e. Tech Spec Required Actions should be updated on the status board.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

3.

COMPLETE TURNOVER:

a.

Review applicable current Unit Status

12 CRD Pump for repair of damaged electrical leads to the pump motor.

Shift RBCCW Pumps due to vibration analysis indicating a slight degradation

b.

Review relevant At-Power Risk status

c.

Review current LCOs not met and Action Requirements TS 3.5.1 Condition J, HPCI inoperable due to finding water in a recent oil sample Condition J.1, immediately verify RCIC is operable is met.

Condition J.2, restore HPCI, in day 2 of 14

d.

Verify crew performs walk down of control boards and reviews turnover checklists.

e.

Plant Staffing The following support is available:

Normal Weekday Night Shift Operations:

Normal crew compliment only based on actual crew staffing.

Maintenance: Available as needed or requested.

Engineering: Available as needed or requested.

Management: Available as needed or requested.

f.

Planned Shift Activities

1) Shift to the Standby RBCCW

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

4.

SHIFT BRIEF

a.

Role Play as necessary. Turbine Building status:

CRS Leads the Shift Brief 1). 5 Condensate demins in service.

ATC/BOP Participate in Shift Brief 2). C highest @ 6.0 psid.

3). All systems in Turbine building are normal.

b.

Role Play as necessary. Rx Building status:

4). Maintenance is standing by for RBCCW Pump shift 5). HPCI and 12 CRD Pump are tagged out for maintenance.

6). All other systems in the Rx bldg are normal.

CRS Crew assumes the duty.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Event 1

5.

BOP shifts RBCCW pumps

a.

Role play and complete necessary actions as an in-plant operator:

BOP Transfers to the standby RBCCW Pump per B.02.05-05. E.1

1) Standing by to shift RBCCW Pumps Station an operator at RBCCW Pumps

2) The #12 pump suction and discharge valves are open prior to starting Establish communications

3) The pump and motor operate normally after starting Insure #12 RBCCW Pump suction and discharge valves are open Start #12 RBCCW Pump Confirm proper operation with in-plant operator

4) When directed to close RBCC 4-1 insert TRIGGER 2. Verify the valve closes over the 30 second ramp and report that #11 RBCCW Pump discharge valve has been closed Direct in-plant operator to slowly close the #11 RBCCW Pump discharge valve

1. When the #11 RBCCW Pump discharge valve is closed, immediately trip the pump

5) When directed to reopen RBCC 4-1 insert TRIGGER 4. Verify the valve opens over the 30 second ramp and report that #11 RBCCW Pump discharge valve has been reopened.

2. Direct the in-plant operator to re-open the #11 RBCCW Pump discharge valve Place the #11 RBCCW Pump switch in Auto-standby

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Event 2

6.

APRM #3 fails upscale

a.

When directed by the Lead Examiner, insert MANUAL TRIGGER 1 Key Parameter Response: APRM Channel #3 High or INOP Red indicating light lit; APRM Channel #3 recorder upscale high

1) Verify Malfunction NI13C goes active.

Key Expected Alarms: C05-A-22 (APRM UPSC/INOP Trip), C05-A-3 (ROD WITHDRAW BLOCK), C05-A14 (APRM ALARM)

Auto Actions: 1/2 Vote trip for APRM 3 on all 2 out of 4 Vote Logic Channels ATC Responds to Annunciators C05-A-3, 14 & 22 and notifies CRS.

Determines the trip signal by pressing the APRM or APRM ODA TRIP STATUS softkey Determines that APRM Channel 3 is upscale and Inoperable Verifies Automatic actions initiated.

b.

When operator goes to Panel C-37 to observe status of 2 of 4 Voter Modules #1, 2 & 4, inform him these voters indicate the same as Voter Module #3 for APRM Channel #3. Voter Modules 1, 2 & 4 are not modeled.

Verifies each 2 of 4 Voter Module APRM UPSC/INOP INPUT SATUS LEDs is ON for APRM #3

Rod Block initiated

INPUT STATUS LEDs activated on the 2 of 4 Voter for APRM UPSC/INOP, OPRM DIDA/INOP, and OPRM CDA/INOP Determines the INOP signal by pressing the APRM or APRM ODA INOP STATUS softkey; Critical Self Test Fault ATC Bypasses APRM Ch #3 as directed by the CRS.

CREW Notifies Plant Engineering.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES CRS Acknowledges alarm receipt. Conducts validation and verification of APRM status and declares APRM Channel #3 inoperable. Consults Tech Spec LCO 3.3.1.1, Table 3.3.1.1-1 and LCO 3.3.2.1, Table 3.3.2.1-1 and determines LCO 3.3.1.1 & 3.3.2.1 continue to be MET due to 3 APRM channels remain operable. Also refers to TRM and determines TLCO 3.3.2.1 is MET.

c.

Role Play plant support personnel as necessary to acknowledge report.

CRS Directs OATC to bypass APRM Channel #3.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Event 3

7.

Inadvertent RCIC start.

a.

When directed by the Lead Examiner, insert MANUAL TRIGGER 3 Key Parameter Response: Pump speed rising.

1) Verify Malfunction RC02 goes active to cause an auto initiation of RCIC Key Expected Alarms: 4-A-14 (RCIC Low Flow)

2) Note that Override 02-S17-04 is inserted at setup to cause a failure of the turbine trip pushbutton.

Auto Actions: RCIC starts and injects, Feed flow may reduce to compensate Crew Recognizes the RCIC start and informs CRS Crew Makes a plant announcement about RCIC in operation and about evacuation of the RCIC Room CRS Directs BOP to use C.4-G and secure RCIC BOP CRS Performs the required actions per C.4-G (Inadvertent ECCS Initiation Signal).

BOP Determines was caused by a spurious signal.

BOP Depresses the RCIC Turbine Trip pushbutton.

b.

With a failure of the RCIC Trip Pushbutton, two additional methods may be used to shutdown RCIC.

BOP Determines that HO-7, Turbine Stop Valve, remains open.

BOP Notifies CRS CRS Directs the BOP to secure RCIC by either of the following methods:

c.

CRS may reference C.4-B.04.01.E (PCIS Group

5) for alternate methods to shutdown RCIC BOP (Option 1) Closing MO-2080:

Places the handswitch for MO-2080 to close.

Observes HO-7 closing

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Verifies that RCIC speed lowers when the valve has closed and reports to the CRS that RCIC has been shutdown.

BOP (Option 2) For closing the Steam line isolation valves:

8.

MO-2076 and MO-2078 will reopen if closed due to receiving an open signal from the initiation signal.

Closes MO-2075 Verifies one of the steam line isolations remain closed Verifies RCIC speed lowers when the steam line isolates Notifies CRS that RCIC has been shutdown Crew Notifies Management, RP and Single Point of Contact.

CRS References TS 3.5.3 to assess RCIC operability

a.

Role Play plant support personnel as necessary to acknowledge report.

CRS Determines RCIC is INOP (but available in an emergency)

Condition A is not met because HPCI is inoperable.

Conditions B.1 and B.2 then apply. (Be in Mode 3 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and reduce steam dome pressure to 150 psig in 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months )

References TS 3.5.1 to assess the combination of HPCI and RCIC both inoperable Determines Condition N applies because the completion time of Condition J not met (Be in Mode 3 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and reduce steam dome pressure to 150 psig in 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months )

Event 4

9.

EPR Failure

a.

When directed by the lead evaluator, INSERT MANUAL TRIGGER 5 Key Parameter Response: RPV Pressure rises which also raises Core Thermal Power

1) Verify Override 04-A2S70-04 goes active to stop the EPR Key Expected Alarms: C07-B-15 EPR TROUBLE

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

2) Note: the MPR setpoint is raised slightly at setup Auto Actions: The MPR begins to control pressure BOP Responds to C07-B-15, EPR TROUBLE and notifies the CRS Verifies that the MPR assumes stable steam pressure control Depress the ELECTRIC PRESSURE REG STOP Pushbutton Recognizes that the EPR TROUBLE annunciator does not reset CRS BOP Performs C.4-B.05.09-B Main Steam Pressure Regulator Failure Causing Increased Pressure BOP/ATC Monitor Reactor Pressure Identifies that Reactor pressure increased slightly when the EPR failed Adjusts the MPR to maintain Reactor Dome Pressure per C.1 (Startup Procedures)

b.

Role Play plant support personnel as necessary to acknowledge report.

BOP CRS Initiate an investigation to determine the cause of the EPR failure Event 5

10. Rod Drift Out

1) When the OATC is not observing C-05 and when directed by the lead evaluator, INSERT MANUAL TRIGGER 7 Key Parameter Response: Rod 42-27 indication on the full core display starts changing from 12 to 48 and its ROD DRIFT indicating light will be on.

a) Verify Override 03-S72-24 goes active to give rod 42-27 an out signal.

Key Expected Alarms: C05-A27 ROD DRIFT Auto Actions: Reactor power increases ATC Responds to C05-A27 ROD DRIFT and notifies the CRS If any control rod is moving and movement was not intended, enter C.4-B.01.03.C

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Identify that only one rod is drifting (manual scram is not necessary)

Momentarily place ROD SELECT POWER SWITCH 3A-S1 to OFF and then back to ON to deselect the drifting rod Identifies that rod continues to withdraw Reselects the drifting rod and uses the normal or emergency insert and maintain the control rod at position 00 Verifies proper CRD operating parameters

2) Role Play Nuclear Engineering Supervisor as necessary BOP CRS Verify that core thermal power and thermal limits have not been exceeded

3) Role Play Reactor Bldg Operator as necessary and, when directed to disarm Rod 42-27 activate MANUAL TRIGGER 9 Notify Nuclear Engineering Supervisor Refer to B.01.03-05.H, Inadvertent Control Rod Withdrawal/Rod Drift Out a) Verify Malfunction CH01_65 reactivates and deletes in 1 second o

Directs the Reactor Bldg Operator to disarm or isolate Rod 42-27 b) Verify Remote Function CH15_65 goes to 0 to effect electrically disarming.

CRS Supervises actions for a Rod drift c)

Wait 2 minutes and report Rod 42-27 has been disarmed. NOTE: Optional 3rd TS call for the CRS only required.

Enters TS 3.1.3 Condition C for an inoperable control rod. Fully insert CR in 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months and disarm CRD in 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

Event 6

11. Rapid Power Reduction for elevated Turbine vibes Key Parameter Response: Rising vibrations for Bearings 7, 8, & 9 on VR-1716 at C-07, Computer Alarm at 7 mils

a.

When directed by the Lead Examiner, insert MANUAL TRIGGER 11.

Key Expected Alarms: C07B-33 TURBINE VIBRATION HIGH

1) Verify Malfunctions TU03G, TU03H and TU03I begin to ramp in.

Auto Actions: None BOP Responds to Annunciator C07B-33 and informs CRS Note: The first annunciator will activate in approximately 2 minutes.

BOP Monitor Turbine vibration as indicated on VR-1716 (Panel C-07).

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

b.

Role Play Equipment Operator or in-plant personnel as necessary:

CREW Verify that annunciator was not caused by maintenance or other activities on the Turbine floor that could cause a false vibration indication.

1) Confirm that there are no activities on the Turbine floor that could cause false readings.

CRS IF sustained Turbine Generator vibration levels are 10 Mils or

higher, THEN refer to C.3 (SHUTDOWN PROCEDURES),

AND remove the Turbine-Generator from service.

2) Also report that vibrations can be felt in the Turbine floor.

IF Rapid Power Reduction is deemed necessary THEN perform C.4-F (RAPID POWER REDUCTION),

as required to reduce vibration levels CRS Supervises Rapid Power Reduction ATC Performs Rapid Power Reduction per C.4.F ATC Reduces recirculation flow ATC Does NOT go below 35Mlb/hr

c.

When the Turbine trips, verify Event Trigger 28 goes True Crew IF sustained Turbine vibration levels approach 15 Mils, THEN perform the following:

1) Verify the severity of Malfunctions TU03G, TU03H and TU03I begin to ramp down and the malfunctions delete in 2 minutes ATC o

Reduce recirculation flow to minimum.

ATC o

Initiate a manual Reactor scram BOP o

Manually trip the Turbine Generator.

Event 7

12. ATC Actions for Reactor Scram ATC Actions per C.4-A (Reactor Scram):

a.

Verify Event Trigger 26 goes True when the Mode Switch is taken to SHUTDOWN Place Mode Switch in SHUTDOWN.

1) Verify that Malfunction RC03 (RCIC Trip) goes active Verify all Control Rods are inserted to or beyond position 04.

2) Verify that Malfunctions FW16A & FW16B (Feed Pump Trips) go active Provides scram script to CRS when RPV level drops to less than 9 EOP Entry Condition

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

3) Verify that Malfunction RR01B (Small Line Break) goes active after a 2 minute delay and begins to increase to 15% severity on a 2 minute ramp.

Controls Reactor water level between +9 and +48 inches.

When reactor water level starts to increase:

o Place CV-6-13 Manual Loading Station Low Flow Valve in AUTO set between 15 and 20 inches o

Close both Main FW Reg Valves o

Close MO-1133 and MO-1134 (HP Feedwater Line Block valves o

Verify CV-6-13 is closed when RPV level reaches

+15 to +20 inches Monitor Reactor Power o

Insert SRM and IRM detectors.

o Switch recorders from APRM to IRM.

o Range down on IRMs as necessary.

Verify SDV Vent and Drain Valves closed.

Event 7

13. BOP Actions for Reactor Scram BOP Starts performance of Part B of C.4.A Announce over the plant paging system that a Reactor Scram has occurred.

Open Main Generator output bkrs 8N4 & 8N5.

Trip the Main Turbine.

Verify the Generator Field Breaker Open.

Start the Turbine Aux Oil Pump.

Verify Turbine Exhaust Hood Sprays in service.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Verify Main Steam Pressure Control or Low-Low Set is controlling Reactor Pressure.

CRS Supervise response to reactor scram Event 7

14. EOP 1100 Actions CRS Directs performance of C.5-1100 (RPV Control)

a.

Role Play in-plant operators as necessary. There is no apparent cause for the loss of the Feed Pumps.

ATC Recognizes the loss of both Feed Pumps Attempts to restart the Feed Pumps Notifies the CRS CT-16 Inhibit ADS to avoid auto initiation that would result in a violation of cooldown rate or a loss of adequate core cooling.

CRS Direct Alternate Level control Actions ATC Inhibit ADS

b.

When directed to close CRD-168, insert MANUAL TRIGGER 13.

Performs RPV makeup with CRD: Directs in-plant operator to close CRD-168 (Pump Bypass Isol)

1) Verify Remote Function CH34 goes to 1 (Closed)

Starts a SBLC pump for injection. (C.5-3203)

2) Wait 2 minutes and report that CRD-168 is closed.

o Verifies injection

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES o

Adequately monitors and reports RPV level and Pressure, both values and trends.

EVALUATOR NOTE: The crew may deem RCIC unavailable due to the earlier inadvertent start. To manually initiate the steam lines must be reopened. In either case RCIC will NOT start and inject.

Crew o

Recognizes that RCIC is available.

ATC/BOP Attempts to manually start RCIC Informs the CRS that RCIC will not start Event 7

15. LOCA inside Drywell BOP Reports Drywell pressure rising Reports EOP entry conditions.

o DW pressure, DW Temp and Torus temp Note: Containment Spray/Cooling actions may not be taken if the crew prioritizes RPV water level.

CRS Directs performance of C.5-1200 (PC Control)

Start Torus sprays Start all available Torus cooling Spray the Drywell BOP Performs C.5 1200 actions Places Torus Sprays in service per C.5-3502:

o Verifies RHR Pumps running o Takes Cont Spray/Cooling LPCI Initiation Bypass (A/B) to BYPASS

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES o Opens MO-2006, 2010, & 2008 (A Loop) or Opens MO-2007, 2011, & 2009 (B Loop) o Verifies LPCI Inject Outboard Valves are closed; MO-2012 and MO-2013.

BOP Initiates Containment Cooling o RHRSW Outlet valve controller set 20%

o Place HX Bypass in CLOSE o ECCS Load Shed to MANUAL OVERRIDE Event 7 (cont)

16. LOCA Primary Containment Control (Drywell):

o Start RHRSW Pump(s) o Adjust flow to 3500 gpm per pump o Start room cooler BOP Reports Drywell pressure rising Reports EOP entry conditions.

o DW pressure, DW Temp and Torus temp CRS Directs performance of C.5-1200 (PC Control)

Start all available Drywell cooling Spray the Drywell (If Drywell Pressure exceeds 12 psig)

BOP Performs C.5 1200 actions Start all available drywell cooling (C.5-3503) o Place all D/W fan control switches to OFF

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES o

Open Knife switch KS3100 o

Verify fan inlet dampers are in AUTO o

Place all D/W fan control switches to ON o

OPEN associated fan disch dampers BOP Initiates Drywell Spray (C.5-3502) o Open Drywell Spray Outboard MO-2020 (2021) o Open Drywell Spray Inboard MO-2022 (2023) o Close Torus Cooling MO-2008 (2009)

Event 7

17. Alternate RPV Level Control /Blowdown:

CRS Verifies two or more Injection Subsystems lined up with pumps running.

CT-22 When RPV water level cannot be maintained

>-149, Emergency Depressurize the reactor.

When RPV level is < -126 inches and prior to -149 inches, directs performance of C.5-2002 (Emergency RPV Depressurization)

Verifies Torus level > -5.9 ft.

Directs opening of all 3 ADS SRVs.

Directs RPV Level restoration BOP Verifies that both Core Spray Subsystems and LPCI Pumps are available for injection

a.

Verify Event Trigger 24 goes True when A SRV Handswitch is taken to Open BOP/ATC Opens 3 ADS SRVs

1) Verify that Malfunction RR03B (Large Line Break) goes active at 5% severity.

Monitor and report RPV level values and trends

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES BOP Controls RPV injection from RHR.

o Throttles MO-2012.

BOP Controls RPV injection from Core Spray.

o Throttles MO-1753 and MO-1754 ATC Controls RPV injection from the Condensate system.

18. SCENARIO TERMINATION

a.

The scenario may be terminated when:

1) Emergency Depressurization has been performed

2) RPV water level is recovered above TAF.

b.

The scenario may be also terminated at the discretion of lead instructor/evaluator Crew:

Remain in simulator for potential questions from evaluator.

c.

End the scenario by placing the simulator in FREEZE.

Crew:

No discussion of scenario or erasing of procedure marking is allowed.

Monticello NRC EXAM Scenario 2 Appendix D Scenario Outline Form S-D-1 Facility: Monticello Scenario No.: NRC Scenario 2 Op-Test No.: MNGP 2010301 Examiners: ____________________________ Operators:

Initial Conditions: 100% Power Turnover: #12 Service Water Pump Out of Service Event No.

Malf. No.

Event Type*

Event Description 1

None N

BOP Shutdown of the Hydrogen Seal Oil Vacuum Pump 2

NI15A I

ATC/SRO One channel of the RBM fails downscale. (TS) 3 SW01A I

BOP/SRO Trip of the running RBCCW Pump, Manual Start of Standby Pump.(ABN) The momentary loss results in a loss of RWCU. (ABN) 4 None TS SRO ECCS Room Fan found inoperable. (TS) 5 MC04B MC03 C

BOP/SRO Loss of Main Condenser Vacuum due to SJAE controller problems. (ABN) 6 None R

ATC/SRO Rapid Power Reduction is performed due to loss of vacuum. (ABN) 7 MC03 CH16 CH19 M

Crew An air leak into the condenser results in a severe loss of vacuum. When the Turbine trips, a Hydraulic ATWS is identified. EOP 1100 and 2007 are performed. Because the loss of vacuum results in the main condenser as a heat sink, Power Level Control must be performed and SRVs must be used to stabilize RPV Pressure. The scenario may be stopped when Control Rods have been inserted an/or RPV level has been restored.

8 SL01A/B C

ATC When SBLC injection is initiated, the first SBLC Pump selected will not start. The ATC must identify this failure and start the alternate SBLC Pump.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor ES-301-4 Quantitative attributes:

Total Malfunctions (5-8): 5 Malfunction(s) after EOP (1-2): 2 Abnormal Events (2-4): 4 Major Transient(s) /E-Plan entry (1-2): E7 EOPs (1-2): 1100, 2007, 1200 EOP Contingencies (0-2): PLC Critical Tasks (2-3): 3 ES-301-5 Quantitative attributes:

BOP Normal: E1 ATC Reactivity (1 per set): E6 BOP I/C (4 / set): E3 & 5 ATC I/C (4 / set): E2 & 8 SRO-I I/C (4 / set inc 2 as ATC): E2 & E5 SRO Tech Spec (2 per set): E2 &4 ALL Major Transients (2 per set): E7

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SIMULATOR EXERCISE GUIDE (SEG)

SITE:

MONTICELLO SEG #

ILT-SS-12E SEG TITLE:

2010 ILT NRC 2 REV. #

0 PROGRAM:

INITIAL LICENSE TRAINING MT-ILT COURSE:

NRC EXAM M-8119 TOTAL TIME:

1.5 HOURS Additional site-specific signatures may be added as desired.

Developed by:

Instructor Date Reviewed by:

Instructor (Simulator Scenario Development Checklist.)

Date Validated by:

Validation Lead Instructor (Simulator Scenario Validation Checklist.)

Date Approved by:

Training Supervision Date

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Guide Requirements Goal of Training:

ILT NRC Exam Learning Objectives:

8.

Demonstrate the ability to predict and/or monitor changes in parameters associated with operating system controls for the appropriate tasks.

9.

Demonstrate the ability to correctly use procedures to correct, control, or mitigate the consequences of normal and abnormal operations for the appropriate tasks.

10.

Demonstrate the ability to monitor automatic operations of the systems to ensure proper operation for the appropriate tasks.

11.

Demonstrate the ability to manually operate and/or monitor systems in the control room in accordance with approved procedures for the appropriate tasks.

12.

Demonstrate the ability to complete administrative requirements, as necessary, in order to operate the plant for the appropriate tasks.

13.

Demonstrate knowledge of and ability to implement shift supervision duties as they relate to crew operations for the appropriate tasks.

14.

Given a degrading or improving plant condition or event, demonstrate the ability to: (CRS)

a. Evaluate trends that may result in equipment damage or reduction in plant safety.

b. Ensure proper diagnosis of plant problems by monitoring and interpreting data (information from panel indications).

c. Evaluate and diagnose challenges to Critical Plant Parameters.

d. Evaluate events and accidents.

Prerequisites:

2.

Completion of MT-ILT Training Program Training Resources:

8.

Full Scope Simulator

9.

3139 (Control Room Shift Turnover Checklist)

10. 3140 (Shift Supervisors Office Shift Turnover Checklist)

11. Simulator Driver

12. Simulator Phone Talker

13. Operations Representative

14. Evaluators

References:

26. B.03.01-05 (CORE SPRAY)

27. B.03.04-05 (RHR SYSTEM)

28. B.06.03.3-05 (GENERATOR HYDROGEN SEAL OIL)

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29. C.4-A (REACTOR SCRAM)

30. C.4-B.02.05.A (LOSS OF RBCCW FLOW)

31. C.4-B.06.03.A (DECREASING CONDENSER VACUUM)

32. C.4-F (RAPID POWER REDUCTION)

33. C.4-K (IMMEDIATE REACTOR SHUTDOWN)

34. C.5-1100 (RPV CONTROL)

35. C.5-1200 (PRIMARY CONTAINMENT CONTROL)

36. C.5-2007 (FAILURE TO SCRAM)

37. C.5-3101 (ALTERNATE ROD INSERTION)

38. C.5-3205 (TERMINATE AND PREVENT)

39. C.5-3301 (DEFEATING RPV LOW-LOW LEVEL ISOLATION FOR MSIV CLOSURE)

40. C.5-3502 (CONTAINMENT SPRAY)

41. C.5-3503 (DEFEAT DRYWELL COOLER TRIPS)

42. C04-B-26 (CLEAN UP DEMINTEMP HI)

43. C.6-005-B-20 (CONDENSER LOW VACUUM SCRAM TRIP)

44. C.6 6-B-32 (RBCCW LOW DISCH PRESS)

45. Tech Specs Section 3.3

46. Tech Specs Section 3.5

47. Technical Requirements Manual 3.3 Commitments:

2.

None Evaluation Method:

ILT NRC Exam Operating Experience:

Not Applicable / ILT Exam

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Related PRA Information:

Initiating Event with Core Damage Frequency Contribution:

Internal Flood (36.8%)

Station Blackout (27.4%)

Loss of High Pressure Injection (13.4%)

ATWS (11.4%)

LOCA (7.7%)

Loss of Low Pressure Injection (2.0%)

LOCA Outside Containment (0.6%)

Loss of Containment Heat Removal (0.4%)

Important Components:

EDGs HPCI RCIC Scram Feed/Cond SRV (When stuck open)

SRVs Instrument AC Fire System (for RPV Injection) 4160 VAC Important Operator Actions with Task Number:

CR314.101, Emergency Depressurize CR305.108, Recover Offsite Power CR305.105/6, SBO-Recover an EDG CR305.121, Align #13 EDG to Essential MCCs CR314.126, Vent Containment CR259.127, Control Feedwater following a Scram CR314.112, Control Reactor Water Level during an ATWS CR211.106, Inject with SBLC during an ATWS

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TASKS ASSOCIATED WITH SIMULATOR EXERCISE(S):

Shift Manager Tasks:

None SRO Tasks:

SS299.351 Apply administrative requirements for Tech Spec Section 3.3 and Bases to Instrumentation 6, 7 SS299.354 Apply administrative requirements for Tech Spec Section 3.5 and Bases to ECCS and RCIC 6, 7 SS299.362 Apply administrative requirements of the Technical Requirements Manual 6, 7 SS304.193 Implement RPV control 6, 7 SS304.194 Implement primary containment control 6, 7 SS304.201 Implement the response for failure to scram 6, 7 SS314.101 Supervise alternate rod insertion 6, 7 SS314.108 Supervise terminate and prevent 6, 7 SS314.111 Supervise defeat of RPV Low-Low Level isolation for MSIV closure 6, 7 SS314.119 Supervise containment Spray 6, 7 SS314.120 Supervise defeat of Drywell Cooler trips 6, 7 SS315.101 Supervise response to a reactor scram 6, 7 SS315.107 Supervise response to loss of RBCCW 6, 7 SS315.114 Supervise response to PCIS Group 3 6, 7 SS315.127 Supervise response to decreasing condenser vacuum 6, 7 SS315.159 Supervise rapid power reduction 6, 7 SS315.164 Supervise immediate reactor shutdown 6, 7

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RO Tasks:

CR200.143 Perform a manual reactor scram in response to plant conditions 1-5 CR200.146 Perform the procedure for Rx Scram 1-5 CR200.153 Perform the procedure for Loss of RBCCW Flow 1-5 CR200.159 Perform the procedure for PCIS Group 3 1-5 CR200.172 Perform the procedure for decreasing condenser vacuum 1-5 CR200.203 Perform the procedure for rapid power reduction.

1-5 CR200.208 Perform the procedure for immediate reactor shutdown 1-5 CR211.101 Operate the SBLC System 1-5 CR203.112 Place Torus Cooling in service during abnormal and emergency conditions 1-5 CR215.000 Nuclear Instrumentation (Duty Area) 1-5 CR215.135 Resetting APRM/RBM Trip and alarm indications 1-5 CR245.131 Seal Oil Vacuum Pump P-69 Removal/Restoration with the Plant On-line 1-5 CR304.102 Perform actions associated with RPV control 1-5 CR304.103 Perform actions associated with Primary containment control 1-5 CR314.104 Perform actions associated with Failure to Scram 1-5 CR314.105 Perform actions associated with Alternate Rod Insertion 1-5 CR314.112 Perform actions to terminate and prevent 1-5 CR314.115 Defeat RPV Low-Low Level isolation for MSIV closure 1-5 CR314.123 Perform actions associated with Containment Spray 1-5 CR314.124 Defeat Drywell Cooler Trips 1-5 STA Tasks:

None

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QUANTITATIVE ATTRIBUTES (Use this form for Evaluations only.)

Malfunctions:

Before EOP Entry:

6. Condenser Vacuum Switch failure / No 1/2 Scram

7. Trip of running RBCCW Pump

8. SJAE Controller After EOP Entry:

3. First SBLC Pump fails to start

4. Turbine BPVs fail closed on complete loss of condenser vacuum Abnormal Events:

5. Loss of RBCCW

6. Primary Containment Isolation Group 3

7. Loss of Main Condenser Vacuum

8. Rapid Power Reduction Major Transients:

2. Hydraulic ATWS Critical Tasks:

3. CT-43: When control rods fail to insert and heat is being added to the primary containment then inject SBLC.

4. CT-46: During failure to scram conditions with reactor power above 3%, terminate and prevent injection from all sources except SBLC, RCIC, and CRD until level lowers to at least -33.

5. CT-48: During failure to scram conditions with a critical reactor, insert control rods using one or more methods contained within C.5-3101 to achieve reactor shutdown under all conditions.

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SCENARIO OVERVIEW:

INITIAL CONDITIONS:

5. IC 282, 100% %Power, Normal Ops

6. The following equipment is OOS

#12 Service Water Pump

7. The following evolutions are planned for the shift:

Secure the Hydrogen Seal Oil Vacuum Pump for inspection.

SEQUENCE OF EVENTS:

Event 1: Secure the Hydrogen Seal Oil Vacuum Pump

The BOP performs Seal Oil Vacuum Pump P-69 Removal/Restoration with the Plant On-line.

Event 2: Condenser Vacuum switch Failure Condenser Low-Vacuum switch fails. The annunciator alarms but the Channel A RPS logic fails to trip, which requires the ATC operator to insert a manual scram on A RPS.

Event 3: Running RBCCW Pump Trip

The #11 RBCCW Pump trips and the #12 RBCCW Pump fails to auto start. When the BOP verifies automatic actions and takes the #12 RBCCW Pump to START, it will start.

Event 4: ECCS Room Fan Found Inoperable The Reactor Building Operator reports that he found a large fan belt hanging from V-AC-4 in the Division 2 RHR /Core Spray Corner Room. Per the B Manuals for RHR and Core Spray, the loss of Room Cooling makes the affected Core Spray and LPCI mode inoperable. The CRS applies TS 3.5.

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Event 5: Loss of Main Condenser Vacuum.

Alarms will indicate a loss of steam to the B SJAE. The BOP takes actions per the Abnormal procedure for loss of Main Condenser Vacuum. In-plant operator actions can eventually bypass the failed control valve to restore steam to the SJAE. The BOP can then reset the SJAE Isolation. (Note:

When this event was used for the ILT Exam in 2008 it exposed a procedural and training deficiency that has since been corrected.)

Event 6: Rapid Power Reduction is performed due to loss of vacuum.

The CRS and OATC coordinate to lower Recirc Pump speeds as dictated by the Abnormal procedure for loss of Main Condenser Vacuum.

Event 7: Turbine Trip, Hydraulic ATWS

An air leak causes a severe loss of Main Condenser Vacuum. The crew may manually scram the reactor prior to the Turbine trip. Eventually, the loss of vacuum will close the Turbine Bypass Valves, which will complicate RPV pressure Control during the ATWS.

After the reactor scram, a Hydraulic ATWS is identified. EOP 1100 and 2007 are performed.

Because the loss of vacuum results in the main condenser as a heat sink, Power Level Control must be performed. The scenario may be stopped when Control Rods have been inserted and/or RPV level has been restored.

Event 8: SBLC Initiation problems

When SBLC injection is initiated, the first SBLC Pump selected will not start. The ATC must identify this failure and start the alternate SBLC Pump.

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NOTE: Table may be modified as needed to include all scenario time-line items SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

19. INITIAL CONDITIONS (IC):

l.

IC: 282

m. Mode: 1

n. Power: 100%

o. Generator: 604 Mwe

p. Xcel system condition is GREEN

q. Plant CDF is GREEN

r. River temp is 56°F and no towers are in service

s. Outside temp is 60°F

t. Hydrogen Seal Oil Vacuum Pump is running hot.

u. #12 Service Water Pump is out of service

20. SIMULATOR SET UP

f. Set the plant initial conditions per the Initial conditions under the Scenario Overview, Initial Conditions, and Manual Settings.

g. Enter the malfunctions, remotes, overrides and event triggers per the Simulator Input Summary.

h. Control Room and Shift Supervisor turnover checklists should be provided with the scenario IC.

i.

Core Damage Frequency (CDF) should be updated on the status board.

j.

Tech Spec Required Actions should be updated on the status board.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

21. COMPLETE TURNOVER:

a.

Review applicable current Unit Status (Green)

b.

Review relevant At-Power Risk status (Green)

c.

Review current LCOs not met and Action Requirements (None)

d.

Verify crew performs walk down of control boards and reviews turnover checklists.

e.

Plant Staffing The following support is available:

Normal Weekday Night Shift Operations:

Normal crew compliment only based on actual crew staffing.

Maintenance: Available as needed or requested.

Engineering: Available as needed or requested.

Management: Available as needed or requested.

f.

Shift Activities

1) Secure the Hydrogen Seal Oil Vacuum Pump. It is running hot and Maintenance will inspect after it is shut down. Operating experience shows that Hydrogen purity will not change for several hours.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

22. SHIFT BRIEF

a.

Role Play as necessary. Turbine Building status:

CRS Leads the Shift Brief 7). 5 Condensate demins in service.

ATC/BOP Participate in Shift Brief 8). C highest @ 6.3 psid.

9). #12 Service Water Pump was tagged out 10). All systems in Turbine building are normal.

b.

Role Play as necessary. Rx Building status:

11). No Maintenance in progress or planned 12). All systems in the Rx bldg are normal.

c.

Role Play as necessary. Third Operator:

13). Nothing to add.

CRS Crew assumes the duty.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Event 1

23. Hydrogen Seal Oil Vacuum Pump Shutdown Note: Gas purity will not change during the scenario, making feed and bleed actions and power reduction unnecessary.

ATC SRO Perform B.06.02.03-05 Seal Oil Vacuum Pump P-69 Removal/Restoration with the Plant On-line

a.

Role Play Turbine Bldg Operator as necessary; Report that H-37 is cracked open (Step 1).

Direct the TB Operator to slowly crack open H-37, Manual Vacuum Regulator At C-08, Take the SOVP handswitch to OFF

b.

Role Play Turbine Bldg Operator as necessary; Report that H-37 is closed (Step 3).

Direct the TB Operator to slowly close H-37 Monitor Generator Gas Purity on C-08 INSTRUCTOR NOTE: 8-A-22 (NO. 1 GEN H2 SYSTEM TROUBLE) will be expected for the starting of this pump.

Start the Emergency Seal Oil Pump. P-68 Stop the Main Seal Oil Pump

c.

Role Play Turbine Bldg Operator as necessary for Gas Purity and Vacuum Tank monitoring (Step 8).

Direct the TB Operator to monitor Vacuum Tank Level and Pressure

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Event 2

24. Condenser Vacuum Switch Failure

a.

When directed by the lead evaluator, Insert MANUAL TRIGGER 1.

Key Parameter Response: None

b.

Verify the following go active:

Key Expected Alarms: 5-B-20 (Condenser Low Vacuum Scram Trip) a) MALFUNCTION (Annunciator) C-05-B20 Auto Actions: None, RPS A fails to trip.

ATC Responds to annunciator and reports to the CRS

c.

Evaluator prompt when the operator goes around back to C-15; 5A-K2A in C-15 is deenergized 5A-K2B, C, & D are all energized CREW Recognize 1/2 scram should have occurred and did NOT CRS Refers to TRM 3.3.1.1 and enters Required Action A.2, Place associated trip system in Trip, in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

Provides crew brief Directs 1/2 scram be inserted on A RPS ATC Inserts 1/2 scram by depressing A manual scram pushbutton Event 3

25. Trip of the Running RBCCW Pump

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Note the Auto-Start of the Standby RBCCW pump is defeated during setup. The following commands on Manual Trigger 3 provide indication of a supply breaker trip.

Key Parameter Response: RBCCW Header Pressure is approaching 0 psig; Both red and green indicating lights for 11 RBCCW Pump are OFF

a.

When directed by the Lead Examiner, insert MANUAL TRIGGER 3 Key Expected Alarms: C06-B-31 RBCCW LOW DISCH PRESS, C04-B-26 (CLEAN UP DEMINTEMP HI

1) Verify Malfunction SW01A goes active Auto Actions: (Within a few seconds) RWCU isolation on high NRHX outlet temp

2) Verify Override 04-A1DS122-02 goes active Responds to annunciator and informs CRS Check System Pressure at C06 If RBCCW Pressure is < 30 psig, refer to C.4-B.02.05.A, Loss of RBCCW Flow.

Verify (Auto Actions) that the Standby RBCCW pump has started Takes the #12 RBCCW Pump hand switch to START and verifies that RBCCW pressure is restored.

b.

Role Play the Reactor Bldg Operator as necessary: The 11 RBCCW Pump is very hot to the touch and the supply breaker is open Direct the Reactor Bldg Operator to investigate the cause of the loss of RBCCW CRS Supervises restoration of RBCCW Contacts the System Engineer BOP ATC Responds to RWCU isolation by verifying automatic actions:

MO-2399 RWCU Return Isolation Valve closed RWCU Pump has tripped

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Role Play the Reactor Bldg Operator as necessary Direct the Reactor Bldg Operator to close the Demin Flow control valves Event 4

26. ECCS Room Fan found Inoperable Role Play the Reactor Building Operator and report the following. You found the fan belt hanging from V-AC-4 in the Division 2 RHR /Core Spray Corner Room.

If asked, it is a single belt fan.

CRS References B.03.04-05 (RHR) or B.03.01-05 (Core Spray) Section A.3 or System/Component Operability Requirements for Room Heat Up analysis. Both state that the RHR and Core Spray pumps are inoperable if the associated Room Cooling Unit (V-AC-4 or 5) is inoperable References TS 3.5.1 ECCS Operating Role Play plant support personnel as necessary when contacted about the inoperable ECCS Room fan.

Determines Condition E applies with one Core Spray and one LPCI Subsystem inoperable. Core Spray or the LPCI subsystem must be restored to operable within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . Or Condition G applies which requires a shutdown to mode 3 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and to Mode 4 in 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

Event 5

27. SJAE Problems, Loss of Main Condenser Vacuum

a.

When directed by the Lead Examiner, insert MANUAL TRIGGER 5 Key Parameter Response: Degrading Condenser Vacuum

1) Verify the following Malfunctions go active:

Key Expected Alarms: 7-A-20 (Offgas Annunciator) and 252-A-46 (11 SJAE Steam Supply Press Low Trip) a) MC04B, Loss of Steam to SJAE Auto Actions: AO-1085A closes.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES b) MC03, Condenser air in-leakage at 0.5%

severity BOP Perform actions from C.4-B.06.03.A (Decreasing Condenser Vacuum)

Trip HWC by placing HS-4148 (HWC System Control) on OFF

2) When requested to open the Mechanical Vacuum Pump suction valves, Role Play the in-plant operator as necessary.

Notify the Chemist that HWC is out of service

3) Wait until Rapid Power Reduction has been initiated and at least 3 minutes. Open the MVP Suction using Remote Function:

Notify Radiation Protection Personnel of changing radiological conditions in MVP Room a) Activate MANUAL TRIGGER 7 (Modifies REMOTE FUNCTION MC06 to 100%)

Direct an in-plant operator to open MVP Suction Valves, OG-22-1and OG-22-2 Identify that PI-1246 reading is NOT normal Take manual control of PC-1246 and attempt to restore SJAE Sup pressure to 120-130 psig

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

4) When Rapid Power Reduction with Recirc has been completed, restore SJAE pressure using Remote Function:

Dispatch an in-plant operator to locally bypass the failed PCV using MS-24-1 a) Activate MANUAL TRIGGER 9 (Modifies REMOTE FUNCTION MC01, #11 SJAE PCV Bypass MS-24-1 to 18%)

BOP o

When SJAE Supply pressure is restored to 120-130 psig, reset the SJAE supply trip using PB-1085 (SJAE Isolation Trip Reset)

Confirm that Offgas and Condenser Vacuum parameters return to normal Event 6

28. Rapid Power Reduction CRS Supervises Rapid Power Reduction for Immediate Action of C.4-B.06.03.A, Decreasing Condenser Vacuum.

ATC Performs Rapid Power Reduction per C.4.F ATC Reduces recirculation flow ATC Does NOT go below 35Mlb/hr

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Event 7

29. Severe Loss of Vacuum / Turbine Trip/ Hydraulic ATWS

a.

When directed by the Lead Examiner, insert MANUAL TRIGGER 11 Key Parameter Response: Decreasing Main Condenser Vacuum, Decreasing Generator Megawatts

1) Verify the following malfunction Key Expected Alarms: 5-B-46 Condenser Low Vacuum a) MC03 Condenser Air In-leakage begins to ramp to 30% severity over 5 minutes Auto Actions: Turbine Trip b)

CH19 Multiple control rods stuck.

BOP Responds to annunciator 5-B-46 Condenser Low Vacuum and notifies the CRS CRS Directs reduction of reactor power per C.4-F until vacuum stabilizes ATC Performs Rapid Power Reduction per C.4.F ATC Reduces recirculation flow but does NOT go below 35Mlb/hr during Rapid Power Reduction actions BOP Monitor LP turbine exhaust pressures per SPDS screen 656 or on PR-1264 at C-07 Crew If either LP turbine exhaust pressures enters the SCRAM REQUIRED region of Figure 1 or approaches the low vacuum scram setpoint then manually scram the reactor per C.4-K, Immediate Reactor Shutdown CRS Directs a manual reactor scram per C.4-K ATC If time permits then reduce Recirculation flow to minimum ATC Depresses the REACTOR SCRAM A and B pushbuttons Event 7

30. Hydraulic ATWS

a.

When the Mode Switch is take to SHUTDOWN, verify EVENT TRIGGER 25 goes active OATC Provides a Scram Report

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

1) Verify Malfunction MC03 modifies to 100%

severity Mode Switch is in Shutdown

2) Note the complete loss of Condenser Vacuum takes away the availability of the Turbine Bypass Valves, adding heat to the Torus and Making SBLC injection necessary.

All rods are NOT in Reactor power is >3%

EOP Entry CRS Enters EOP 1100 RPV Control, transitions to EOP 2007, Failure to Scram, and directs:

o Inhibit ADS o Defeat MSIV Low-Low Level Isolation (C.5-3301) o Prevent Core Spray injection (C.5-3205) o Perform C.5-3101.

BOP Inhibits ADS BOP Defeat MSIV low-low level isolation BOP Terminates and Prevents Core Spray Event 7

31. Hydraulic ATWS Power Leg Actions Note: C.5-3101 Part C and/or Part D may be performed. If only one part is performed, the actions form the other part are not applicable ATC Performs C.5-3101.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES May perform C.5 3101 Part C to insert rods CT-48 During failure to scram conditions with a critical reactor, insert control rods using one or more methods contained within C.5-3101 to achieve reactor shutdown under all conditions.

Bypass the RWM Start #12 CRD Pump Fully open the CRD Flow Control Valve o

Place FC 3-301 in MAN o

Adjust output of FC 3-301 to 100%

Open MO-3-20 Drive Pressure to CRD

a. Role play as necessary: When requested to close CRD-168, activate MANUAL TRIGGER 13 Directs Reactor Building Operator to CLOSE CRD-168, CRD-79-1 & CRD-79-2

1) Verify Remote Function CH 34 is modified to 1, wait 2 minutes and report CRD-168, 79-1 and 79-2 closed.

Drive rods using RMCS o

Establish Drive Pressure as high as possible below 400 psig by one or more of the following:

o Throttle closed the CRD Flow Control Valve o

Throttle closed Open MO-3-20 Drive Pressure to CRD

b. Role play as necessary: When requested to close CRD-14, activate MANUAL TRIGGER 15 o

Directs the Reactor Bldg Operator to CLOSE CRD-14 to raise drive pressure

1) Verify Remote Function CH 22 is modified to 0. Report CRD-14 Closed.

Select and insert rods in non-peripheral core regions with few or no rods inserted Event 7 (Continued)

Hydraulic ATWS Power Leg Actions (Continued)

c. When directed by the lead instructor DELETE Malfunction CH19 to allow rods to be driven in.

ATC Attempt to achieve a Black and White pattern May perform C.5 3101 Part D to insert rods

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

d. Role play as necessary: When requested to deenergize the ARI valves insert Trigger 17, this modifies RR18 is to Open.

Wait 2 minutes and report the ATWS 125 VDC Breakers Open.

Evacuate personnel from the RB 896 Floor and the Equipment Drain tank Room Directs the in-Plant operator to deenergize the ATWS 125 VDC Valves

e. If the OATC hangs the jumpers to bypass all automatic scram signals insert Trigger 19 this modifies PP06 to INSTLD.

NOTE: Contacts not modeled in the Simulator, modify PP06 when OATC hangs jumpers in C15 and C17.

Installs jumpers to bypass all automatic scram signals in C-15

& C-17 Resets the scram

f.

Role play as necessary: if requested to open CRD-14, modify Remote Function CH22 is to Open, wait 2 minutes and report CRD-14 Open.

Directs the Reactor Bldg Operator to open CRD-14 Verifies SDV Vent and drain valves Open When Annunciator C05-B-21 clears, closes the SDV vent and drain valves

g. If Manual Reactor Scram is performed for Part D, Delete Malfunction CH16 only when the OATC re-scrams to allow the control rods to insert.

Inserts a Manual Reactor Scram Verifies all control rods fully inserted and informs the CRS Event 7

32. Hydraulic ATWS Level Leg Actions CRS Verify needed auto actions Identifies that power >3% & level above -33 and directs Terminate and Prevent actions CT-46 During failure to scram conditions with reactor power above 3%, terminate and prevent injection from all sources except SBLC, RCIC, and CRD until level lowers to at least -33.

ATC Prevents injection from Condensate & Feedwater by placing the FRV Controllers in Manual and closing the Reg Valves

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES BOP ATC Prevents injection form HPCI by placing the Aux Oil Pump in PTL Prevents Core Spray injection as follows:

Place the A & B CS INJECTION BYPASS Switches to BYPASS Close MO-1751 (1752) Injection Outboard Place A and B CS Pump switches to PTL Close MO-1753 (1754) Injection Inboard Prevents LPCI injection as follows Open Knife switches (C-03)

Verify LPCI Inject Outboard Valves are closed, MO-2012 &

13 CRS Lets level drop until Power is <3% or All SRVs stay closed and DW < 2 psig or Level reaches -126 inches For level control, the CRS should direct condensate and feedwater injection be re-established and used to maintain level in the desired band.

Records final level and sets level band When Power Level Control has been performed and when directed by the Lead Examiner, Delete Malfunction CH16 to allow the control rods to insert.

Uses Condensate & Feedwater as necessary to maintain established level band.

OATC Recognizes and reports all rods are fully inserted.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Event 7

33. Hydraulic ATWS Pressure Leg Actions CRS/ BOP Recognize the loss of Turbine Bypass Valves due to the loss of vacuum CRS/ BOP Stabilize RPV pressure below 1056 psig using SRVs Event 7

34. Hydraulic ATWS (PRIMARY CONTAINMENT CONTROL)

BOP Monitor Primary Containment Parameters

a. EOP C.5-1200 steps become applicable only if Torus Water Temperature exceeds 90°F If Torus Water Temperature exceeds 90°F, notify the CRS of the EOP C.5-1200 entry condition.

CRS Enters EOP C.5-1200 Primary (Containment Control)

Directs start of all available Torus Cooling BOP Starts all available Torus Cooling per the Hard Card.

Verify CV-1728 (1729), RHR HX SW Outlet, controller set at 20%.

START No 11(12) and or No 13(14) RHRSW pumps as needed.

Adjust flow for ~3500 gpm per pump using CV-1728 (CV-1729).

Verify No 11(12) and /or No 13 (14) RHR pumps running.

Partially OPEN MO-2008 (2009), Torus Cooling Inj/Test Inboard, by holding handswitch in OPEN position for 8 seconds.

Give MO-2006 (2007) an OPEN signal by momentarily placing RHR Div 1 Disch to Torus Otbd handswitch 10A-S14A (B) to OPEN.

THROTTLE OPEN MO-2008 (2009) to provide ~4000 gpm per pump.

CLOSE MO-2002 (2003), HX Bypass.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES NOTE: V-AC-4 is not available due to the earlier equipment issue.

Verify V-AC-5 (4), A (B) RHR RM COOLER UNIT, in operation.

Event 8

35. SBLC Initiation Problems

a. Event Triggers 28 or 29 will auto activate to clear the trip on the second SBLC pump that is started.

Key Parameter Response: Selected pump Green light stays on and Red light stays off, SBLC discharge pressure remains at 0 psig

b. If #11 SBLC is attempted to be started first, verify Event Trigger 29 goes True and SL01B deletes after 1 second so

12 SBLC pump will start.

Key Expected Alarms: None

c. If #12 SBLC is attempted to be started first, verify Event Trigger 28 goes True and SL01A deletes after 1 second so

11 SBLC pump will start.

Auto Actions: RWCU isolates and pumps trip CRS Directs SBLC initiation before Torus temp reaches 110ºF OATC Initiates SBLC when directed Places 11A-S1 SBLC System Selector Switch to SYS 1 or SYS 2 Verify RWCU isolation and Pumps tripped Identifies that the selected SBLC pump did not start. (no running light, discharge pressure or tank level decreasing)

Starts the other SBLC pump CT-43 When control rods fail to insert and heat is being added to the primary containment then inject SBLC Verifies SBLC Pump running light is ON and, discharge pressure is slightly higher than RPV pressure

36. SCENARIO TERMINATION

a.

The scenario may be terminated when the conditions are stabilized as follows:

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

1) All rods inserted and the crew has entered C.5-1100 and/or is restoring RPV water level to the normal band.

b.

The scenario may be also terminated at the discretion of lead instructor/evaluator Crew:

Remain in simulator for potential questions from evaluator.

c.

End the scenario by placing the simulator in FREEZE.

Crew:

No discussion of scenario or erasing of procedure marking is allowed.

Monticello NRC EXAM Scenario 3 Appendix D Scenario Outline Form ES-D-1 Facility: Monticello Scenario No.: NRC Scenario 3 Op-Test No.: MNGP 2010301 Examiners: ____________________________ Operators:

Initial Conditions: 46% Power, normal shutdown in progress 12 Core Spray Pump Out of Service Turnover: Secure #11 RFP then continue inserting control rods for shutdown Event No.

Malf. No.

Event Type*

Event Description 1

None N

BOP Secure #11 RFP.

2 None R

ATC/SRO Insert control rods for shutdown.

3 CH07B I

ATC/SRO While inserting control rods, the in-service CRD Flow Control Valve will fail, requiring a shift to the alternate FCV.

4 SL02A (TS only)

SRO (Optional) Loss of continuity to one SBLC Squib valve.

(TS) 5 01-DS085-02 01-DS084-02 (TS only)

SRO (Optional) A Core Spray becomes inoperable when the Inboard Inject valve is found deenergized (TS) 6 ED06B C

BOP/SRO (Optional) Loss of Turbine Bldg Load Center 102 (ABN) 7 CH08A CH08B I

ATC/SRO 11 CRD Pump trip / restore with 12 CRD Pump / 12 CRD Pump trip (ABN). Immediate Reactor Shutdown (ABN) 8 CH22A CH22B 03-S45-04 M

Crew Loss of both CRD pumps. Manual scram for 2nd accumulator (CT) and performs EOP 1100. In-Plant personnel begin reporting indications of leak in the Scram Discharge Volume. The Scram discharge Volume high Level Trip cannot be bypassed to reset the scram. When parameters in 2 areas exceed Max Safe values, Emergency Depressurization is performed. (CT) 9 AP08D I

BOP D ADS SRV Stuck closed (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor ES-301-4 Quantitative attributes:

Total Malfunctions (5-8): 7 Malfunction(s) after EOP (1-2): 2 Abnormal Events (2-4): E6 & E7 Major Transient(s) /E-Plan entry (1-2): E8 EOPs (1-2): 1300, 1100 EOP Contingencies (0-2): ED Critical Tasks (2-3): 2 ES-301-5 Quantitative attributes:

BOP Normal: E1 ATC Reactivity (1 per set): E2 BOP I/C (4 / set): E6 & 9 ATC I/C (4 / set): E3 & 7 SRO-I I/C (4 / set inc 2 as ATC): E3, 6 & 7 SRO Tech Spec (2 per set): E4 & 5 ALL Major Transients (2 per set): 1

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SIMULATOR EXERCISE GUIDE (SEG)

SITE:

MONTICELLO SEG #

ILT-SS-13E SEG TITLE:

2010 ILT NRC 3 REV. #

0 PROGRAM:

INITIAL LICENSE TRAINING MT-ILT COURSE:

NRC EXAM M-8119 TOTAL TIME:

1.5 HOURS Additional site-specific signatures may be added as desired.

Developed by:

Instructor Date Reviewed by:

Instructor (Simulator Scenario Development Checklist.)

Date Validated by:

Validation Lead Instructor (Simulator Scenario Validation Checklist.)

Date Approved by:

Training Supervision Date

QF-1075-02 Rev. 3 (FP-T-SAT-75)

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Guide Requirements Goal of Training:

ILT NRC Exam Learning Objectives:

15.

Demonstrate the ability to predict and/or monitor changes in parameters associated with operating system controls for the appropriate tasks.

16.

Demonstrate the ability to correctly use procedures to correct, control, or mitigate the consequences of normal and abnormal operations for the appropriate tasks.

17.

Demonstrate the ability to monitor automatic operations of the systems to ensure proper operation for the appropriate tasks.

18.

Demonstrate the ability to manually operate and/or monitor systems in the control room in accordance with approved procedures for the appropriate tasks.

19.

Demonstrate the ability to complete administrative requirements, as necessary, in order to operate the plant for the appropriate tasks.

20.

Demonstrate knowledge of and ability to implement shift supervision duties as they relate to crew operations for the appropriate tasks.

21.

Given a degrading or improving plant condition or event, demonstrate the ability to: (CRS)

a. Evaluate trends that may result in equipment damage or reduction in plant safety.

b. Ensure proper diagnosis of plant problems by monitoring and interpreting data (information from panel indications).

c. Evaluate and diagnose challenges to Critical Plant Parameters.

d. Evaluate events and accidents.

Prerequisites:

3.

Completion of MT-ILT Training Program Training Resources:

15. Full Scope Simulator

16. 3139 (Control Room Shift Turnover Checklist)

17. 3140 (Shift Supervisors Office Shift Turnover Checklist)

18. Simulator Driver

19. Simulator Phone Talker

20. Operations Representative

21. Evaluators

References:

48.

B.01.03-05 (CRD HYDRAULIC SYSTEM)

49.

B.02.04-05 (MAIN STEAM)

50.

B.05.05-05 (RMCS)

51.

B.06.06-05 (CONDENSATE AND REACTOR FEEDWATER)

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52.

C.3 (SHUTDOWN PROCEDURES)

53.

C.4-B.01.03.A (LOSS OF CRD PUMP FLOW)

54.

C.4-B.06.03.A (DECREASING CONDENSER VACUUM)

55.

C.4-B.06.04.A (DECREASED CIRCULATING WATER FLOW)

56.

C.4-B.09.07-B (480 VOLT STATION AUXILIARY)

57.

C.4-A (REACTOR SCRAM)

58.

C.4-K (IMMEDIATE REACTOR SHUTDOWN)

59.

C.5-1100 (RPV CONTROL)

60.

C.5-1300 SECONDARY CONTAINMENT CONTROL)

61.

C.5-2002 (EMERGENCY RPV DEPRESSURIZATION)

62.

C.6-003-B-56 (HIGH AREA TEMP STEAM LEAK)

63.

C.6-004-A-11 (REACTOR BUILDING HI RADIATION)

64.

C.6-005-B-17 (CHARGING WATER LO PRESSURE)

65.

C.6-005-B-25 (33) CRD PUMP 3-16A(B) BREAKER TRIPPED

66.

C.6-005-B-26 (34) CRD PUMP 3-16A(B) OL

67.

C.6-005-B-31 (LOSS OF CONTINUITY TO SQUIB VALVE)

68.

C.6-008-C-30 (NO. 102 TRANS 480V BKR TRIP)

69.

C.6-00 8-C-5 (NO. 1R RES TRANS TROUBLE)

70.

Tech Specs Section 3.1

71.

Tech Specs Section 3.5 Commitments:

3.

None Evaluation Method:

ILT NRC Exam Operating Experience:

Not Applicable / ILT Exam

QF-1075-02 Rev. 3 (FP-T-SAT-75)

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Related PRA Information:

Initiating Event with Core Damage Frequency Contribution:

Internal Flood (36.8%)

Station Blackout (27.4%)

Loss of High Pressure Injection (13.4%)

ATWS (11.4%)

LOCA (7.7%)

Loss of Low Pressure Injection (2.0%)

LOCA Outside Containment (0.6%)

Loss of Containment Heat Removal (0.4%)

Important Components:

EDGs HPCI RCIC Scram Feed/Cond SRV (When stuck open)

SRVs Instrument AC Fire System (for RPV Injection) 4160 VAC Important Operator Actions with Task Number:

CR314.101, Emergency Depressurize CR305.108, Recover Offsite Power CR305.105/6, SBO-Recover an EDG CR305.121, Align #13 EDG to Essential MCCs CR314.126, Vent Containment CR259.127, Control Feedwater following a Scram CR314.112, Control Reactor Water Level during an ATWS CR211.106, Inject with SBLC during an ATWS

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TASKS ASSOCIATED WITH SIMULATOR EXERCISE(S):

Shift Manager Tasks:

None SRO Tasks:

SS200.142 Direct Reactor Shutdown IAW C.3 6, 7 SS211.000 Standby Liquid Control Duty Area 6, 7 SS299.349 Apply administrative requirements for Tech Spec Section 3.1 and Bases to Reactivity Control Systems 6, 7 SS299.353 Apply administrative requirements for Tech Spec Section 3.5 and Bases to ECCS and RCIC 6, 7 SS304.193 Implement RPV control 6, 7 SS314.196 Implement Secondary Containment control 6, 7 SS314.198 Implement Emergency RPV Depressurization 6, 7 SS315.101 Supervise response to a reactor scram 6, 7 SS315.102 Supervise response to loss of CRD Pump flow 6, 7 SS315.127 Supervise the response to decreasing condenser vacuum 6, 7 SS315.129 Supervise the response to decreased Circulating Water flow 6, 7 SS315.142 Supervise the response to loss of power to LC-102 or its MCCs 6, 7 SS315.164 Supervise immediate reactor shutdown 6, 7

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RO Tasks:

CR200.135 Perform a power reduction to 25%

1-5 CR200.146 Perform the procedure for Rx Scram 1-5 CR200.147 Perform the procedure for loss of CRD Pump Flow 1-5 CR200.172 Perform the procedure for decreasing condenser vacuum 1-5 CR200.174 Perform the procedure decreased Circulating Water flow 1-5 CR200.186 Perform the procedure for loss of power to LC-102 or its MCCs 1-5 CR200.208 Perform the procedure for immediate reactor shutdown 1-5 CR201.111 Place the standby CRD Flow Control Valve in service 1-5 CR201.138 Operate RMCS during Control Rod Movement 1-5 CR203.113 Place Torus Cooling in service during abnormal and emergency conditions 1-5 CR211.000 Standby Liquid Control 1-5 CR256.118 Shutdown the Condensate and Reactor Feedwater system 1-5 CR259.127 Control Feedwater following a Scram 1-5 CR304.102 Perform actions associated with RPV control 1-5 CR304.105 Perform actions associated with Secondary Containment Control 1-5 CR314.101 Perform actions associated with Emergency Depressurization 1-5 STA Tasks:

None

QF-1075-02 Rev. 3 (FP-T-SAT-75)

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QUANTITATIVE ATTRIBUTES (Use this form for Evaluations only.)

Malfunctions:

Before EOP Entry:

9. CRD Flow control Valve failure

10. (Optional) Loss of LC-102 (TS)

11. (Optional) Loss of SBLC Squib Valve Continuity (TS)

12. Loss of CRD Pumps

13. (Optional) A Core Spray Inoperability After EOP Entry:

5. Scram reset switch failure

6. 1 ADS SRV fails to open Abnormal Events:

9. Loss of LC-102

10. Loss of CRD

11. Immediate Reactor Shutdown Major Transients:

3. Unisolable Scram Discharge Volume leak Critical Tasks:

6. CT-1: Within 5 minutes of the second accumulator low pressure alarm, scram the reactor when no CRD pump is running and the second accumulator low pressure alarm is received.

7. CT-34: When a primary system is discharging into the secondary containment through an unisolable break, perform an Emergency Depressurization per C.5-2002 when max safe operating values are exceeded in two or more areas.

QF-1075-02 Rev. 3 (FP-T-SAT-75)

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SCENARIO OVERVIEW:

INITIAL CONDITIONS:

8. IC 283, 46 %Power, Shutdown in progress

9. The initial plant conditions are:

Normal Shutdown is in progress

10. The following equipment is OOS

12 Core Spray Pump

11. The following evolutions are planned for the shift:

Continue the shutdown in accordance with C.3

Secure the 11 Feed Pump

Insert control rods per Nuclear Engineer recommendations (provided)

SEQUENCE OF EVENTS:

Event 1: Secure the 11 RFP.

The BOP coordinates with the Out Plant Operator to secure the 11 Reactor Feed Pump.

Event 2: Insert control rods for shutdown.

Control Rods are inserted using the recommendations provided by the Nuclear Engineer.

Event 3: The in-service CRD Flow Control Valve will fail

While inserting control rods, the in-service CRD Flow Control Valve will fail, requiring a shift to the alternate FCV.

Event 4: (OPTIONAL) Loss of continuity to one SBLC Squib valve.

Loss of electrical continuity on A SBLC Squib valve will occur which will require the CRS to declare A SBLC system INOPERABLE. Crew will evaluate Tech Specs and determine LCO 3.1.7 is NOT MET with Condition B applicable.

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Event 5: (OPTIONAL) A Core Spray Inoperability

The Reactor Bldg Operator finds the breaker tripped at MCC133 for MO-1753, A Core Spray Injection Inboard. With both Core Spray systems now inoperable, Tech Spec 3.5.1 Condition F is entered.

Event 6: (OPTIONAL) Loss of Turbine Bldg Load Center 102

Loss of LC-102 results in the loss of: #12 Circ Water Pump, #12 Steam Packing Exhauster, #12 Stator Cooling Pump, cooling fans for the 1R Transformer, and #12 EDG control panel C-94. The BOP secures the electric plant lineup and takes appropriate actions for the affected systems. The plant will continue to operate without immediate challenge.

Event 7: Loss of CRD Pump 11, Start CRD Pump 12, Loss of CRD Pump 12

11 CRD Pump trips and cannot be restarted. The 12 CRD Pump can be started and CRD parameters stabilized. However, one minute later, the 12 CRD pump will also trip.

With no CRD flow, the abnormal procedure is performed, which requires an immediate reactor shutdown when the second CRD accumulator low pressure alarms.

Event 8: Unisolable Scram Discharge Volume Rupture

Following the manual scram, the Scram Discharge Volume vents and drains fail to close. The leak cannot be isolated and the Scram cannot be reset.

Turbine Bypass valves can be used to lower RPV pressure in anticipation of Emergency Depressurization.

When parameters in 2 areas exceed Max Safe values, Emergency Depressurization is performed.

Event 9: Only 2 of 3 ADS valves will open

When Emergency Depressurization is performed the D ADS SRV fails to open. The BOP must open an additional SRV to establish a total of 3 SRVs open.

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NOTE: Table may be modified as needed to include all scenario time-line items SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

37. INITIAL CONDITIONS (IC):

v. IC: 283

w. Mode: 1, Shutting down

x. Power: 46 %

y. Generator: 249 Mwe

z. Recirc Flow is 35.7 mlb/Hr aa. Xcel system condition is GREEN bb. Plant CDF is YELLOW cc. River temp is 56°F and NO towers are in service dd. Outside temp is 60°F ee. 12 Core Spray Pump is out of service ff. 12 Steam Packing Exhauster is in service gg. The next evolution is shutdown of the 11 RFP.

hh. Ensure C.3 (Shutdown) is marked to Step IV.C.2

38. SIMULATOR SET UP

k. Set the plant initial conditions per the Initial conditions under the Scenario Overview, Initial Conditions, and Manual Settings.

l.

Enter the malfunctions, remotes, overrides and event triggers per the Simulator Input Summary.

m. Control Room and Shift Supervisor turnover checklists should be provided with the scenario IC.

n. Core Damage Frequency (CDF) should be updated on the status board.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

o. Tech Spec Required Actions should be updated on the status board.

39. COMPLETE TURNOVER:

a.

Review applicable current Unit Status

b.

Review relevant At-Power Risk status

c.

Review current LCOs not met and Action Requirements B Core Spray Pump, Condition B, Day 1 of 7, breaker removed for maintenance.

d.

Verify crew performs walk down of control boards and reviews turnover checklists.

e.

Plant Staffing The following support is available:

Normal Weekday Night Shift Operations:

Normal crew compliment based on actual crew staffing for shutdown.

Maintenance: Available as needed or requested.

Engineering: Available as needed or requested.

Management: Available as needed or requested.

f.

Shift Activities

1) Continue the shutdown, holding at Step C.3 IV.C.2

2) Stop the 11 Reactor Feed Pump, leave it in a warmup lineup

3) Continue with control rod insertion per the Nuclear Engineers recommendations

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

40. SHIFT BRIEF

a.

Role Play as necessary. Turbine Building status:

CRS Leads the Shift Brief 14). Hydrogen Water Chemistry System has been secured ATC/BOP Participate in Shift Brief 15). A, B, & C Condensate demins in service.

ATC/BOP Participate in Shift Brief 16). C highest @ 5 psid.

17). Assigned to support the shutdown of 11 RFP after turnover.

18). #12 Steam Packing Exhauster is in service 19). All systems in Turbine building are normal.

b.

Role Play as necessary. Rx Building status:

20). No Maintenance is in progress 21). All other systems in the Rx bldg are normal.

c.

Role Play as necessary. Third Operator:

22). Nothing to add CRS Crew assumes the duty.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Event 1

41. Secure 11 RFP.

a.

Role Play the Plant Equipment Operator at the 11 RFP as necessary to support the shutdown CRS Directs the BOP to secure the 11 RFP IAW C.3.C Step 2 and B.06.05 BOP Starts 11 RFP Aux Oil Pump and verifies that it is running Establishes communications with the Plant Equipment Operator to monitor FIS-3489 Assures that suction flow does not drop below 1200 gpm

b.

Role play Turbine Bldg operator as necessary and close FW-68-1 using MANUAL TRIGGER 1 Slowly closes FW-68-1 RFP Discharge valve, allowing FIC-3489 time to open the Recirc Valve

1) Verify Remote Function FW46 modifies to 0 (Closed) over 30 seconds Verify that CV-3489, 11 RFP P-2A FW Recirc to Condenser, OPENS and controls flow at approximately 3300 gpm Stop 11 RFP Verify that CV-3489, 11 RFP P-2A FW Recirc to Condenser, CLOSES approximately 11 seconds after the pump trip

c.

Role play Turbine Bldg operator as necessary.

If directed, re-open FW-68-1 using MANUAL TRIGGER 3 Re-open FW-68-1 RFP Discharge valve while monitoring Pump Discharge Pressure (PI-1130) and Feed Reg Valve position

1) Verify Remote Function FW46 modifies to 100 (Open) over 30 seconds Directs the Plant equipment Operator to open the Warm-up valves for 11 RFP (FW-69-1 & FW-70-1)

d.

Role play Turbine Bldg operator as necessary if asked for #12 RFP Running Amps. Report #12 RFP running at 685amps Event 2

42. Insert control rods for shutdown.

INSTRUCTOR NOTE: If requested, act as a valid Reactivity Management SRO and provide the necessary peer checks.

CRS Directs OATC to continue lowering reactor power by inserting control rods as recommended by the Nuclear Engineer

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES ATC Lowers power by inserting control rods using the A2SD sequence, Step 10 (Backwards) For each rod:

Selects desired control rod (18-43, 42-35, 10-19)

a.

After the first rod is inserted and as directed by the Lead Examiner, insert MANUAL TRIGGER 5 to begin Event 3 Takes the ROD MOVEMENT CONTROL switch to ROD IN and holds until rod is at position 00

1. Verify the following MALFUNCTION goes active: CH07B, CRD Flow control Valve fails closed Monitors the following:

o APRMs Relationship to Gardel thermal power within 2%

o Core Flow o

Recirculation flow o

Steam flow o

Feedwater flow o

RPV Water level Event 3

43. The in-service CRD Flow Control Valve fails Key Parameter Response: Reduced CRD cooling water flow, inability to drive control rods Key Expected Alarm: 5-B-41, CRD HI TEMPERATURE (Possible)

Auto Actions: CRD Flow Control valve is closed.

ATC Responds to annunciator QF-1075-02 Rev. 3 (FP-T-SAT-75)

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Informs Shift Supervision

a.

If directed to investigate CRD temperatures, wait 2 minutes and report that many CRD temperatures are rising and that CRD 26-15 is in alarm. The highest reading temperature is 255°F.

o Sends Reactor Building Operator to investigate CRD temperature recorder o

Refers to procedure B.01.03-05 CRDH o

Recognizes CRD FCV failure CRS Directs swap to standby CRD FCV

b.

When directed to report to the CRD FCV station to support shift of FCV, WAIT 3 minutes and report you are standing by.

ATC Coordinates with Reactor Building Operator and performs the following:

o Opens standby FCV manual inlet/outlet valves o

Places Flow Controller in MANUAL o

Manually runs controller to 0

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Event 3 Continued ATC Places the CRD Flow Selector to the B position

c.

When directed to OPEN CRD-16-2 and CRD 2, WAIT 2 minutes, then use MANUAL TRIGGER 7 to modify REMOTE FUNCTION CH17 to OPEN and report this action to the Control room.

Slowly OPENS the B FCV manually to approximately 54 to 56 gpm Places the FCV in AUTO

d.

When directed to CLOSE CRD-16-1 and CRD-18-1, WAIT 2 minutes, then use MANUAL TRIGGER 9 to modify REMOTE FUNCTION CH16 to CLOSE and report this action to the Control room Closes previously in-service FCV manual inlet/outlet valves Acknowledge annunciator 5-B-41 clear and informs Shift Supervision.

e.

If directed to report CRD temperatures, report all alarms are clear and all temperatures are lowering to normal.

Places the CRD Flow Selector to the B position

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Event 4

44. (OPTIONAL) Loss of continuity to one SBLC Squib valve.

Note: This event is OPTIONAL and has no bearing on the subsequent events. It may be omitted at the discretion of the Lead Examiner when the CRS/SRO candidate has had the requisite number of Technical Specification determinations.

a.

When directed by the Lead Examiner, insert MANUAL TRIGGER 11 Key Parameter Response: 11 Squib valve Ready light de-energizes

1) Verify Malfunction SL02A goes Active Key Expected Alarms: 5-B-31 (LOSS OF CONTINUITY TO SQUIB VALVE)

Auto Actions: None OATC Announces alarm and consults associated ARP. Reports ready light for 11Squib valve is NOT lit.

EVALUATOR QUE:

Takes the following action per ARP 5-B-31:

b.

Relays are not modeled in the simulator. When the operator checks the readings behind C-05, the associated evaluator must provide the cue that Relay 11-67A is reading 0 ma.

BOP Reads values on meter relays11-67A & 11-67B located on the back of C-05 to verify which circuit has lost continuity.

c.

Role Play Plant support personnel as necessary to investigate and repair the squib valve.

CREW Notifies Shift Supervision & System Engineer.

CRS Acknowledges alarm receipt. Declares A SBLC system inoperable.

Consults Tech Specs and determines LCO 3.1.7 NOT MET and enters Condition B (Restore to operable within 7 days).

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Event 5

45. (OPTIONAL) A Core Spray Inoperability Note: This event is OPTIONAL and has no bearing on the subsequent events. It may be omitted at the discretion of the Lead Examiner when the CRS candidate has had the requisite number of TS Calls.

a.

When directed by the Lead Examiner, insert MANUAL TRIGGER 13 Key Parameter Response: A report from the Reactor Bldg. will be necessary. Both red and green indicating lights for MO-1753 on C-03 will be off.

1) Verify Overrides 01-DS085-02 and 01-DS084-02 go active.

Key Expected Alarms: None

b.

Role Play Reactor Bldg operator. Report that you were investigating an acrid odor and found Breaker 3324 on MCC-133 is in the trip free position Auto Actions: None BOP Identifies that MO-1753 appears deenergized

2) If an attempt to reset the breaker is made, it will not reset CRS Evaluate Tech Spec Section 3.5 Identify that A Core Spray is inoperable.

Enter TS 3.5.1 Condition B & F, 72 Hour Action statement Event 6

46. (OPTIONAL) Loss of Turbine Bldg Load Center 102

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Note: This event is OPTIONAL and has no bearing on the subsequent events. It may be omitted at the discretion of the Lead Examiner when the BOP candidate has had the requisite number of Instrument/Component failures.

Key Parameter Response: Breaker 57-201 OPEN and 0 amps indicated on LC-102.

Key Expected Alarms: 8-C-30 (No. 102 Trans 480v Bkr Trip) and 8-C-5 (No. 1R Res Trans Trouble)

a.

When directed by the Lead Examiner, insert MANUAL TRIGGER 15 Auto Actions:

Loss of #12 Circ Water Pump, #12 Steam Packing Exhauster, #12 Stator Cooling Pump, cooling fans for the 1R Transformer, and #12 EDG control panel C-94

1) Verify Malfunction ED06B goes active BOP Responds to annunciator 8-C-30, NO. 102 TRANS 480V BKR TRIP, and informs the CRS

b.

Role Play the dispatched operator as necessary.

Report that 1/2 of the cooling fans are off BOP May respond to C-08-C-5, NO. 1R RES TRANS TROUBLE) by dispatching an operator to investigate (from a distance) the 1R Trouble alarm Performs actions of C.4-B.09.07.B (Loss of Power To LC-102 or its MCCs).

c.

If dispatched to investigate the trip of breaker 52-201, report no apparent cause of the failure.

May dispatch an operator to investigate why breaker 52-201 tripped BOP Verifies that Main Condenser Vacuum is stable and that no actions are necessary per C.4-B.06.03.A (Decreasing Condenser Vacuum)

Execute C.4-B.06.04.A (Decreased Circulating Water Flow)

Take the control switch for #12 Circ Water Pump to SHUTDOWN and verify system valves automatically reposition.

d.

Role Play Shift Chemist as necessary to acknowledge the directive from the control room BOP Notify the Shift Chemist to reduce the feed rate of both the Sodium Hypochlorite and Sodium Bromide injections systems, and any other chemical injection equipment For loss of power to MCC-121, refer to B.09.02-5, Less than Full Cooling for Generator Transformer.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Verifies Generator Load <531 MVA (13.94 K Amps) for the loss of 6 pumps and 18 fans on MCC121.

e.

Role Play Turbine Bldg Operator as necessary:

The A Isophase Bus fan is running in AUTO Dispatch an operator to verify that the A Isophase Bus cooler is in service.

BOP Take appropriate action for Steam Packing exhauster Starts #11 Packing Exhauster Blower

f.

When the Packing Exhauster is restored, start the next event.

Opens the #11 Packing Exhauster Discharge Valve BOP May take action for Service Water (either action)

Opens #13 SW Breaker and Starts #12 Service Water Pump (in either order)

g.

Role Play Turbine Bldg/Reactor Bldg Operators as necessary when dispatched to monitor Service water loads Dispatch the TBO or RBO to monitor Service Water Loads and adjust as necessary CRS Direct response to loss of LC-102 Prioritize actions of C.4-B.09.07.B (Loss of Power to LC-102 or its MCCs).

NOTE: It is not intended for the CRS to make this TS CALL.

Refers to TS for loss of power to #12 EDG control panel, C-94 and enters 3.8.1 Condition B for one inoperable EDG Event 7

47. Loss of CRD Flow / Manual Scram Actions

a.

When directed by the Lead Examiner, insert MANUAL TRIGGER 17 Key Parameter Response: Indicating lights for CRD Pumps 11 & 12; CRD Drive pressure lost

b.

Verify Malfunction CH08A goes active.

Key Expected Alarms: C05-B-17 (CHARGING WATER LO PRESSURE); C05-B-25 (33) CRD PUMP 3-16A(B) BREAKER TRIPPED; C05-B-26 (34) CRD PUMP 3-16A(B) OL Auto Actions: None

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES ATC Respond to annunciators and notify the CRS Verify a CRD Pump is running / Start 12 CRD Pump Reset annunciators Monitor and control system pressures and flows

c.

Role Play Turbine Bldg/Reactor Bldg Operators as necessary when dispatched to investigate the loss of CRD. Report no apparent cause.

Investigate the reason for the loss of the 11 CRD Pump Note: 12 CRD Pump will trip in one minute after it was started, using Event Trigger 26 to activate Malfunction CH08B Respond to annunciators and notify the CRS Identify that no CRD Pumps are running or can be started Note: The second accumulator will alarm in approximately 3.5 minutes.

ATC CRS When the second accumulator low pressure alarm is received, manually scram the reactor CT-1 Within 5 minutes of the second accumulator low pressure alarm, scram the reactor when no CRD pump is running and the second accumulator low pressure alarm is received.

ATC Depresses MANUAL REACTOR SCRAM pushbuttons.

Event 8

48. Reactor Scram response (ATC):

ATC Actions per C.4-A (Reactor Scram):

Place Mode Switch in SHUTDOWN.

Verify all Control Rods are inserted to or beyond position

04.

Provides scram script to CRS Reports when Reactor level drops to less than 9 EOP entry condition.

Controls Reactor water level between +9 and +48 inches.

When reactor water level starts to increase:

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES o

Place CV-6-13 Manual Loading Station Low Flow Valve in AUTO set between 15 and 20 inches o

Close both Main FW Reg Valves o

Close MO-1133 and MO-1134 (HP Feedwater Line Block valves o

Verify CV-6-13 is closed when RPV level reaches

+15 to +20 inches Monitor Reactor Power o

Insert SRM and IRM detectors.

o Switch recorders from APRM to IRM.

o Range down on IRMs as necessary.

ATC Reports to CRS that SDV Vent and Drain Valves are NOT closed.

Event 8

49. Reactor Scram response (BOP):

BOP Starts performance of Part B of C.4.A Announce over the plant paging system that a Reactor Scram has occurred.

Open Main Generator output breakers 8N4 & 8N5.

Trip the Main Turbine.

Verify the Generator Field Breaker Open.

Start the Turbine Aux Oil Pump.

Verify Turbine Exhaust Hood Sprays in service.

Verify Main Steam Pressure Control or Low-Low Set is controlling Reactor Pressure.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Event 8

50. Unisolable Scram Discharge Volume Rupture NOTE: The malfunctions for SDV vent and drain valve failures, CH22A and CH22B, are inserted during the initial setup.

Key Parameter Response: Scram Discharge Volume Vents and Drains remain open Key Expected Alarms: 3-B-56 (High Area Temp Steam Leak), 4-A-11 (Reactor Building Hi Radiation)

Auto Actions: None NOTE: It takes approximately 4 minutes for area A-11, West CRD HCU, to reach Max Safe Rad levels (1R/hr). It takes an additional 4 minutes for the second area, A-15 Reactor Bldg Drain Tank, to reach Max Safe (1R/hr).

The BOP will respond to annunciators and report to the CRS EOP 1300 Entry Conditions o 3-B-56 (High Area Temp Steam Leak) o 4-A-11 (Reactor Building Hi Radiation)

CREW Perform the actions of EOP-1300 (Secondary Containment Control)

Directs evacuation of area or entire reactor building.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Reports Reactor Building radiation levels and temperatures are rising Keeps the CRS informed of Secondary Containment parameter values and trends ATC Attempts to manually close SDV isolation valves INSTRUCTOR NOTE: If the BOP operator is using C.5-3302 for opening the PRO, and if asked, state that the TSC is NOT yet staffed.

BOP If directed to anticipate Blowdown, takes the Turbine PRO to OPEN Event 8 Continued Unisolable Scram Discharge Volume Rupture CRS Enters EOP-1300 (Secondary Containment Control)

Direct isolation of the SDV CRS Monitors Secondary Containment parameters CRS May anticipate Blowdown per a C.5-1100 Override Statement and direct RPV pressure be lowered using the Turbine Bypass Valves CT-34 When a primary system is discharging into the secondary containment through an unisolable break, perform an Emergency Depressurization per C.5-2002 when max safe operating values are exceeded in two or more areas.

CREW Recognizes when 2 area radiation levels have exceeded Max Safe CRS Enters and directs EOP-2002 (Blowdown)

Verifies Torus level > -5.9 ft.

Directs that 3 ADS SRVs be opened BOP Perform Emergency Depressurization

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Event 9

51. Emergency Depressurization BOP When directed by CRS, take 3 ADS SRVs to OPEN Monitor RPV Pressure and Level When directed by CRS, take 3 ADS SRVs to OPEN Recognize that SRV D did NOT open Informs the CRS of the failure Opens a non-ADS SRV to establish 3 SRVs open.

52. SCENARIO TERMINATION

a.

The scenario may be terminated when the conditions are stabilized as follows:

1) Emergency depressurization has begun

2) RPV level is stable

b.

The scenario may be also terminated at the discretion of lead instructor/evaluator Crew:

Remain in simulator for potential questions from evaluator.

c.

End the scenario by placing the simulator in FREEZE.

Crew:

No discussion of scenario or erasing of procedure marking is allowed.

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Appendix D Scenario Outline Form ES-D-1 Facility: Monticello Scenario No.: NRC Scenario 4 Op-Test No.: MNGP 2010301 Examiners: ____________________________ Operators:

Initial Conditions: 80% Power, after a rod Sequence exchange.

One Drywell Spray valve inoperable.

1AR out of Service HPCI outage complete Turnover: Return HPCI to standby readiness.

Event No.

Malf. No.

Event Type*

Event Description 1

None N

BOP Return HPCI to standby readiness.

2 C-05-B54 (TS-only)

SRO (Optional) Tripped breaker in Y80 to Alternate Shutdown Panel (TS) 3 C-08-B01 C

BOP/SRO An oil leak on T12 requires an emergency transfer to T11. (TS) 4 RR06A C

BOP/SRO A Recirc Pump trips. BOP performs the actions to secure the Recirc Pump and for Single Loop Ops. (ABN) 5 None R

ATC/SRO Insert control rods to exit Region 2.

6 RX03 C

ATC/SRO Core Thermal Hydraulic Instability begins. The ATC inserts a manual reactor Scram. (ABN) (CT) 7 03-A166-02 (Ovrd)

I ATC The Low Flow Feed Reg Valve will not open in AUTO during post scram RPV level control. (ABN) 8 MS04B 01-S072-02 (Ovrd)

M Crew A steam leak begins inside the Drywell. EOP 1100 is entered and performed. RPV water level control is complicated by failure of the Low Flow Reg Valve (See Event 7) EOP 1200 is entered. Because the only available Drywell Spray will not function, Drywell air temperature cannot be controlled and Emergency Depressurization is performed. (CT)

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor ES-301-4 Quantitative attributes:

Total Malfunctions (5-8): 6 Malfunction(s) after EOP (1-2): 2 Abnormal Events (2-4): E4, 6, 7 Major Transient(s) /E-Plan entry (1-2): E8 EOPs (1-2): 1200, 1100 EOP Contingencies (0-2):ED Critical Tasks (2-3): 2 ES-301-5 Quantitative attributes:

BOP Normal: E1 ATC Reactivity (1 per set): E5 BOP I/C (4 / set): E3 & 4 ATC I/C (4 / set): E6 & 7 SRO-I I/C (4 / set inc 2 as ATC): E2, 3, 4, & 6 SRO Tech Spec (2 per set): E2 & 3 ALL Major Transients (2 per set): E8

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SIMULATOR EXERCISE GUIDE (SEG)

SITE:

MONTICELLO SEG #

ILT-SS-14E SEG TITLE:

2010 ILT NRC 4 REV. #

0 PROGRAM:

INITIAL LICENSE TRAINING MT-ILT COURSE:

NRC EXAM M-8119 TOTAL TIME:

1.5 HOURS Additional site-specific signatures may be added as desired.

Developed by:

Instructor Date Reviewed by:

Instructor (Simulator Scenario Development Checklist.)

Date Validated by:

Validation Lead Instructor (Simulator Scenario Validation Checklist.)

Date Approved by:

Training Supervision Date

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Guide Requirements Goal of Training:

ILT NRC Exam Learning Objectives:

22.

Demonstrate the ability to predict and/or monitor changes in parameters associated with operating system controls for the appropriate tasks.

23.

Demonstrate the ability to correctly use procedures to correct, control, or mitigate the consequences of normal and abnormal operations for the appropriate tasks.

24.

Demonstrate the ability to monitor automatic operations of the systems to ensure proper operation for the appropriate tasks.

25.

Demonstrate the ability to manually operate and/or monitor systems in the control room in accordance with approved procedures for the appropriate tasks.

26.

Demonstrate the ability to complete administrative requirements, as necessary, in order to operate the plant for the appropriate tasks.

27.

Demonstrate knowledge of and ability to implement shift supervision duties as they relate to crew operations for the appropriate tasks.

28.

Given a degrading or improving plant condition or event, demonstrate the ability to: (CRS)

a. Evaluate trends that may result in equipment damage or reduction in plant safety.

b. Ensure proper diagnosis of plant problems by monitoring and interpreting data (information from panel indications).

c. Evaluate and diagnose challenges to Critical Plant Parameters.

d. Evaluate events and accidents.

Prerequisites:

4.

Completion of MT-ILT Training Program Training Resources:

22. Full Scope Simulator

23. 3139 (Control Room Shift Turnover Checklist)

24. 3140 (Shift Supervisors Office Shift Turnover Checklist)

25. Simulator Driver

26. Simulator Phone Talker

27. Operations Representative

28. Evaluators

References:

72. B.3.02-05 HPCI

73. B.05.05-05 (RMCS)

74. B.03.04-05 (RHR)

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75. B.08.05-05 (FIRE PROTECTION)

76. B.09.06-05 (4.16 KV STATION AUXILIARY)

77. C.2-05 (POWER OPERATION - SYSTEM OPERATION)

78. C.4-A (REACTOR SCRAM)

79. C.4-B.01.04.A (TRIP OF ONE RECIRC PUMP)

80. C.4-B.04.01.F (LEAK INSIDE PRIMARY CONTAINMENT)

81. C.4-B. 05.01.02A (CONTROL OF NEUTRON FLUX OSCILLATIONS)

82. C.4-B.05.07A (LOSS OF REACTOR WATER LEVEL CONTROL)

83. C.5-1100 (RPV CONTROL)

84. C.5-1200 (PRIMARY CONTAINMENT CONTROL)

85. C.5-2002 (EMERGENCY RPV DEPRESSURIZATION)

86. C.5-3502 (CONTAINMENT SPRAY)

87. C.5-3503 (DEFEAT DRYWELL COOLER TRIPS)

88. C.6-004-B-35 (DRYWELL-TORUS HI PRESS)

89. C.6-005-B-34 (ASDS TRANSFER SW ACTIVATED OR POWER FAILURE)

90.

C.6-004-C-1 (RECIRC A LOCKOUT)

91.

C.6-004-C-6 (RECIRC PUMP MOTOR A LOCKED ROTOR TRIP)

92.

C.6-004-C-31 (RECIRC DRIVE MOTOR A TRIP)

93.

C.6-004-B-25 (RECIRC PUMP MTR A HI VIBRATION)

94. C.6-005-B-24 (REACTOR WATER LEVEL HI/LOW)

95. C.6-008-B-01 (NO 2XR TROUBLE)

96. Tech Specs Section 3.3

97. Tech Specs Section 3.5

98. Tech Specs Section 3.8 Commitments:

4.

None Evaluation Method:

ILT NRC Exam Operating Experience:

Not Applicable / ILT Exam

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Related PRA Information:

Initiating Event with Core Damage Frequency Contribution:

Internal Flood (36.8%)

Station Blackout (27.4%)

Loss of High Pressure Injection (13.4%)

ATWS (11.4%)

LOCA (7.7%)

Loss of Low Pressure Injection (2.0%)

LOCA Outside Containment (0.6%)

Loss of Containment Heat Removal (0.4%)

Important Components:

EDGs HPCI RCIC Scram Feed/Cond SRV (When stuck open)

SRVs Instrument AC Fire System (for RPV Injection) 4160 VAC Important Operator Actions with Task Number:

CR314.101, Emergency Depressurize CR305.108, Recover Offsite Power CR305.105/6, SBO-Recover an EDG CR305.121, Align #13 EDG to Essential MCCs CR314.126, Vent Containment CR259.127, Control Feedwater following a Scram CR314.112, Control Reactor Water Level during an ATWS CR211.106, Inject with SBLC during an ATWS

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TASKS ASSOCIATED WITH SIMULATOR EXERCISE(S):

Shift Manager Tasks:

None SRO Tasks:

SS299.351 Apply administrative requirements for Tech Spec Section 3.3 and bases for Instrumentation.

6, 7 SS299.353 Apply administrative requirements for Tech Spec Section 3.5 and Bases to ECCS and RCIC 6, 7 SS299.356 Apply administrative requirements for Tech Spec Section 3.8 and Bases to Electric Power Systems 6, 7 SS304.193 Implement RPV control 6, 7 SS304.194 Implement primary containment control 6, 7 SS314.119 Supervise Containment Spray 6, 7 SS314.120 Supervise defeat drywell cooler trips 6, 7 SS314.198 Implement Emergency RPV Depressurization 6, 7 SS315.101 Supervise response to a reactor scram 6, 7 SS315.103 Supervise response to trip of one recirc pump 6, 7 SS315.117 Supervise the response to a leak inside primary containment 6, 7 SS315.119 Supervise response to Control of Neutron Flux Oscillations 6, 7

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RO Tasks:

CR200.146 Perform the procedure for Reactor Scram 1-5 CR200.147 Perform the procedure for one recirc pump trip 1-5 CR200.162 Perform the procedure for a leak inside primary containment 1-5 CR200.168 Perform the procedure for Control of Neutron Flux Oscillations 1-5 CR201.138 Operate RMCS during control rod movement 1-5 CR203.113 Place Torus Cooling in service during abnormal and emergency conditions 1-5 CR206.116.

Open HPCI steam line isolation valves MO-2034 &

MO-2035 1-5 CR259.127 Control Feedwater following a Scram 1-5 CR262.133 Transfer of plant busses from 2R to 1R using emergency method 1-5 CR304.102 Perform actions associated with RPV control 1-5 CR304.103 Perform actions associated with Primary containment control 1-5 CR314.101 Perform actions associated with Emergency Depressurization 1-5 CR314.123 Perform actions associated with Containment Spray 1-5 CR314.124 Defeat Drywell Cooler Trips 1-5 STA Tasks:

None

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QUANTITATIVE ATTRIBUTES (Use this form for Evaluations only.)

Malfunctions:

Before EOP Entry:

14. (Optional) Loss of Power to ASDS Panel

15. Oil leak on T12 Transformer

16. Recirc Pump Trip

17. Neutron Flux Oscillations After EOP Entry:

7. Low Flow Feed Reg Valve Failure

8. Drywell Spray failure Abnormal Events:

12. Recirc Pump Trip

13. Loss of Reactor Water Level Control

14. Core Power Oscillation Major Transients:

4. LOCA Critical Tasks:

CT-8: Scram the reactor in response to core oscillations as indicated by:

o LPRM HI or DOWNSCALE alarms in a wide area of the core that repeatedly alarm, then clear.

o LPRM indications on the four rod display indicate an oscillation.

o APRM recorders indicate a peak-to-peak oscillation greater than 10% that is not attributable to pressure or Recirc flow control problems.

CT-30: When drywell temperature can NOT be restored and maintained below 281°F, then perform Emergency Depressurization per C.5-2002.

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SCENARIO OVERVIEW:

INITIAL CONDITIONS:

12. IC 284, 80 %Power, Normal Ops

13. The initial plant conditions are:

Power lowered for a rod sequence exchange, ready to return to full power.

14. The following equipment is OOS

HPCI Steam Lines are closed

Division 2 Containment Spray

1AR Transformer

15. The following evolutions are planned for the shift:

Restore HPCI to standby readiness

Return to full power SEQUENCE OF EVENTS:

Event 1: Return HPCI to standby readiness.

Return HPCI to Standby Readiness after maintenance by opening HPCI steam line isolation valves MO-2034 & MO-2035.

Event 2: (Optional) Loss of power to Alternate Shutdown System Panel (ASDS) (TS)

Annunciator C-05-B54 indicates a loss of power to the ASDS panel. Breaker D-100 Ckt 4 is found tripped. The CRS addresses Tech Spec 3.3.3.2 and the Fire Detection System impairment from B.08.05-05.

Event 3: An oil leak on T12 requires an emergency transfer to T11. (TS)

A significant oil leak on 2R Transformer requires emergency transfer to 1R. The CRS will address Tech Specs for offsite sources, 3.8.1.

Event 4: A Recirc Pump trips.

11 Recirc Pump seizure. C.4-B.01.04A (Trip of One Recirc Pump) is performed. BOP performs the actions to secure the Recirc Pump and for Single Loop Ops.

The CRS may address Tech Specs for T.S. 3.4.1, 2.1.1 and 3.3.1.1 as time allows.

Event 5: Insert control rods to exit Region 2

After identifying operation in Region 2, the crew will insert control rods to exit.

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Event 6: Neutron Flux Oscillations The ATC identifies neutron flux oscillations and inserts a manual reactor Scram. (ABN) (CT)

Event 7: Low Flow Feed Reg Valve Failure

During post-scram RPV Water Level Control, the Low Flow Feed Reg Valve will not open in either Auto or Manual. Per the Abnormal Procedure for loss of RPV Level control, the ATC can control reactor water level with any unlocked reg valve. Either or both main reg valves can be returned to service.

Event 8: LOCA Inside Drywell A steam leak begins inside the Drywell. EOP 1100 is entered and performed without further challenge.

EOP 1200 is entered. Because the only available Drywell Spray will not function, Drywell air temperature cannot be controlled and Emergency Depressurization is performed. (CT)

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NOTE: Table may be modified as needed to include all scenario time-line items SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

53. INITIAL CONDITIONS (IC):

ii. IC: 284 jj. Mode: 1 kk. Power: 80%

ll. Generator: 470 Mwe mm.

Xcel system condition is GREEN nn. Plant CDF is YELLOW oo. River temp is 56°F and NO towers are in service pp. Outside temp is 60°F qq. HPCI is out of service but ready for restoration rr. MO-2023 Div 2 DW Spray is out of service ss. 1AR Transformer is out of service

54. SIMULATOR SET UP

p. Set the plant initial conditions per the Initial conditions under the Scenario Overview, Initial Conditions, and Manual Settings.

q. Enter the malfunctions, remotes, overrides and event triggers per the Simulator Input Summary.

r. Control Room and Shift Supervisor turnover checklists should be provided with the scenario IC.

s. Core Damage Frequency (CDF) should be updated on the status board.

t. Tech Spec Required Actions should be updated on the status board.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

55. COMPLETE TURNOVER:

a.

Review applicable current Unit Status

b.

Review relevant At-Power Risk status

c.

Review current LCOs not met and Action Requirements Tech Spec LCO 3.6.1.8 is not met with condition A and required action A.1 entered yesterday. MO-2023 is due back later in this shift. Day 2 of 7 Tech Spec LCO 3.6.1.3 is not met with condition A and required actions A.1 and A.2 entered yesterday. This is due to work on MO-2023. MO-2021 is closed, deactivated and tagged.

1AR is out of Service. TS 3.8.1 applies but 2 required offsite sources remain available.

HPCI is in Day 2 of 14 per TS 3.5.1 Condition J. It has been repaired but remains out of service until restored and tested.

d.

Verify crew performs walk down of control boards and reviews turnover checklists.

e.

Plant Staffing Weekday Night Shift The following support is available:

Operations:

Normal crew compliment only based on actual crew staffing.

Maintenance: Staffed to support repair of MO-2023 Engineering: Staffed to support repair of MO-2023 Management: ERT Activated for repair of MO-2023

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

f.

Shift Activities

1) Return HPCI to Standby readiness

2) Return to full power after the rod sequence exchange

56. SHIFT BRIEF

a.

Role Play as necessary. Turbine Building status:

CRS Leads the Shift Brief 23). 5 Condensate demins in service.

ATC/BOP Participate in Shift Brief 24). C highest @ 5.0 psid.

25). All systems in Turbine building are normal.

b.

Role Play as necessary. Rx Building status:

26). Maintenance is complete on HPCI, tags were cleared at the end of last shift 27). MO-2023 is tagged out for scheduled maintenance.

28). All other systems in the Rx bldg are normal.

c.

Role Play as necessary. Third operator:

29). Nothing to add.

CRS Crew assumes the duty.

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Event 1

57. Return HPCI to standby readiness.

BOP Reopen HPCI Steam Line Isolation valves per B.03.02-05 G.4 Verify no Group 4 isolation signal present

a.

Role play Radiation Protection personnel as necessary.

Notify Radiation Protection of the changing radiological conditions in the HPCI Room Verify CV-2043, Drain Trap Bypass, in AUTO Verify CV-2046A & B, Steam line Drains to Main Condenser, are OPEN Fully open MO-2035, Outboard Isolation Jog open MO-2034, Inboard Isolation to slowly pressurize the HPCI steamline Verify MO-2034 fully open Monitor annunciator 3-B-10 Verify HPCI panel lineup in standby readiness CRS Refers to TS 3.5.1 for returning HPCI to Operable status Event 2

58. (Optional) Loss of Power to ASDS Panel Key Parameter Response: None

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Note: This event is OPTIONAL and has no bearing on the subsequent events. It may be omitted at the discretion of the Lead Examiner when the CRS/SRO candidate has had the requisite number of Technical Specification determinations.

Key Expected Alarms: C05-B-54, ASDS Transfer Switch Activated or Power failure

a.

When directed by the lead evaluator, INSERT MANUAL TRIGGER 1 Auto Actions: None

1) Verify Malfunction C-05-B54 goes active ATC Respond to annunciator and inform the CRS

b.

Role Play in plant operator. Breaker D-100 Ckt 4 is in the tripped free position.

Dispatch an operator to determine the cause of the annunciator ATC CRS Notify System engineer and plant Electrician CRS Reference Tech Spec 3.3.3.2. Condition A is applicable, which is a 30 Day LCO for ASDS panel inoperability Reference Fire Protection B.08.05-05 Section A.2 Plant Operating Requirements Table A.2-1 and Section H. The fire detection instrumentation must be restored to operability within 7 days in Modes 1, 2, & 3.

Event 3

59. Oil leak on 2R / Emergency transfer to 1R Key Parameter Response: None

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

a.

When directed by the lead evaluator, INSERT MANUAL TRIGGER 3 Key Expected Alarms: 8-B-01 (No. 2R XFMR TROUBLE)

1) Verify the following Malfunction goes active:

C-08-B01, 2TR Trouble Auto Actions: None BOP Dispatch an operator to investigate from a distance.

Note: the following cue must make it clear that it is imperative to do the emergency transfer operation.

Verify that 2R Voltages appear normal

b.

Role Play the dispatched operator: Wait 2 minutes and then report hysterically that a steady stream of oil is leaking out of 2R and a large pool of oil has already formed Relay information about the oil leak to the CRS CRS Directs emergency transfer from 2R to 1R BOP Performs emergency closed bus transfer from 2R to 1R Makes plant page about 4KV breaker operation and to clear personnel from vicinity of 2R and 1R Verify 115KV system voltage is 117.4 KV or confirm that the 10TR/XFMR auto load tap changer is in service.

Bus 13 o

Place 152-302/CS to CLOSE o

Place 152-301/CS to TRIP Bus 14 o

Place 152-402/CS to CLOSE Bus 11 Event 3 Continued BOP o

Place 152-102/CS to CLOSE o

Place 152-101/CS to TRIP

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Bus 12 NOTE: Verify the BOP has opened the knife switch on C-31. If not, then DO NOT open 3N4 with the following actions.

o Place 152-202/CS to CLOSE o

Place 152-201/CS to TRIP

c.

Role Play the equipment operator dispatched to open 3N4 as necessary. Wait 2 minutes and:

Open knife switch 16 on panel C-31

1) Manually activate Event Trigger 5 Open 3N4 34.5KV Circuit Breaker

2) Verify Remote Function ED06, 3N4 Local operation, to OPEN

d.

If asked, Role Play personnel to confirm that the 10TR XFMR Auto load tap changer is in service.

Dispatch an operator to place the 2R Load Tap Changers in Manual and adjust voltages locally

e.

Role Play System Dispatcher as necessary when called to isolate the 2R Transformer BOP Contact the System Dispatcher to isolate the 2R Transformer CRS Evaluate Tech Spec 3.8.1 NOTE: CRS may also refer to TRM and determine TLCO 3.8.1 is applicable.

Determine T.S. 3.8.1 Condition A is applicable Role Play as necessary to inform the crew that another operator will be called in to perform OSP-MSC-0542 Initiate SR 3.8.1.1 (OSP-MSC-0542, Weekly Breaker Alignment, Indicated Power Availability, and Voltage to AC

& DC Power Distribution Checks)

For notifications, Role Play Single Point of Contact and plant support personnel as necessary Make the following notifications for the LCO Entry.

o Single Point of Contact Event 4

60. #11 Recirc Pump Trip

a.

When directed by the lead evaluator, INSERT MANUAL TRIGGER 7 Key Parameter Response: Reduction in reactor power and total core flow.

QF-1075-02 Rev. 3 (FP-T-SAT-75)

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

1) Verify Malfunction RR06A goes active Key Expected Alarms: 04-C-1 (RECIRC A LOCKOUT), 04-C-6 (RECIRC PUMP MOTOR A LOCKED ROTOR TRIP), 04-C-31 (RECIRC DRIVE MOTOR A TRIP) and 04-B-25 (RECIRC PUMP MTR A HI VIBRATION)

Auto Actions: Field breaker trip.

BOP Responds to C-04 annunciators (above) and informs the crew that #11 Recirc Pump has tripped CRS Directs the response to trip of one Recirc Pump Note: Wait 2 minutes and report as the Outplant operator that there is no visual evidence for the pump failure.

BOP Verifies A Recirc Drive Motor and Field Breakers have tripped Dispatches an out-plant operator to determine the cause of the lockout. (May correlate to Annunciator C04-C-6, Locked Rotor)

Performs actions of C4-B.01.04.A ATC Monitors and controls RPV water level +30 to +40 inches ATC Performs actions of C.4-B.05.01.02.A Control of Neutron Flux Oscillations:

Checks power/flow map.

If core flow is < 35 Mlb/hr, then determine if the Region 1 or 2 has been entered Event 4 Continued ATC Determines core flow of approximately 23 Mlb/hr (28 indicated - 5 reverse flow on A Loop)

Determines reactor power at approximately 60 %

Determines current operation in Region 2 Monitors for neutron flux oscillations

QF-1075-02 Rev. 3 (FP-T-SAT-75)

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES BOP Closes the #11 Recirc Pump discharge valve After Approximately 5 minutes, reopen the #11 Recirc Pump discharge valve as follows:

o Determine Rod Block setpoint o

Throttle Open the valve with 3-second open signal o

Verifies no change to Rod Block setpoint o

Fully open the valve Dispatch an out-plant operator to monitor and control Recirc MG Lube Oil Temperature Note: The scenario is expected to progress quickly from the Recirc Pump Trip to rod insertion to flux oscillations, which will not allow adequate time to make a complete Tech Spec determination.

CRS (Time permitting) Refers to TS and enters LCO Conditions for single loop operations 3.4.1 required action B.1 (Recirc Loops Operating) 3.3.1.1-1 Fnct 2a (Flow Biased Scram Setpoint)

CRS Provides crew brief Event 5

61. Insert Control Rods to exit Region 2 CRS Directs control rod insertion to exit Region 2 Verifies operation on the Power to Flow Map Specifies the desired reactor power (Should be less than approximately 45%)

ATC Inserts control rods to exit Region 2 (C.4-F) o Follows the rod sequence from the RWM Rapid Power Reduction program

QF-1075-02 Rev. 3 (FP-T-SAT-75)

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES o

Uses continuous insert method Event 6

62. Neutron Flux Oscillations

a.

When Reactor power has been lowered to <55%

(After rod 26-27 is full in) and as directed by the Lead Examiner, insert MANUAL TRIGGER 9 Key Parameter Response: Operation in Stability Region 2, APRM indications of >10% peak-to-peak oscillations

1) Verify Malfunction RX03 goes active Key Expected Alarms: C05-A-37/45 LPRM HI//Downscale, OPRM Trip Enabled or Alarm CT-8 Scram the reactor in response to core oscillations as indicated by:

Auto Actions: Reactor Scram o

LPRM HI or DOWNSCALE alarms in a wide area of the core that repeatedly alarm, then clear.

ATC Performs actions of C.4-B.05.01.02.A Control of Neutron Flux Oscillations o

LPRM indications on the four rod display indicate an oscillation.

ATC Monitors APRM indications and recognizes oscillations of

>10%

o APRM recorders indicate a peak-to-peak oscillation greater than 10% that is not attributable to pressure or Recirc flow control problems ATC SRO If neutron flux oscillations are observed for any reason while operating in Stability Region 1 or 2, then initiate a Manual Reactor Scram Event 6

63. Reactor Scram response (ATC):

Actions per C.4-A (Reactor Scram):

a.

When the Mode Switch is placed in SHUTDOWN, verify EVENT TRIGGER 28 goes active ATC Depresses MANUAL REACTOR SCRAM pushbuttons.

1) Verify Override 03-A166-02 goes active to fail the Low Flow FRV Place Mode Switch in SHUTDOWN.

2) Verify Malfunction MS04B delay (5 minutes) starts to time down Verify all Control Rods are inserted to or beyond position

04.

Provides scram script to CRS Reports when Reactor level drops to less than 9 EOP entry condition.

Controls Reactor water level between +9 and +48 inches.

When reactor water level starts to increase:

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES o

Place CV-6-13 Manual Loading Station Low Flow Valve in AUTO set between 15 and 20 inches o

Close both Main FW Reg Valves o

Close MO-1133 and MO-1134 (HP Feedwater Line Block valves Event 7

64. Low Flow Feed Reg Valve Failure Key Parameter Response: CV-6-13 does not open when placed in service, no feed flow Key Expected Alarms: 5-B-24 Reactor Water Level HI/LOW does not reset Auto Actions: If no action is taken, HPCI and RCIC will auto start at -

47 inches.

ATC Identifies that CV-6-13 remains closed Note: Use of either the Low Flow FRV in MANUAL or a return to a Main Feed Reg Valve is acceptable.

ATC Attempts to control RPV Water Level with the Low Flow Reg Valve in MANUAL OR Attempts to control RPV Water Level with one or both Main FW Reg Valves.

o Re-opens MO-1133 and MO-1134 (HP Feedwater Line Block valves

QF-1075-02 Rev. 3 (FP-T-SAT-75)

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES o

Adjusts a Main Feed Reg Valve in MANUAL to restore and maintain Level Event 8

65. Reactor Scram response (ATC):

ATC Monitor Reactor Power o

Insert SRM and IRM detectors.

o Switch recorders from APRM to IRM.

o Range down on IRMs as necessary.

Verify SDV Vent and Drain Valves closed.

Event 8

66. Reactor Scram response (BOP):

BOP Starts performance of Part B of C.4.A Announce over the plant paging system that a Reactor Scram has occurred.

Open Main Generator output breakers 8N4 & 8N5.

Trip the Main Turbine.

Verify the Generator Field Breaker Open.

Start the Turbine Aux Oil Pump.

Verify Turbine Exhaust Hood Sprays in service.

Verify Main Steam Pressure Control or Low-Low Set is controlling Reactor Pressure.

Event 8

67. LOCA Inside Drywell INSTRUCTOR NOTE: The LOCA is triggered to start 5 minutes after the Mode Switch is taken to SHUTDOWN.

Key Parameter Response: Drywell Pressure rising, Drywell Temperature rising, Drywell Floor Drain Sump Leakage rising

QF-1075-02 Rev. 3 (FP-T-SAT-75)

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Key Expected Alarms: 3-B-54 (Containment Spray Permissive), 4-B-35 (Drywell-Torus Hi Press)

Auto Actions: When Drywell pressure reaches 1.84 psig: Reactor Scram, ECCS Initiation, Group II Isolation BOP Reports Drywell pressure rising

1. Reports drywell pressure and temperature and torus temperature EOP entry conditions, values, and trends Event 8

68. EOP-1100 RPV Control CRS Supervise response to reactor scram, enters EOP-1100 and directs:

OATC Maintain RPV Water Level 9-48 inches BOP With DW Press >2 psig, before 320 psig Reactor Pressure prevent injection from Core Spray and LPCI NOT needed for core cooling Verifies that RPV pressure is stable and <1056 psig BOP When directed, prevent injection from Core Spray and LPCI NOT needed for core cooling (per C.5-3205)

Prevents CS injection from Div 1 & Div 2 o

Takes CS Injection Bypass switches to BYPASS (14A-S16A & B)

BOP o

Closes CS Injection Outboard valves (MO-1751 and MO-1752) o Takes CS pump Handswitches to Pull-To-Lock o

Closes CS Injection Inboard valves (MO-1753 and MO-1754)

Prevents LPCI Injection

QF-1075-02 Rev. 3 (FP-T-SAT-75)

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES o

Bypasses LPCI Initiation 5-minute seal in by opening knife switches 10A-S31A and 10A-S31B o

Verify closed MO-2012 Div 1 Inj Outboard o

Verify closed MO-2013 Div 2 Inj Outboard Event 8

69. LOCA:

NOTE: The severity of the leak will ramp in over 15 minutes. If mitigating actions are taken promptly Drywell Air Temperature will exceed 281°F in approximately 10 minutes. If mitigating actions are NOT performed efficiently, 281°F will be exceeded more quickly.

BOP Continues to report drywell pressure and temperature and torus temperature EOP entry conditions, values, and trends CRS Enters EOP-1200 and directs:

Start all available torus cooling Start all available drywell cooling Start torus sprays Event 8

70. Torus Cooling / Torus Sprays:

BOP Places Torus Sprays in service per C.5-3502:

Verifies RHR Pumps running Takes Cont Spray/Cooling LPCI Initiation Bypass to BYPASS, 10A-S17A Opens Discharge to Torus Outboard, MO-2006 Opens Torus Spray Inboard, MO-2010

QF-1075-02 Rev. 3 (FP-T-SAT-75)

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Throttles Torus Cooling Inj/Test Inboard, MO-2008 Verifies LPCI Inject Outboard Valves are closed; MO-2012 and MO-2013.

Event 8

71. Initiates Containment Cooling BOP Initiates Containment Cooling o RHRSW Outlet valve controller set to 20%

o Place HX Bypass in CLOSE, MO-2002 o Start RHRSW Pump(s) o Adjust flow to 3500 gpm per pump o Verify HX Bypass closed, MO-2002 o Verify RHR Room Cooler in operation, V-AC-5 Event 8

72. Drywell Cooling:

BOP / ATC Start all available drywell cooling (C.5-3503)

Place all D/W fan control switches to OFF Open Knife switch KS3100 Verify fan inlet dampers are in AUTO, HS-8040 A&C Place all D/W fan control switches to ON, V-RF-1&3 OPEN associated fan disch dampers, V-D-15 & 19 at 100%

QF-1075-02 Rev. 3 (FP-T-SAT-75)

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Event 8

73. Drywell Spray failure BOP / ATC Start D/W sprays Opens the Outboard Drywell Spray valve, MO-2020 Attempts to open the Inboard Drywell Spray valve, MO-2022 Reports inability to spray drywell Event 8

74. Drywell Spray failure/ Blowdown CRS May anticipate Emergency Depressurization / direct opening the Turbine Bypass valves CT-30 When drywell temperature cannot be restored and maintained below 281°F, then perform Emergency Depressurization per C.5-2002.

When D/W temp can NOT be maintained below 281°F directs performance of C.5-2002 (Emergency RPV Depressurization)

Directs injection be prevented from Core Spray and LPCI (NOT needed for Core Cooling)

Verifies Torus level > -5.9 ft.

Directs opening of all 3 ADS SRVs.

Directs RPV Level restoration

QF-1075-02 Rev. 3 (FP-T-SAT-75)

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES

75. SCENARIO TERMINATION

a.

The scenario may be terminated when the conditions are stabilized as follows:

1) Emergency depressurization has commenced

2) RPV water level is stable

b.

The scenario may be also terminated at the discretion of lead instructor/evaluator Crew:

Remain in simulator for potential questions from evaluator.

c.

End the scenario by placing the simulator in FREEZE.

Crew:

No discussion of scenario or erasing of procedure marking is allowed.

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