ML081410680

Proposed Scenarios for the Davis-Besse Initial Examination - February 2008

ML081410680
Person / Time
Site:	Davis Besse
Issue date:	02/28/2008
From:	Valos N NRC/RGN-III/DRS/OLB
To:	FirstEnergy Nuclear Operating Co
References
50-346/08-301
Download: ML081410680 (73)

Text

Appendix D Scenario Outline Form ES-D-1 Facility:

Davis-Besse Scenario No.:

1 Op Test No.:

Examiners:

Operators:

Initial Conditions:

100% power, MOL High Pressure Injection Pump 2 is out of service HIS SP 16, Turbine Throttle Pressure, selected to PT SP16B (NNI-Y)

Turnover: The crew will assume the watch with the plant at 100% power. The Plant Risk level will be YELLOW due to High Pressure Injection Pump 2 out of service for maintenance.

Following turnover the Crew will take action to place TPCW Pump 1 in service and remove TPCW Pump 3 from service for maintenance.

Event No.

Malf.

No.

Event Type*

Event Description 1

N - BOP Swap Turbine Plant Cooling Water Pumps 2

HU 21A C - RO TS - SRO RCP 1-1 loss of oil to upper bearing 3

R - RO Power reduction prior to stopping RCP 1-1 4

SFDVG C - BOP MFPT 2 high vibration 5

LI62L C - RO TS - SRO Stuck Control Rod at 75% power 6

HH43 M - All Reactor Coolant System leak - 2500 gpm 7

L6LE C - RO SFAS Module L231 fails to trip 8

L1T2N I - BOP SG 2 level transmitter fails above setpoint (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D NUREG 1021 Revision 9

Appendix D Scenario Outline Form ES-D-1 DAVIS-BESSE 2008 NRC EXAM SIMULATOR SCENARIO 1 GENERAL DESCRIPTION The crew will assume control with power holding at 100% power.

The Lead Evaluator will cue the Crew to swap of the Turbine Plant Cooling Water Pumps in accordance with DB-OP-06263, Turbine Plant Cooling Water System.

The Lead Evaluator will cue the oil leak on RCP 1-1 thrust bearing. The oil leak will cause a low oil level computer alarm and an increase in bearing temperatures. The crew should respond to alarm 6-1-A, in accordance with DB-OP-02006, Reactor Coolant Pump Alarm Panel 6 Annunciators, and then enter DB-OP-02515, Reactor Coolant Pump And Motor Abnormal Operation. DB-OP-02515 will require the crew to reduce power to 72% using DB-OP-02504, Rapid Shutdown, and then stop the affected RCP. The SRO should enter the proper Tech Spec after the RCP is stopped.

After the RCP is stopped the Lead Evaluator will cue the increase in MFPT 2 vibrations. The Crew should respond using DB-OP-2010, Feedwater Alarm Panel Annunciators The vibrations will increase to the point that a trip of MFPT 2 is required. The plant will automatically runback to 55% power when the MFPT is tripped.

During the plant runback, a Control Rod will stick. The crew should respond to alarm 5-2-E, CRD ASYM-METRIC ROD, in accordance with DB-OP-02516, CRD Malfunctions. The SRO should enter Tech Spec 3.1.3.1. The Tech Spec power limit with a stuck rod and 3 RCPs is 45% power (320 MWE). The crew should reduce power in accordance with DB-OP-02504, RAPID SHUTDOWN.

During the power reduction the Lead Evaluator will cue the RCS leak. This will lower Pressurizer level and the crew should trip the reactor when 100 is reached in accordance with DB-OP-02522, Small RCS Leaks. The crew will transition to DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube Rupture when the reactor trips.

RCS pressure will lower and a loss of subcooling margin will occur. The crew will trip all running RCPs and route to DB-OP-02000, Section 5.0, Lack Of Adequate Subcooling Margin. The RCS leak is large enough to cause an SFAS actuation.

The failure of a SFAS module will prevent Component Cooling Water Pump 1 from operating and SG 1 level will not control at the higher SG level setpoint. The crew should start CCW Pump 1 and manually control level at the higher level or manually select the HIGH setpoint for SG 1 level.

The failure of the SG 2 level transmitter will cause a loss of level in SG 2. Manual control of the SG 2 level control valve is required to maintain proper level in the SG.

The Lead Evaluator can terminate the scenario when all high level activities have been completed and the evaluators agree the crew can be properly evaluated.

Appendix D NUREG 1021 Revision 9

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 1 Event No.: 1 Page 1 of 1 Event

Description:

After turnover is complete the crew will refer to section 3.2 of DB-OP-06263, Turbine Plant Cooling Water System, to start TPCW Pump 1 and stop TPCW Pump 3 due to increasing vibrations on TPCW Pump 3.

Time Position Applicants Actions or Behavior BOP Verify the TPCW System is in service by checking that TPCW Pump 2 and TPCW Pump 3 are running BOP Verify the prestart checklist is complete for TPCW Pump 1 BOP Start TPCW Pump 1 using HIS 627 BOP Stop TPCW Pump 3 using HIS 629 BOP Direct an Equipment Operator to check the oil level on the motor for TPCW Pump 1 After TPCW Pump 3 is started direct the Simulator Operator to insert Event Line 2 for an RCP 1-1 oil leak Page 1 of 15

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 1 Event No.: 2 & 3 Page 1 of 2 Event

Description:

After the TPCW Pumps have been swapped an oil leak will develop on Reactor Coolant Pump 1-1 requiring a power reduction to 72% power in order to stop the pump. Tech Specs for operable RCS loops and RPS setpoints will be applicable Time Position Applicants Actions or Behavior Crew Recognize an oil leak on RCP 1-1 Computer point for RCP 1-1 Thrust Bearing oil level, L791 6-1-A 1-1 MOTOR VIB HI RO Attempt to reset annunciator 6-1-A SRO Implement DB-OP-02515, RCP and Motor Abnormal SRO Direct load reduction to 72% power per DB-OP-02504 Rapid Shutdown SRO Notify the Load Dispatcher RO Perform Rapid Shutdown actions Set Rate of Change as directed by the SRO Verify the MIN LIMIT is set to 180 MWE Lower power using the DECREASE pushbutton Monitor Rod insertion limits using the Reactor Operator Guidance sheet or Tech Spec 3.1.3.6 Maintain Imbalance using APSRs BPO Perform Rapid Shutdown actions Notify Chemistry to monitor polishers and sample the RCS At 90%, remove the AFPT Main Steam Minimum flow lines from service When condensate flow is <7.0 MPPH then stop one Condensate pump Page 2 of 15

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 1 Event No.: 2 & 3 Page 2 of 2 Event

Description:

Continued Time Position Applicants Actions or Behavior SRO When power has decreased to 72% return to DB-OP-02515 RO When power has decreased to 72% stop RCP 1-1 Run oil lift pump as necessary BOP Verify proper feedwater re-ratio SG 2 flow should be 2.4 times the SG 1 flowrate RO Verify Tave control on the Reactor Coolant Loop 2 SRO Refer to Tech Specs 3.2.5 for RCS flow 3.4.1.1 for RPS trip setpoints SRO Contact I&C to verify //Flow trips and adjust High Flux trips After the Tech Specs are reviewed, direct the Simulator Operator to insert Event Line 4 to increase vibrations on Main Feed Pump Turbine 2 Page 3 of 15

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 1 Event No.: 4 Page 1 of 1 Event

Description:

Following the power reduction for stopping the RCP, the vibrations on MFPT 2 will increase. The increase in vibrations will require MFPT 2 to be manually tripped causing an automatic runback to 55% power.

Time Position Applicants Actions or Behavior CREW Recognize high MFPT 2 vibrations 10-3-B MFP 2 OR BFP 2 BEARING VIB HI Computer Point V651, MFP, MFPT, GEAR, OR BFP 2 BRG VIB BOP Refer to DB-OP-2010, Feedwater Alarm Panel Annunciators BOP Direct an Equipment Operator to monitor MFPT 2 vibrations locally BOP Check vibration reading on ZJR 2538, Main Turbine and MFP Turbines Bearing Vibration and Eccentricity BOP Check vibration levels are above the second computer alarm setpoint of 5.0 Mils BOP Trip MFPT 2 using HS 798 SRO Refer to DB-OP-06401, ICS Operating Procedure CREW Verify a proper ICS runback to 55% power occurs RO Verify RC 2, Pressurizer Spray Valve, is in automatic and closed RO Perform an NI Power/Heat Balance Power comparison Event Line 5 for the stuck rod will automatically insert when power is less than 60%

Page 4 of 15

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 1 Event No.: 5 Page 1 of 2 Event

Description:

During the plant runback, Control Rod 7-4 will become stuck when power goes below 60% power. The stuck rod will require a Shutdown Margin determination, implementation of Tech Specs and a plant shutdown.

Time Position Applicants Actions or Behavior CREW Recognize a stuck/misaligned Control Rod 5-1-E CRD LCO 5-2-E CRD ASYMMETRIC ROD Control Rod 7-4 misaligned with Rod Group 7 SRO Implement DB-OP-02516, CRD Malfunctions RO Check Reactor power is > 5%

RO Check only one Control Rod is misaligned SRO Refer to NOP-OP-1004, Reactivity Management Notify Operations Management Notify the Shift Manager SRO Request I&C investigate the misaligned Control Rod CREW Determine Control Rod is stuck SRO Refer to Tech Spec 3.1.3.1 Page 5 of 15

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 1 Event No.: 5 Page 2 of 2 Event

Description:

Continued Time Position Applicants Actions or Behavior CREW Determine adequate Shutdown Margin exists SRO Refer to DB-OP-02504 and begin a plant shutdown SRO Notify the Load Dispatcher RO Perform Rapid Shutdown actions Set Rate of Change as directed by the SRO Verify the MIN LIMIT is set to 180 MWE Lower power using the DECREASE pushbutton Monitor Rod insertion limits using the Reactor Operator Guidance sheet or Tech Spec 3.1.3.6 Maintain Imbalance using APSRs After the power reduction has begun, direct the Simulator Operator to insert Event Line 6 to start the RCS leak Page 6 of 15

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 1 Event No.: 6,7,8 Page 1 of 4 Event

Description:

An RCS leak leads to a Reactor trip, automatic SFAS actuation and a loss of adequate subcooling margin. An SFAS malfunction prevents CCW Pump 1 from automatically starting and providing cooling water to the only operable HPI Pump and prevents AFW from automatically raising SG 1 level to the 124 inch setpoint. Following the Reactor trip, Steam Generator 2 level transmitter fails causing a failure of automatic AFW level control that require manual control of SG 2 level.

Time Position Applicants Actions or Behavior CREW Identify symptoms of RCS leak inside Containment Normal sump level rising Radiation levels rising MU flow rising MU tank level dropping SRO Route to DB-OP-02522, Small RCS Leaks RO Determine Pressurizer level is NOT being maintained RO Isolate Letdown RO Monitor Pressurizer level and Makeup tank level RO Calculate the leak rate RO Start the standby Makeup pump RO When Pressurizer level falls below 100 then trip the Reactor Page 7 of 15

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 1 Event No.: 6,7,8 Page 2 of 4 Event

Description:

Continued Time Position Applicants Actions or Behavior RO Perform DB-OP-02000 Immediate Actions

• Manually trip the reactor

• Verify power decreasing in the intermediate range

• Manually trip the turbine SRO Implement DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube Rupture SRO Verify Immediate Actions CREW Check for Specific Rules implementation RO Implement Specific Rule 2 - Loss of Subcooling Margin Time SCM lost ________

• Trip all RCPs Time RCPs are tripped BOP Implement Specific Rule 4 - Steam Generator Control

- Recognize neither SG is feeding up to the proper level

• Manually control AF 6452 to feed SG 1 to the proper level OR select HIGH on HIS 6453

• Manually control AF 6451 to feed SG 2 to the proper level RO Implement Specific Rule 6

- Recognize CCW Pump 1 did not automatically start

• Manually start CCW Pump 1

• Critical Task Page 8 of 15

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 1 Event No.: 6,7,8 Page 3 of 4 Event

Description:

Continued Time Position Applicants Actions or Behavior RO Check for Symptom direction Recognize Loss of Subcooling Margin SRO Implement DB-OP-02000, Section 5 RO

• Verify all RCPs are tripped Time RCPs are tripped RO Implement Attachment 8, Place MU/HPI/LPI in Service Set Pressurizer Level Controller to 100 inches Lock MU Pump suctions on the BWST Start/Verify running the second MU Pump

• Start/Verify running the standby CCW Pump Recognize only HPI Pump 1 running Verify open HP 2A, HP 2B, HP 2C and HP 2D Start both LPI Pumps Open DH 64 and DH 63 RO Implement Attachment 11 for HPI flow balancing Close MU 6421 Verify HP 2C and HP 2D are open Compare HPI flow through each injection line to Figure 3 RO Verify proper SFAS actuation

• Critical Task Page 9 of 15

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 1 Event No.: 6,7,8 Page 4 of 4 Event

Description:

Continued Time Position Applicants Actions or Behavior BOP Verify proper SFRCS actuation BOP Verify proper SG level control BOP Realign AFW if an SFRCS low pressure trip occurs RO Check for LPI flow CREW Check for Overcooling RO Isolate possible RCS leaks per Attachment 19 RC 11, PORV Block Valve RC 2, Spray Valve RC 10, Spray Block Valve RCS High Point Vents Pressurizer Sample Valves RCS Sample Valves CREW Check for ICC Conditions CREW Monitor for adequate Subcooling Margin Termination Criteria SG levels at the proper setpoint HPI and Makeup are maintaining core cooling Site Area Emergency based on EAL 2.A.4 for an RCS leak larger than High Pressure Injection system capacity Page 10 of 15

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 CRITICAL TASK JUSTIFICATION Trip all RCPs within 2 minutes of a loss of subcooling margin SSig - Failure to do so could lead to uncovering the core if stopped later Cue - SCM less than 20°, Procedural guidance MPI - RCP switches to OFF OPF - RCPs green lights on, zero amps KSA Number: 011-EA1.03 (4.0/4.0) Ability to operate and monitor the securing of the RCPs Manually start a CCW Pump SSig - Failure to do so could lead to loss of cooling to the only available HPI Pump Cue - CCW Pump 1 not running, Procedural Guidance MPI - CCW Pump 1 switch to START OPF - CCW Pump 1 RED light on KSA Number: 008-A4.08 (3.1/2.8) Ability to manually operate CCW Pump Control Switch from the Control Room Manually control AFW flow to feed at least one SG SSig - Provide for auxiliary feedwater for core cooling via the SGs when subcooling margin is regained Cue - Procedural direction MPI - Target rock controllers in MANUAL and throttled open OPF - Flow to at least one SG, SG(s) level(s) increasing KSA Number: 061-A2.05 (3.1/3.4) Ability to predict the impact of an automatic control malfunction for AFW Page 11 of 15

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 SCENARIO ATTRIBUTES Total Malfunctions 7

Malfunctions after EOP Entry 2

Abnormal Events 3

Major Transients 1

EOPs 1

EOP Contingencies 2 (Specific Rule 4, Specific Rule 6)

Scenario Runtime 75 minutes EOP runtime 30 minutes Crew Critical Tasks 3

Technical Specifications Exercised 2

Page 12 of 15

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 CUE SHEET Event 1 - Swap TPCW Pumps Role play as an Equipment Operator to inspect TPCW Pump 1. Report oil level is visible in the bullseye on the motor Event 2 and 3 - RCP Oil Leak and Power Reduction Role play as the System Dispatcher to acknowledge the power reduction Role play as Chemistry to support the power reduction Role play as I&C for verifying //flow trips and resetting High Flux trips Event 4 - MFPT 2 High Vibrations Role play as an Equipment Operator to monitor local vibrations on MFPT 2 Event 5 - Stuck Control Rod Role play as Operations Management for Reactivity Management notifications Role play as I&C for investigating the potential misaligned rod Role play as Reactor Engineering to provide assistance for the stuck rod Role play as the System Dispatcher to acknowledge the power reduction Event 6, 7, and 8 - RCS Leak, Reactor Trip and AFW Level Control Malfunctions Page 13 of 15

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Simulator Setup Instructions

1. Verify the following:

a. Previous data on Yokogawa recorders is cleared

b. Chart recorders are rolled forward

c. Applicable procedures are wiped cleaned

d. Used Alarm Typer paper is removed

e. Computer alarms are cleared/acknowledged

2. Initialize at 100% power

3. Equipment Status:

a. Hang License Requirement Sheet on the status board

b. Tag out HPI Pump 2 Switch

c. Turn on the HPI blue status

d. Hang Protected Train 1 signs

e. Select SP16B for Turbine Throttle Pressure input

f. Reset SASS annunciators as required

4. Set Up Batch File

a. Initial Setup

- Rackout the breaker for HPI Pump 2 IRF BFP2A RACKOUT

- Fail SFAS Channel 1 Output Module L231 IMF L6LE

- Fail SP16A low to put SP16B in service IMF L1T2N 0.0 Page 14 of 15

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2

b. Triggers

- Reactor power < 60% activates the stuck rod TRGSET 5 RATPW<59.0

- Reactor power < 5% activates the SG 2 Startup Level transmitter (SP9A3) failing to 140" TRGSET 8 RATPW<5.0

c. Events Event 1 - Swap TPCW pumps Event 2 - RCP 1-1 loss of upper bearing oil IMF HU21A (2) 0.85 00:03:00 Event 3 - Power Reduction Event 4 - MFPT 2 vibrations IMF SFDVG (4) 1.0 00:06:00 0.0 Event 5 - Stuck Rod 7-4 at 60% power IMF LI62L (5)

Event 6 - 2500 gpm RCS leak IMF HH43 (6) 0.0028 00:01:00 0.0 Event 7 - SFAS Modules L231 fail to trip Event 8 - Reactor power < 5% triggers SG 2 Startup Level transmitter (SP9A3) failing to 140" IMF L1TH20 (8) 0.55 00:00:20 0.17 Page 15 of 15

Appendix D Scenario Outline Form ES-D-1 Facility:

Davis-Besse Scenario No.:

2 Op Test No.:

Examiners:

Operators:

Initial Conditions:

60% power, MOL 3 Reactor Coolant Pumps running, RCP 1-1 not running Decay Heat Pump 1 is out of service HIS SP 16, Turbine Throttle Pressure, selected to PT SP16B (NNI-Y)

Turnover: The crew will assume the watch with the plant at 50 - 60% power. Three RCPs are running. RCP 1-1 was stopped due to low oil level in the lower bearing reservoir. Senior Management is currently deciding when to begin a plant shutdown to repair RCP 1-1. The Plant Risk level will be YELLOW due to Low Pressure Injection Pump 1 out of service for maintenance. Following turnover the Crew will take action to transfer Gland Steam from Main Steam to Auxiliary Steam in order allow packing adjustment on GS 2384, Seal Steam Supply Valve Event No.

Malf.

No.

Event Type*

Event Description 1

N - BPO Transfer Gland Steam from Main Steam to Auxiliary Steam 2

SFEJA TS - SRO The crew will be notified that Auxiliary Feedwater Pump 1 has no Governor oil 3

H170 C - RO Pressurizer level control valve (MU 32) fails to operate in auto 4

LI53B R - RO TS - SRO Control Rod drop 5

NP19D I - BOP Loss of NNI-Y DC 6

PLZZ M - All Loss of Offsite AC 7

G529B C - RO Emergency Diesel Generator 1 fails to auto start 8

SFERE C - BOP AFW Pump 2 governor valve closes (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D NUREG 1021 Revision 9

Appendix D Scenario Outline Form ES-D-1 DAVIS-BESSE 2008 NRC EXAM SIMULATOR SCENARIO 2 GENERAL DESCRIPTION The crew will assume control with power at 60% power and 3 Reactor Coolant Pumps in operation.

After turnover is complete the Lead Evaluator will direct the crew to transfer Gland Steam from Main Steam to Auxiliary Steam.

The Lead Evaluator will cue the Auxiliary Feedwater Pump 1 governor oil problem. The crew should review T.S. 3.7.1.2 and declare AFW 1 inoperable. This will put the plant in a 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Action Statement.

The Lead Evaluator will cue the MU 32 failure to operate in automatic due to a blown fuse.

Annunciator 14-2-E, ICS/NNI FUSE BLOWN on MSR/ICS Alarm Panel 14 Annunciators will alarm. The crew should refer to DB-OP-02014 and identify the blown fuse is preventing MU 32 from responding in automatic. The crew should take the MU 32 to HAND and control Pressurizer level by adjusting Makeup system flow manually.

The Lead Evaluator will cue the dropped rod. The crew should enter DB-OP-02516, CRD Malfunctions. The SRO should enter Tech Spec 3.1.3.1. The Tech Spec Limit with a dropped rod and 3 RCPs running is 45% power (320 MWE). The crew should reduce power in accordance with DB-OP-02504, Rapid Shutdown.

The Lead Evaluator will cue the Loss of NNI-Y DC power during control rod recovery.

Annunciator 14-1-E, NNI-Y 24 VDC BUS TRIP, on MSR/ICS Alarm Panel 14 Annunciators will alarm. The crew should enter DB-OP-2532, Loss of NNI/ICS Power. The crew should recognize a minor transient is in progress due to the mid-scale failure of Turbine Throttle Pressure by transferring the Turbine to MANUAL and transferring the SG/Rx Demand Station to HAND, and lowering the Turbine load.

The Lead Evaluator will cue the Loss of Offsite AC power. The crew will enter DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube Rupture, when the reactor trips. Emergency Diesel Generator (EDG) 1 will fail to auto start. EDG 1 should be started manually.

The AFPT 2 governor valve will fail closed when AFW Pump 2 receives a start signal. The crew should respond by entering DB-OP-02000, Section 6, Lack Of Heat Transfer. The crew should energize non-essential electrical bus D2 from the Station Blackout Diesel Generator or one of the EDGs and align the Motor Driven Feedwater Pump to feed at least one of the Steam Generators.

The Lead Evaluator can terminate the scenario when all high level activities have been completed and the evaluators agree the crew can be properly evaluated.

Appendix D NUREG 1021 Revision 9

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 2 Event No.: 1 Page 1 of 1 Event

Description:

Following turnover the Crew will transfer Gland steam from the Main Steam system to the Auxiliary Steam System in accordance with section 3.6 of DB-OP-06205, Turbine Generator And Main Feedwater Pump Turbine Gland Steam And Turbine Drains Time Position Applicants Actions or Behavior BOP Verify the 235 psig Aux Steam Header is in service BOP Open AS1934, Aux Steam Supply to 5# Condensate Tank 1-1 Control Valve, for 1 minute and then close AS 1934 BOP Throttle open GS 2385, Steam Seal Feed Bypass, to control Gland Steam pressure at 4.5 psig using HIS 2385 BOP Close GS 2384, Seal Steam Supply Valve using HIS 2384 BOP Open GS 2380, Aux Steam Supply Steam Seal Valve, using HIS 2380 BOP Close GS 2385 using HIS 2385 BOP Verify Steam Seal Header pressure is between 2.5 to 4.5 psig After the Gland Steam System supply is transferred to the Auxiliary Steam System direct the Simulator Operator to enter Event Line 2 and to call the Control Room to report the oil sight glass on the AFPT 1 governor is broken and the oil has leaked out of the governor Page 1 of 16

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 2 Event No.: 2 Page 1 of 1 Event

Description:

An Equipment Operator will report that AFPT 1 Governor oil sightglass is broken and the oil has leaked out. The SRO should declare AFPT 1 inoperable and entered the AFW Tech Spec Time Position Applicants Actions or Behavior SRO Determine AFW Pump 1 is inoperable SRO Refer to Tech Spec 3.7.1.2 SRO Notify Operations Management of the unplanned entry into Tech Specs After the AFW Tech Spec is entered, direct the Simulator Operator to enter Event Line 3 to fail the automatic response of MU 32 Page 2 of 16

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 2 Event No.: 3 Page 1 of 1 Event

Description:

The NNI fuse that powers the automatic control for MU 32 will blow causing MU 32 to fail closed while the HAND/AUTO station is in automatic. The Crew will either control MU 32 in manual or place the alternate Makeup injection line in service Time Position Applicants Actions or Behavior CREW Recognize a blown fuse to MU 32 controller 14-2-E ICS/NNI FUSE BLOWN Pressurizer level decreasing with MU 32 closed Computer Alarm (Q718) NNI FUSE BOP Refer to DB-OP-02014, MSR/ICS Alarm Panel 14 Annunciators BOP Check the blown fuse indicators in the top of the front and back of the NNI Cabinets NNI cabinets are not modeled on the simulator. The NRC Examiner will inform the Operator that the blown fuse indicator is lit for Fuse 1 in NNI Cabinet 5759B. The fuse is labeled RC-LIC14 RO Place MU 32 in MANUAL and maintain desired Pressurizer level OR Place the Makeup System alternate injection line in service Close MU 6422, Makeup Train 2 To RCS Isolation Open MU 6421, Makeup Train 1 To RCS Isolation Throttle open MU 6419, Makeup Train 1 Injection, to maintain desired Pressurizer level Direct an Equipment Operator to open MU 6423B, Makeup Train 1 Flow Controller Bypass After Pressurizer level is restored, direct the Simulator Operator to enter Event Line 4 to drop Control Rod 5-8.

Page 3 of 16

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 2 Event No.: 4 Page 1 of 2

Event

Description:

Control Rod 5-8 will drop requiring a rapid power reduction in accordance with DB-OP-02516, CRD Malfunctions, to comply with Tech Specs.

Time Position Applicants Actions or Behavior CREW Recognize a dropped control rod Annunciator 5-1-E, CRD LCO Annunciator 5-2-E, CRD ASYMETRIC ROD Control Rod 5-8 Rod Bottom light ON SRO Implement DB-OP-02516, CRD Malfunctions RO Reduce Reactor power to 50%

Reduce ULD MAX LOAD LIMIT to 320 MWE Set ULD to 30 MWE/ MIN SRO Refer to DB-OP-02504, Rapid Shutdown SRO Notify the Load Dispatcher of plant shutdown SRO Contact Chemistry to monitor Condensate Polishers and sample the RCS RO Maintain Makeup tank level BOP Remove a Main Feed Pump from service Place the ICS controller in HAND and lower speed to 3900 RPM Null the transfer volts using the MDT 20 output Place the MDT 20 control in MANUAL Lower the MDT 20 to the LOW SPEED STOP Trip the MFPT Verify the Discharge NRV is closed Page 4 of 16

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 2 Event No.: 4 Page 2 of 2 Event

Description:

Continued Time Position Applicants Actions or Behavior RO Manually control Pressurizer level RO Stabilize power at < 45%

Adjust the ULD MAX LOAD LIMIT as directed Adjust the ULD RATE OF CHANGE as directed SRO Refer to NG-DB-00230, Reactivity Management SRO Contact Reactor Engineering RO Contact Work Week Manager/I&C to investigate SRO Refer to DB-OP-02516 Attachment 3 to determine Tech Spec applicability Tech Spec. 3.1.3.1 for the dropped rod After power is stabilized and Tech Specs are reviewed direct the Simulator Operator to enter Event Line 5 for the loss of NNI-Y DC power Page 5 of 16

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 2 Event No.: 5 Page 1 of 1 Event

Description:

A loss of NNI-Y DC power will cause Turbine Throttle Pressure to fail midscale since the controlling signal is powered from NNI-Y. The Crew will be required to manually control the Main Turbine to maintain Throttle Pressure Time Position Applicants Actions or Behavior CREW Recognize a loss of NNI-Y DC Power 14-1-E NNI-Y 24 VDC BUS TRIP Loss of Y-DC NNI Power Indicating Light on Control Room Panel C5722 SRO Implement DB-OP-02532, Loss of NNI/ICS Power CREW Recognize a midscale failure of Turbine Throttle Pressure Recorder SP 16 indicates 900 PSI Steam Generator pressures decreasing BPO Place the EHC Control Panel in MANUAL RO Place the SG/Rx Demand Station in HAND BOP Adjust Turbine load using the INCREASE and/or DECREASE pushbuttons to restore Turbine Throttle Pressure as directed by the SRO RO Monitor Makeup Tank level using NNI-Y powered indication Manually transfer Makeup Pump suction valves as required After the Turbine Throttle Pressure is restored, direct the Simulator Operator to insert Event Line 6 for the loss of offsite power Page 6 of 16

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 2 Event No.: 6,7,8 Page 1 of 5 Event

Description:

A loss of offsite electrical power causes a Reactor trip and a loss of all RCPs. The loss of the RCPs causes a SFRCS actuation. AFPT 1 will start and overspeed trip due to the loss of governor oil. AFPT 2 fails to start requiring the use of the MDFP. D2 Bus will have to be reenergized to provide power to D2 Bus. EDG 1 fails to automatically start but can be started manually from the Control Room Time Position Applicants Actions or Behavior CREW Recognize a loss of offsite power and Reactor trip RO Perform DB-OP-02000 Immediate Actions

• Manually trip the reactor

• Verify power decreasing in the intermediate range

• Manually trip the turbine SRO Route to DB-OP-02000, Section 3 SRO Verify immediate actions CREW Implement Specific Rules RO/BOP

• Use Attachment 6 of DB-OP-02000 to re-power D2 Bus

- From the SBODG Open ABDD2 Verify AD 110 is open Start the SBODG by pressing START at the SBODG Control Panel C5740 Check SBODG speed approximately 900 RPM Verify AD213 is closed Close AD 301 to energize Bus D2 Verify Bus D2 energized Verify AD2DF7 is closed Verify BDF7 is closed

• Critical Task Page 7 of 16

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 2 Event No.: 6,7,8 Page 2 of 5 Event

Description:

Continued Time Position Applicants Actions or Behavior RO/BOP

• Use Attachment 6 of DB-OP-02000 to re-power D2 Bus

- From EDG 2 Verify AD301, SBODG BKR is open Verify AD205, XFMR BDF6 is open Verify AD206, CLNG WTR PMP 2 is open Verify AD201, STA AIR CMPSR 2 is open or lock out Verify AD202, CLNG TWR MU PMP 2 is open Verify AD204, HTR DRN PMP 2 is open Verify AD207, CNDS PMP 2 is open Verify AD210, MOTOR DRIVEN FEED PUMP is open Open ABDD2, HIS 6228, ABDD2 Place D1 SYNC SELECT to BKR to D2 Close AD110, HIS 6233, AD110 Verify D2 is energized Place D1 SYNC SELECT in the OFF Close AD2DF7 Verify BDF7 is closed

- From EDG 1 Verify AD301, SBODG BKR is open Verify ABDD2, BUS TIE XFMR BD is open Verify AD205, XFMR BDF6 is open Verify AD206, CLNG WTR PMP 2 is open Verify AD201, STA AIR CMPSR 2 is open or lock out Verify AD202, CLNG TWR MU PMP 2 is open Verify AD204, HTR DRN PMP 2 is open Verify AD207, CNDS PMP 2 is open Verify AD210, MOTOR DRIVEN FEED PUMP is open Verify AD110 is open, HIS 6233, AD110 Verify HBBD is open, HIS 6214, HBBD Verify AC110 is open, HIS 6223, AC110 Place the C1 SYNC SELECT Switch to BKR TO XBD Close ABDC1, HIS 6220, ABDC1 Place the C1 SYNC SELECT Switch to OFF Close ABDD2, HIS 6228, ABDD2 Verify D2 is energized Close AD2DF7 Verify BDF7 is closed

• Critical Task Page 8 of 16

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 2 Event No.: 6,7,8 Page 3 of 5 Event

Description:

Continued Time Position Applicants Actions or Behavior BOP

• Use Attachment 5 of DB-OP-02000 to start the MDFP

- Enable BOTH MDFP Discharge Valves HIS 6460 HIS 6459

- Close BOTH MDFP Discharge Valves LIC 6460 LIC 6459

- Start the MDFP

- Establish feedwater flow to both Steam Generators at less than 1000 gpm indicated flow on the MDFP Flow Indicator FI 5876 BOP Verify proper SG level control using Specific Rule 4, Steam Generator Control BOP Direct an Equipment Operator to locally shift MDFP recirculation to the CST RO Implement Specific Rule 6 Verify MU Pump 1 breaker is open Manually start EDG 1 Verify C1 Bus is energized Verify CCW Pump 1 is running Verify Service Water Pump 1 is running CREW Recognize lowering Instrument Air pressure BOP Start the EIAC

• Critical Task Page 9 of 16

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 2 Event No.: 6,7,8 Page 4 of 5 Event

Description:

Continued Time Position Applicants Actions or Behavior CREW Check for symptom direction RO Check for all Group 1-7 Control Rods fully inserted RO Perform Attachment 1, Primary Inventory Control Actions Transfer MU Pump suctions to the BWST Close MU 19 Start both Makeup Pumps Manually control MU 6419 to control Pressurizer level at 80 to 120 inches Brief the SRO on Primary Plant status BPO Perform Attachment 2, Steam Generator Inventory and Pressure Control Actions

- Verify Steam Generator Levels are being controlled at 49 inches with the MDFP

- Place the Atmospheric Vent Valves in manual using Attachment 3

Place the AVV Hand/Auto Stations in HAND Reduce the AVV demands to zero Press the AVV 2 BLOCK pushbuttons Press AUTO on the AVV 2 Hand Indicating Switch Control Steam Generator Pressure as required from the Hand/Auto stations to maintain RCS Tave constant or slightly lowering using both AVVs

- Establish one Condensate Pump operation Page 10 of 16

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 2 Event No.: 6,7,8 Page 5 of 5 Event

Description:

Continued Time Position Applicants Actions or Behavior BOP Check for NNI Power available RO Monitor Makeup Tank level using the NNI-X powered level indicator BOP Check for ICS Power available BOP Check for Instrument Air available RO Check SFAS has not actuated BOP Verify proper SFRCS actuation for the trip parameters present using Table 1 CREW Check for:

Adequate subcooling margin Proper primary to secondary heat transfer SG Tube Rupture Termination criteria MDFP supplying AFW to both SGs Pressurizer level being manually controlled at the proper level Unusual Event per EAL 4.A.1 for loss of offsite power Page 11 of 16

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 CRITICAL TASK JUSTIFICATION Re-power D2 Bus SSig - Failure to do so will cause a loss of all feedwater Cue - Loss of normal power to D2 Bus, Procedural guidance MPI - D2 Bus powered from SBODG OR D2 Bus powered from D1 Bus OR D2 Bus powered from C1 Bus OPF - D2 Bus Voltage indicates 4160 Volts KSA Number: 064-A4.06 (3.9/3.9) Ability to manually start and load EDG from the Control Room Feed at least one SG using the MDFP SSig - Failure to do so will cause a loss of all feedwater Cue - Aux Feedwater Pumps not running, Procedural Guidance MPI - MFFP switch to START, MDFP discharge valve(s) open OPF - Flow to the SG(s), SG level(s) increasing KSA Number: 056-AA1.10 (4.3/4.3) Ability to operate Aux/Emergency Feedwater Pumps during a loss of offsite power Page 12 of 16

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 SCENARIO ATTRIBUTES Total Malfunctions 7

Malfunctions after EOP Entry 3

Abnormal Events 3

Major Transients 1

EOPs 1

EOP Contingencies 2 (Attachment 6 and Attachment 5 of DB-OP-02000)

Scenario Runtime 75 minutes EOP runtime 30 minutes Crew Critical Tasks 2

Technical Specifications Exercised 2

Page 13 of 16

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 CUE SHEET Event 1 - Transfer Gland Steam from Main Steam to Aux Steam Event 2 - Loss of oil in AFPT 1 governor Role play as an Equipment Operator to call the Control Room to report the oil sight glass on the AFPT 1 governor is broken and the oil has leaked out of the governor Role play as Maintenance to investigate the broken sightglass on the AFPT 1 governor Event 3 - MU 32 blown fuse Role play as I&C for investigating/replacing the blown fuse Event 4 - Dropped Control Rod Role play as Operations Management for Reactivity Management notifications Role play as an Equipment Operator/I&C for investigating the dropped rod Role play as the System Dispatcher to acknowledge the power reduction Event 5 - Loss of NNI-Y DC Role play as I&C for investigating loss of NNI-Y DC Event 6, 7 and 8 - Loss of offsite power, Reactor trip, failure of EDG 1 to automatically start and loss of both AFW Pumps Role play as an Equipment Operator to investigate the loss of both AFW Pumps. Report AFPT 1 tripped on overspeed due to no Governor control oil and AFPT 2 governor valve is stuck closed Page 14 of 16

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Simulator Setup Instructions

1. Verify the following:

a. Previous data on Yokogawa recorders is cleared

b. Chart recorders are rolled forward

c. Applicable procedures are wiped cleaned

d. Used Alarm Typer paper is removed

e. Computer alarms are cleared/acknowledged

2. Initialize at 60% power

3. Equipment Status:

a. Hang License Requirement Sheet on the status board for LPI Train 1 and RCP 1-1

b. Tag out LPI Pump 1

c. Turn on the LPI blue status

d. Hang Protected Train 2 signs

e. Select SP16B for Turbine Throttle Pressure input

f.

Reset SASS annunciators as required

4. Set Up Batch File

a. Initial Setup

- Rackout the breaker for LPI Pump 1 IRF BDP1A RACKOUT

- EDG 1 fails to automatically start IRF G529B

- RCP 1-1-1 seal 1 leak IMF HN09 0.4

- RCP 1-1-1 seal 2 leak IMF HN08 0.0017 Page 15 of 16

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2

- Fail SP16A low to put SP16B in service IMF L1T2N 0.0

b. Triggers

- AFPT 2 Gov Valve closes when AFPT 2 steam admission valve opens TRGSET 8 SXA5889B>0.2

c. Events Event 1 - Transfer GS from Main Steam to Auxiliary Steam Event 2 - Loss of oil from AFPT 1 governor IMF SFEJA (2)

Event 3 - Blown fuse causes MU32 to fail to control in automatic IRF H170 (3) TRUE Event 4 - Rod 5-8 drops, location M-5 IMF LI53B (4)

Event 5 - Loss of NNI Y DC IMF NP19D (5) TRUE Event 6 - Loss of offsite power IMF PLZZ (6)

Event 7 - EDG 1 fails to automatically start Event 8 - AFPT 2 Gov Valve closes when the AFP starts IMF SFERE (8) TRUE Page 16 of 16

Appendix D Scenario Outline Form ES-D-1 Facility:

Davis-Besse Scenario No.:

3 Op Test No.:

Examiners:

Operators:

Initial Conditions:

50% power, MOL Emergency Diesel Generator 1 out of service MFPT 1 on the Turning Gear HIS SP 16, Turbine Throttle Pressure, selected to PT SP16B (NNI-Y)

Turnover: The crew will assume the watch with the plant at 50% power and Emergency Diesel Generator 1 out of service for maintenance. The Plant Risk level will be YELLOW. MFPT 2 is on line and MFPT 1 is on the turning gear. Following turnover the Crew will take action to perform the Turbine-Generator Backup Overspeed Trip Circuit Test Event No.

Malf.

No.

Event Type*

Event Description 1

N - BOP Perform TG Backup Overspeed Test, DB-SS-04154 2

B2M1N C - RO TS - SRO Make-Up Pump 1 trips 3

BV24B C - RO MU 1903 fails closed 4

HH50 R - RO TS - SRO SG 1 tube leak and plant shutdown 5

UF09A UF08A UF11A UF06A C - BOP Turbine Vibration 6

HH50 M - All SG 1 Tube Rupture and Reactor trip 7

SFDPC M - All Loss of Main Feedwater 8

F30AB F30AC C -BOP SFRCS Channel 1 fails to actuate (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D NUREG 1021 Revision 9

Appendix D Scenario Outline Form ES-D-1 DAVIS-BESSE 2008 NRC EXAM SIMULATOR SCENARIO 3 GENERAL DESCRIPTION The crew will assume control with power at 50% power. Following turnover the crew will perform DB-SS-04154, Turbine-Generator Backup Overspeed Trip Circuit Test Following the completion of DB-SS-04154 the Lead Evaluator will cue the loss of the running Makeup Pump. The crew will respond to annunciator 6-6-C, SEAL INJ TOTAL FLOW, in accordance with DB-OP-02006, Reactor Coolant Pump Alarm Panel 6 Annunciators, and enter and DB-OP-02512, Loss Of RCS Makeup and DB-OP-02515, Reactor Coolant Pump And Motor Abnormal Operations. The crew should close MU19, Seal Injection Flow Control Valve, and start the standby Makeup Pump. The crew should restore Pressurizer level and RCP Seal Injection flow.

Following the start of the standby Makeup Pump the Lead Evaluator will cue the inadvertent closure of MU1903, Letdown Demin Inlet. The crew will respond to annunciator 2-2-A, LETDOWN PRESS HI, in accordance with DB-OP-02002, Letdown/Makeup Alarm Panel 2 Annunciators. The crew should isolate Letdown to stop an interfacing system LOCA. An Equipment Operator will call up and identify that MU1903 had been inadvertently closed.

Letdown will be re-established in accordance with DB-OP-06006, Makeup And Purification System After Letdown flow is re-established the Lead Evaluator will cue the Steam Generator 1 Tube Leak. The crew should respond to annunciator 12-1-A, MN STM LINE 1 RAD HI, in accordance with DB-OP-02531, Steam Generator Tube Leak. The crew will evaluate the SG leakage and determine the leak rate is in excess of T.S. 3.4.6.2 and start a rapid shutdown.

During the power reduction Main Turbine bearing vibration levels will increase to the point annunciator 15-2-E T-G BEARING VIB HI will alarm. The crew will respond in accordance with DB-OP-02015, Turbine Alarm Panel Annunciators and manually trip the Main Turbine.

After the Main Turbine is tripped the Lead Evaluator will cue the increase in SG tube leakage.

This leak size will be larger than Makeup capacity. The crew will enter DB-OP-02000, RPS SFAS, SFRCS Trip, or SG Tube Rupture and trip the reactor.

After the reactor trip, the Main Feedwater Pump 2 speed will coast down leading to a loss of all Main Feedwater. SFRCS Channel 1 will not actuate either automatically or manually requiring the crew to start AFW Pump 1 and reposition SFRCS Channel 1 actuated valves.

The Lead Evaluator can terminate the scenario when all high level activities have been completed and the evaluators agree the crew can be properly evaluated.

Appendix D NUREG 1021 Revision 9

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 3 Event No.: 1 Page 1 of 1 Event

Description:

Following turnover the crew will perform the Backup Overspeed trip test for the Main Turbine in accordance with DB-SS-04154, Turbine-Generator Backup Overspeed Trip Circuit Test Time Position Applicants Actions or Behavior BOP Place HIS MP111A, Backup Overspeed Trip Test Switch, in TEST position BOP Depress and hold the Backup Overspeed Trip - Push To Test pushbutton located on the EHC Monitor Panel (C5757B)

BOP Check that the Backup Overspeed Trip - Push To Test lamp comes on BOP Release the Backup Overspeed Trip - Push To Test pushbutton BOP Check that the Backup Overspeed Trip - Push To Test lamp goes off BOP Place HIS MP111A, Backup Overspeed Trip Test Switch, in NORMAL position BOP Notify the Shift Manager this procedure is complete After the Backup Overspeed Trip Test is complete direct the Simulator Operator to insert Event Line 2 to trip Makeup Pump 1 Page 1 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 3 Event No.: 2 Page 1 of 2 Event

Description:

Makeup Pump 1 trips causing a loss of RCS Makeup and RCP Seal Injection. The Reactor Operator should isolate Letdown and start the standby Makeup Pump.

The SRO should implement DB-OP-02512, Loss of RCS Makeup and enter the applicable Tech Spec.

Time Position Applicants Actions or Behavior CREW Recognize a loss of the running Makeup Pump 6-5-C SEAL INJ FLOW LO 6-6-C SEAL INJ TOTAL FLOW Zero Makeup flow Makeup Pump red light OFF SRO Implement DB-OP-02512, Loss of RCS Makeup RO Verify Components Cooling Water supply to the RCPs RO Monitor Pressurizer level RO Isolate letdown RO Isolate Seal Injection by closing MU 19 RO Isolate normal Makeup by closing MU 32 SRO Refer to DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation Page 2 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 3 Event No.: 2 Page 1 of 2 Event

Description:

Time Position Applicants Actions or Behavior RO

• Start the standby Makeup Pump RO Restore Seal Injection flow as follows Over 2 minutes open MU 19 to a setpoint of 12-15 gpm After 10 minutes increase total Seal Injection flow to 20 to 25 gpm After another 10 minutes adjust total Seal Injection flow to the normal range Return MU 19 to AUTO RO

• Restore Makeup Flow as follows:

Slowly raise Makeup flow using MU 32 When Pressurizer level is correct return MU 32 to AUTO RO Restore Letdown SRO Refer to Tech Spec 3.1.2.4.

After the SRO refers to Tech Specs, direct the Simulator Operator to enter Event Line 3 to close MU 1903, Purification Demin 3 Letdown Flow Inlet

• Critical Step Page 3 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 3 Event No.: 3 Page 1 of 1 Event

Description:

MU 1903, Purification Demin 3 Letdown Flow Inlet is inadvertently closed from the local switch and causes a loss of Letdown Time Position Applicants Actions or Behavior CREW Recognize a loss of the Letdown flowpath:

Zero Letdown flow 2-2-A LETDOWN PRESS HI RO Refer to DB-OP-02002, Letdown/Makeup Alarm Panel 2 Annunciators RO

• Verify MU 4, Pressure Reducing Valve, is closed (Can also close MU 2B, MU2A or MU 3 to isolate Letdown)

RO Verify MU 6, Letdown Flow Control Valve, is closed RO Check for correct valve lineup in the Letdown line Recognize MU 1903 is closed RO Re-establish Letdown Re-open MU 1903 After Letdown is restored direct the Simulator Operator to insert Event Line 4 for a tube leak in SG 1

• Critical Step Page 4 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 3 Event No.: 4&5 Page 1 of 4 Event

Description:

A tube leak of 75 gpm in SG 1 will require a plant shutdown. During the power reduction vibrations will increase on the Main Turbine requiring the Main Turbine to be manually tripped Time Position Applicants Actions or Behavior CREW Recognize indications of a SG tube leak 9-4-A VAC SYS DISCH RAD HI 12-1-A MN STM LINE 1 RAD HI Increasing Makeup flow SRO Route to DB-OP-02531, Steam Generator Tube Leak RO Monitor Pressurizer level CREW Determine SG 1 has the tube leak RO Calculate a leak rate SRO Direct Chemistry to perform Attachment 2 SRO Direct Radiation Protection to perform Attachment 3 SRO Direct an Equipment Operator/Field Supervisor to perform SRO Direct a plant shutdown SRO Notify the SCC Load Dispatcher of plant shutdown Page 5 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 3 Event No.: 4&5 Page 2 of 4 Event

Description:

Continued Time Position Applicants Actions or Behavior RO Begin plant shutdown

• Set RATE OF CHANGE

• Set MIN LIMIT - MW to 180 MWE

• Depress DECREASE SRO Contact Chemistry to monitor Condensate Polishers and sample the RCS SRO As time permits:

Direct a Reactor Operator to transfer station electrical loads Direct an Equipment Operator to realign the MDFP to the MFW mode Direct an Equipment Operator to fire the Aux Boiler RO Maintain Makeup tank level SRO Refer to TS 3.4.6.2.c Event Line 5 will automatically activate to begin increasing Turbine Vibrations when Reactor power goes below 40%

CREW Recognize increasing vibrations on the Main Turbine 15-2-E T-G BEARING VIB HI High vibration on any Turbine or Generator Bearing at ZJR 2538, Main Turbine & MFP Turbines-Bearing Vibration

& Eccentricity BOP Refer to DB-OP-02015, Turbine Alarm Panel Annunciators Page 6 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 3 Event No.: 4&5 Page 3 of 4 Event

Description:

Continued Time Position Applicants Actions or Behavior BOP Verify bearing vibration location and intensity at ZJR 2538 BOP When vibration intensity is greater than 12 mils for any bearing, then trip the Main Turbine SRO Refer to DB-OP-02500, Turbine Trip BOP Check Turbine Stop Valves and Turbine Control Valves are closed BOP Check Feedwater is controlling on Low Level Limits BOP Check SG pressures controlling at 870 psig BOP Verify ACB 34560 and ABS 34561 are open BOP Verify power is not flowing on the Main Generator BOP Verify the Generator Field Breaker and the Exciter Field Breaker are open BOP Verify MS 199 and MS 314 are closed RO Check proper RCS response RCS pressure RCS temperature Pressurizer level Page 7 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 3 Event No.: 4&5 Page 4 of 4 Event

Description:

Continued Time Position Applicants Actions or Behavior BOP Start the Motor Suction Pump BOP Start the Turning Gear Oil Pump BOP Reset Lift Pump Low Suction Pressure Trip BOP Start the Turbine Lift Oil Pumps BOP Establish one Condensate Pump operation After the Main Turbine is tripped direct the Simulator Operator to insert Event Line 6 to increase the size of the SG tube leak Page 8 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 3 Event No.: 6,7,8 Page 1 of 3 Event

Description:

The tube leak in SG 1 will increase in size and require entry into DB-OP-02000 for a SG Tube Rupture. Since the plant is on Low Level Limits, the Crew should trip the Reactor. Following the Reactor trip the running MFPT speed will decrease and to the point that an SFRCS actuation should occur. SFRCS Channel 1 fails to actuate requiring the Crew to manually reposition the SFRCS actuated valves Time Position Applicants Actions or Behavior CREW Recognize increase in leak rate Makeup flow increasing Pressurizer level decreasing SRO Route back to section 4.1 of DB-OP-02531 RO Isolate letdown RO Recognize PZR level still dropping RO Trip the reactor when Pressurizer level drops to 100 inches or lower SRO Go to DB-OP-02000, RPS SFAS, SFRCS Trip, or SG Tube Rupture RO Perform DB-OP-02000 Immediate Actions

• Manually trip the reactor

• Verify power decreasing in the intermediate range

• Manually trip the turbine SRO Verify immediate actions Page 9 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 3 Event No.: 6,7,8 Page 2 of 3 Event

Description:

Continued Time Position Applicants Actions or Behavior CREW Check for Specific Rule implementation BOP Recognize AFPT 1 did not automatically start Implement Specific Rule 4 Align Auxiliary Feedwater to SG 1

- Open MS 5889A to start AFPT 1 OR

- Start the Motor Driven Feedwater Pump Enable both MDFP Discharge Valves Close both MDFP Discharge Valves Start the MDFP Feed SG 1 BOP Maintain RCS pressure constant or slightly decreasing using the Atmospheric Vent Valves CREW Check for Symptom direction Recognize SG 2 tube rupture SRO Route to Section 8 RO Implement Attachment 8, Place MU/HPI/LPI in Service Set Pressurizer Level Controller to 100 inches Lock MU Pump suctions on the BWST Start/Verify running the standby CCW Pump Start/Verify running both HPI Pumps Verify open HP 2A, HP 2B, HP 2C and HP 2D Start both LPI Pumps Open DH 64 and DH 63 Page 10 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 3 Event No.: 6,7,8 Page 3 of 3 Event

Description:

Continued Time Position Applicants Actions or Behavior RO Set Pressurizer Level Controller to 100 inches SRO Verify the following attachments from DB-OP-02531 are in progress:

• , Chemistry Responsibilities

• , Radiation Protection Responsibilities

• , Control of Secondary Contamination BOP Direct an Equipment Operator/Field Supervisor to place the Auxiliary Boiler in service RO Turn off all Pressurizer heaters RO Begin spraying the Pressurizer to lower RCS pressure RO Block SFAS low RCS pressure trips RO Control MU/HPI to maintain Pressurizer level 80 to 120 inches BOP Begin a RCS cooldown using the Atmospheric Vent Valves Termination Criteria

• HPI maintaining Pressurizer level RCS cooldown in progress using both SGs Alert based on EAL 2.A.2 for an RCS leak greater than 50 gpm Page 11 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 CRITICAL TASK JUSTIFICATION Isolate the Letdown line SSig - Loss of RCS inventory/pressure outside of Containment Cue - Letdown high pressure, Procedural direction MPI - MU 4 CLOSE pushbutton depressed OR MU 2B CLOSE pushbutton depressed OR MU 3 CLOSE pushbutton depressed OR MU 2A CLOSE pushbutton depressed OPF - MU 4 green light on OR MU 2B green light on OR MU 3 green light on OR MU 2A green light on KSA Number: 004-A4.06 (3.6/3.1) Ability to manually operate the Letdown isolation and flow control valves Start the standby Makeup Pump SSig - Prevent loss of RCS inventory control Cue - Procedural direction MPI - Makeup Pump 2 hand switch to START OPF - Makeup Pump 2 RED light lit KSA Number: 004-A4.08 (3.8/3.4) Ability to manually operate the Makeup Pumps Page 12 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 SCENARIO ATTRIBUTES Total Malfunctions 6

Malfunctions after EOP Entry 2

Abnormal Events 4

Major Transients 1

EOPs 1

EOP Contingencies 1 (Specific Rule 4)

Scenario Runtime 75 minutes EOP runtime 30 minutes Crew Critical Tasks 2

Technical Specifications Exercised 2

Page 13 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 CUE SHEET Event 1 - Turbine-Generator Backup Overspeed Trip Circuit Test Event 2 - Makeup Pump 1 trips Role Play as an Equipment Operator to report a 50/51A target, Alarm-Time and Instantaneous Overcurrent on BKR AC105 is showing Role play as the Work Week Manager/Electrical Maintenance to begin trouble shooting AC105 Event 3 - MU 1903, Purification Demin 3 Letdown Flow Inlet is inadvertently closed After MU 1903 is closed, role play as an Equipment Operator to report the local CLOSE pushbutton (NV 19030) was inadvertently depressed Event 4 & 5 - SG 1 tube leak of 75 gpm and high vibrations on the Main Turbine Role play as Chemistry to perform Attachment 2 of DB-OP-02531 Role play as Radiation Protection to perform Attachment 3 of DB-OP-02531 Role play as an Equipment Operator/Field Supervisor to perform Attachment 4 of DB-OP-02531 Role play as the System Dispatcher to acknowledge the power reduction Event 6, 7 & 8 - SGTR, Reactor Trip and Loss of Main Feedwater Page 14 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Simulator Setup Instructions

1. Verify the following:

a. Previous data on Yokogawa recorders is cleared

b. Chart recorders are rolled forward

c. Applicable procedures are wiped cleaned

d. Used Alarm Typer paper is removed

e. Computer alarms are cleared/acknowledged

2. Initialize at 50% power

a. Verify MFPT 2 running

b. Verify MFPT 1 on the Turning Gear

3. Equipment Status:

a. Hang License Requirement Sheet on the status board EDG 1: TS 3.8.1.1.b, fuel oil and lube oil filter replacement, DB-SC-03023 due (current time + 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />) DB-SC-03071 due (current time + 22 hours2.546296e-4 days <br />0.00611 hours <br />3.637566e-5 weeks <br />8.371e-6 months <br />). Restore by (current time + 7 days)

b. Tag out AC 101, EDG 1 output breaker

c. Turn on the EDG blue status

d. Hang Protected Train 2 signs

e. Select SP16B for Turbine Throttle Pressure input

f. Reset SASS annunciators as required

4. Set Up Batch File

a. Initial Setup

- Remove EDG 1 from service.

Close DA44 IRF GD44 close Close DA 30 IRF GD43 close Page 15 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Rack out AC 101 IRF G535A 3.0

- Fail SFRCS Channe1 automatic and manual actuation IMF F30AB IMF F30AC

- Fail SP16A low to put SP16B in service IMF L1T2N 0.0

b. Triggers

- Reactor power < 40% activates the turbine vibrations TRGSET 5 RATPW<40.0

- Reactor power < 10% activates the MFPT 2 loss of speed TRGSET 6 RATPW<10.0

- MU 4 green light on TRGSET 9 "B20MU04g==1"

c. Events Event 1 - Main Turbine Backup Overspeed Trip test Event 2 - Fail Makeup Pump 1 breaker open IMF B2M1N (2) TRUE Event 3 - MU1903 Demin 3 Inlet closes IRF BV24B (3) CLOSE Event 4 - SG 1 tube leak IMF HH50 (4) 0.015 00:01:00 Page 16 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Event 5 - Main Turbine high vibrations IMF UF09A (5) 1.0 60 0.1 IMF UF08A (5) 1.0 90 0.1 IMF UF11A (5) 1.0 120 0.1 IMF UF06A (5) 1.0 150 0.1 Event 6 - MFPT 2 speed lowers IMF SFDPC (6) TRUE Event 7 - Increase size of SG 1 tube leak Use CAEP File Line 2 Event 8 - SFRCS Ch 1 fails to actuate automatically or manually Event 9 - Bleed Letdown system pressure IRF BM77 (9) 0.0 IRF BMS1B (9) 1

d. CAEP File

- Clear failure on MU 1903 IRF BM77 1.0 l04:00:00l2 IRF BMS1B 0.0 l04:00:00l3

- Raise SG 1 leak rate to 0.09 after reactor trip CAEP Line 2 -MMF HH50 0.09l04:00:00l2 Page 17 of 17

Appendix D Scenario Outline Form ES-D-1 Facility:

Davis-Besse Scenario No.:

4 Op Test No.:

Examiners:

Operators:

Initial Conditions:

100% power, MOL Containment Spray Pump 1 out of service HIS SP 16, Turbine Throttle Pressure, selected to PT SP16B (NNI-Y)

Turnover: The crew will assume the watch with the plant at 100% power and Containment Spray Pump 1 out of service for maintenance. The Plant Risk level will be GREEN. Following turnover the Crew will take action to exercise the automatic Main Generator Voltage Regulator in accordance with DB-OP-06301, Generator and Exciter Operating Procedure Event No.

Malf.

No.

Event Type*

Event Description 1

N - BOP Main Generator Voltage Regulator exercise 2

L6P2D I-RO TS-SRO SFAS Containment Pressure transmitter fails low 3

H1C1C I -RO Pressurizer Temperature fails mid-scale 4

KHP309 C - BOP Turbine Plant Cooling Water Pump 3 trips 5

HN29A R -RO TS - SRO RCP 2-1 Seal Cooler leak 6

SFEF M -All Steam Leak in Fan Alley 7

FKGFC C - BOP AF 3872, AFW level control valve, fails open (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D NUREG 1021 Revision 9

Appendix D Scenario Outline Form ES-D-1 DAVIS-BESSE 2008 NRC EXAM SIMULATOR SCENARIO 4 GENERAL DESCRIPTION The crew will take the watch with power holding at 100% power.

The Lead Evaluator will cue the exercise of the Main Generator Voltage Regulator.

After completing the Voltage Regulator exercise, the Lead Evaluator will cue the Containment Pressure transmitter failure. The Crew should respond to alarm 5-4-B, SFAS CTMT PRESS LO CH TRIP, in accordance with DB-OP-02005, Primary Instrumentation Alarm Panel 5 Annunciators. The SRO should enter the correct Tech Spec. The Crew will trip the appropriate SFAS bistables using DB-OP-06405, SFAS Procedure to comply with Tech Specs.

The Lead Evaluator will cue the Pressurizer Temperature mid-scale failure The Crew should respond to annunciator 4-2-E, PZR LVL LO, in accordance with DB-OP-02004, Reactor Coolant Alarm Panel 4 Annunciators, and then enter DB-OP-02513, Pressurizer System Abnormal Operation. The Crew should select the alternate temperature instrument and return to normal operations.

The Lead Evaluator will cue tripping of TPCW Pump 3. The Crew should respond to annunciator 11-1-F, TPCW HI LVL TK LVL, in accordance with DB-OP-02011, Heat Sink Alarm Panel 11 Annunciators, and then enter DB-OP-02514, Loss Of Turbine Plant Cooling Water Pump. The Crew will start TPCW Pump 2.

The Lead Evaluator will cue RCP 2-1 seal cooler leak. The Crew should respond to the leak using DB-OP-DB-OP-02523, Component Cooling Water System Malfunctions and respond to increasing Seal Return temperatures using DB-OP-02515, Reactor Coolant Pump And Motor Abnormal Operation. The crew should begin a power reduction to 72% and stop RCP 2-1 in accordance with DB-OP-02504, Rapid Shutdown.

The Leak Evaluator will cue the steam leak. The crew should respond to annunciator 12-2-B, SG 1 TO AFPT 2 MN STM PRESS LO, in accordance with DB-OP-02525, Steam Leaks.

Following an attempt to isolate the steam leak the crew will trip the reactor and depressurize the Steam Generator.

AF 3872, AFW to SG 2, will fail in the open position. This will cause AFW to overfeed SG 1.

The crew should respond by manually controlling AFW to SG 1 in accordance with DB-OP-02000, RPS, SFAS, SFRCS, or SG Tube Rupture The Lead Evaluator can terminate the scenario when all high level activities have been completed and the evaluators agree the crew can be properly evaluated.

Appendix D NUREG 1021 Revision 9

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 4 Event No.: 1 Page 1 of 1 Event

Description:

Following turnover the Crew will exercise the automatic Main Generator Voltage Regulator in accordance with DB-OP-06301, Generator and Exciter Operating Procedure Time Position Applicants Actions or Behavior SRO Notify the Load Dispatcher that the automatic Main Generator Voltage Regulator will be exercised BOP Transfer the Voltage Regulator from AUTOMATIC to MANUAL Adjust GEN FIELD XFER VOLTS to zero using HIS6012, MANUAL Transfer HIS6011, VOLTAGE REG TRANSFER, from AUTOMATIC to MANUAL Cycle HIS6014, AUTOMATIC (C5722) between upper and lower indicating light limits BOP Transfer the Generator Voltage Regulator from MANUAL to AUTOMATIC Adjust GEN FIELD XFER VOLTS to zero using HIS6014, AUTOMATIC Transfer HIS6011, VOLTAGE REG TRANSFER, from MANUAL to AUTOMATIC NOTE: The Lead Examiner can determine whether or not to perform the Manual Voltage Regulator exercise at this point or to go to the second event BOP Cycle HIS6012, MANUAL (C5722) between upper and lower indicating light limits and return GEN FIELD XFER VOLTS to 0 volts After the Main Generator Voltage Regulator exercise is complete, direct the Simulator Operator to insert Event Line 2 to fail SFAS Channel 2 Containment Pressure Transmitter low Page 1 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 4 Event No.: 2 Page 1 of 2 Event

Description:

Upon completion of the Voltage Regulator exercise, SFAS Channel 2 Containment Pressure Transmitter will fail low requiring the Containment Pressure Trip Bistables in SFAS Channel 2 to be manually tripped Time Position Applicants Actions or Behavior CREW Recognize SFAS Channel 2 Containment Pressure Transmitter has failed low 5-4-B, SFAS CTMT PRESS LO FAIL Bistable BA208 tripped in SFAS Channel 2 PI 2001 indicating 0 psia RO Implement DB-OP-02005, Primary Instrumentation Alarm Panel 5 Annunciators SRO Recognize SFAS Channel 2 is inoperable by comparing channels in accordance with DB-OP-03006, Miscellaneous Instrument Shift Check SRO Refer to Tech Spec 3.3.2.1 and recognize the need to trip the Containment Pressure Trip Bistables in SFAS Channel 2 RO Refer to section 4.1 of DB-OP-06405, SFAS Procedure for actions for an inoperable instrument string RO Trip the following bistables in SFAS Channel 2 by pushing the TEST pushbutton and verifying the TRIP light is ON:

BA210, CONTAINMENT HI PRESSURE Bistable BA211, CONTAINMENT HI HI PRESSURE Bistable RO Verify the associated 1/5 lights on the output modules for all four SFAS Channels are ON Page 2 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 4 Event No.: 2 Page 2 of 2 Event

Description:

Continued Time Position Applicants Actions or Behavior After the SFAS bistables are tripped, direct the Simulator Operator to insert Event Line 3 to fail TE RC15-1, the selected Pressurizer Temperature Instrument, to a midscale position Page 3 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 4 Event No.: 3 Page 1 of 1 Event

Description:

TE RC15-1, Pressurizer Temperature Instrument, fails to a midscale position causing the temperature compensated Pressurizer Level to indicate low. The Crew will be required to manually control Pressurizer level while selecting a good temperature instrument.

Time Position Applicants Actions or Behavior CREW Recognize a Pressurizer Temperature transmitter failure Annunciator 4-3-E, PZR LVL HI Temperature instrumentation indicates a low temperature SRO Implement DB-OP-02513, Pressurizer System Abnormal Operations RO Place MU 32 in HAND and control Pressurizer level RO Compare Pressurizer temperature instruments RO Select an TE RC15-2 as an alternate Pressurizer temperature instrument SRO If Pressurizer level is greater than 228 inches then refer to Tech Spec 3.3.4 RO Return MU 32 to automatic control After MU 32 is returned to automatic control, direct the Simulator Operator to insert Event Line 4 to trip Turbine Plant Cooling Water Pump 3 Page 4 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 4 Event No.: 4 Page 1 of 1 Event

Description:

Turbine Plant Cooling Water Pump 3 trips requiring the standby TPCW Pump to be started Time Position Applicants Actions or Behavior CREW Recognize a failure of TPCW Pump 3

• 11-1-F, TPCW HI LVL TK LVL

• 11-2-F, TPCW LO LVL TK LVL

• TPCW High Level Tank dropping

• TPCW Low Level Tank rising SRO Implement DB-OP-02514, Loss of TPCW Pumps BOP Monitor the High Level Cooling Water Tank level BOP Start TPCW Pump 1 After the standby TPCW pump is started, direct the Simulator Operator to insert Event Line 5 for a seal cooler leak on RCP Page 5 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 4 Event No.: 5 Page 1 of 4 Event

Description:

A leak develops in the seal water cooler on RCP 2-1. Isolation of the leak will cause a loss of CCW to the seal water cooler requiring a power reduction in order to stop the RCP.

Time Position Applicants Actions or Behavior CREW Recognize a leak into the CCW system 6-5-C SEAL INJ FLOW LO 6-5-A MONITOR SYSTEM TRBL CCW Surge Tank level increasing 11-4-A, CCW SURGE TK LVL HI RCP 2-1 high Seal Injection flow Low Seal Injection flow to the remaining 3 RCPs RCP 2-1 high Seal Return temperature 11-1-A CCW RETURN RAD HI SRO For the low Seal Injection flow and Monitor System Trouble, implement DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation RO Verify CCW is available to the RCPs RO Monitor Seal Return temperature SRO For the high CCW Surge Tank level, implement DB-OP-02523, CCW System Malfunctions SRO Direct an Equipment Operator to attempt to reduce surge tank level by draining to the MWDT BOP Verify all sources of makeup to the CCW System are isolated Verify DW 2643, CCW Surge Tank Demin Water Makeup is closed Direct an Equipment Operator to verify DW 3, DW 6, SW 234, SW 233, SW 236 and SW 232 are closed Page 6 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 4 Event No.: 5 Page 2 of 4 Event

Description:

Continued Time Position Applicants Actions or Behavior CREW Determine the source of the leakage into the CCW System SRO Direct Chemistry to sample the CCW System CREW For the rise in CCW activity and leakage into the CCW system implement DB-OP-02523, CCW System Malfunctions RO Verify Computer Point P101 is not in alarm and Letdown Cooler is not leaking CREW Determine the leak is in the RCP 2-1 Seal Cooler High Seal Injection flow to 2-1 RCP, Low Seal Injection flow to the other RCPs RCP 2-1 seal temperature alarms RO Lower Seal Injection flow with MU 19 RO

• Close CC 4300, Seal Cooling CCW Return from RCP 2-1 RO Begin restoring Seal Injection flow using MU 19 CREW Recognize RCP 2-1 Seal Return temperature is greater than 200°F SRO Implement DB-OP-02515, RCP and Motor Abnormal Operation

• Critical Task Page 7 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 4 Event No.: 5 Page 3 of 4 Event

Description:

Continued Time Position Applicants Actions or Behavior SRO Refer to DB-OP-02504, Rapid Shutdown SRO Notify the Load Dispatcher RO Perform Rapid Shutdown actions Set Rate of Change Set MIN LIMIT Lower power Maintain Imbalance using APSRs BOP Perform Rapid Shutdown actions Notify Chemistry to monitor polishers and sample the RCS At 90%, direct an Equipment Operator to remove the AFPT Main Steam Minimum flow lines from service When condensate flow is <7.0 MPPH then stop one Condensate pump RO When power has decreased to 72% stop the affected RCP Run oil lift pump as necessary BOP Verify proper feedwater re-ratio RO Verify Tave control on the RC Loop with 2 RCPs SRO Refer to Tech Spec 3.4.1.1 for //Flow trips and High Flux trips RO Close MU 59A, Seal Return Isolation Valve for RCP 2-1 Page 8 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 4 Event No.: 5 Page 4 of 4 Event

Description:

Continued Time Position Applicants Actions or Behavior After the RCP is stopped, direct the Simulator Operator to insert Event Line 6 to start the unisolable steam leak Page 9 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 4 Event No.: 6 Page 1 of 3 Event

Description:

An unisolable steam leak develops on the SG 2 to AFPT 1 steam line requiring the Reactor to be manually tripped and SFRCS to be manually actuated. SG 2 will be required to be blown dry by opening the Atmospheric Vent Valve. AF 3872 fails to automatically close on the SG 2 low pressure trip causing an overfeed of AFW to SG 1.

Time Position Applicants Actions or Behavior CREW Recognize a steam leak on the steam line from SG 2 to AFPT 1 12-2-B SG 2 TO AFPT 1 MN STM PRESS LO Fire alarms in Fan Alley Time 12-2-B alarms SRO Implement DB-OP-02525, Steam Leaks CREW Determine if a personnel safety issue exists CREW Determine the location of the steam leak BPO Perform Attachment 2 of DB-OP-02525 for a Main Steam Line 2 to AFPT 1 steam leak Close MS 106A Verify closed MS 106 Verify closed MS 107 CREW Recognize the steam leak still exists RO Trip the Reactor RO Perform DB-OP-02000 Immediate Actions

• Manually trip the reactor

• Verify power decreasing in the intermediate range

• Manually trip the turbine Page 10 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 4 Event No.: 6 Page 2 of 3 Event

Description:

Continued Time Position Applicants Actions or Behavior RO Manually initiate AFW flow and isolation of both SGs BOP

• Isolate and blowdown Steam Generator Energize control power to AF 599 Close AF 599 Place the SG 2 Atmospheric Vent Valve HAND/AUTO Station in HAND Reduce demand to zero Depress the Atmospheric Vent Valve BLOCK pushbutton Depress the Atmospheric Vent Valve AUTO pushbutton Fully open the Atmospheric Vent Valve using the AVV H\\A Station Reopen the Atmospheric Vent Valve if SFRCS actuates on low pressure in SG 2 Time the Atmospheric Vent Valve is opened SRO Route to DB-OP-02000, Section 3 SRO Verify immediate actions CREW Check for Specific Rule implementation CREW Check for Symptom direction Recognize Overcooling due to SG 2 less than 960 psig SRO Route to DB-OP-02000, Section 7

• Critical Task Page 11 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Op-Test No.:

Scenario No.: 4 Event No.: 6 Page 3 of 3 Event

Description:

Continued Time Position Applicants Actions or Behavior RO Implement Attachment 8, Place MU/HPI/LPI in Service Set Pressurizer Level Controller to 100 inches Lock MU Pump suctions on the BWST Start/Verify running the second MU Pump Start/Verify running the standby CCW Pump Start/Verify running both HPI Pumps Verify open HP 2A, HP 2B, HP 2C and HP 2D Start both LPI Pumps Open DH 64 and DH 63 BPO Verify proper SFRCS actuation for SG 2 low pressure Recognize AF 3872 did not close BPO

• Take manual control of AF 6451 OR AFPT 2 speed to control AFW flow from AFPT 2 to SG 1 BPO Control Atmospheric Vent Valve 1 to maintain RCS temperature constant or slowly decreasing RO Begin lowering RCS pressure using Pressurizer Spray RO Control MU/HPI flow to control Pressurizer level RO Block SFAS low pressure trips Termination criteria

• SG 2 isolated and blown dry

• RCS temperature constant or slowly decreasing

• RCS inventory maintained with MU and HPI Unusual Event based on EAL 5.A.1 due to valid SFRCS actuation on low SG pressure

• Critical Task Page 12 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 CRITICAL TASK JUSTIFICATION Close CC 4300 to isolate the leak into the CCW System SSig - Loss of RCS inventory outside of Containment Cue - CCW Surge Tank level increasing, CCW activity increasing MPI - CC 4300 CLOSE pushbutton depressed OPF - CC 4300 green light on KSA Number: 009-EA1.05 (3.4/3.4) Ability to operate and monitor the CCW System Blowdown SG 2 due to an unisolable steam leak SSig - Prevent steam and water damage to safety related equipment in Fan Alley Cue - Procedural direction MPI - Isolates AFW to the faulted SG and open the Atmospheric Vent Valve for the faulted SG OPF - Faulted SG pressure and level decreasing KSA Number - 035-A4.06 (4.5/4.6) Ability to isolate a SG on a steam leak Manually control AFW flow to feed the non-faulted SG SSig - Prevent a loss of the good SG by overfeeding from Auxiliary Feedwater in order to maintain core cooling via the SG Cue - Procedural direction MPI - Target rock controllers in MANUAL and throttled closed OR AFPT speed reduced OPF - Level in the good SG controlled at the applicable setpoint KSA Number: 061-A2.05 (3.1/3.4) Ability to predict the impact of an automatic control malfunction for AFW Page 13 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 SCENARIO ATTRIBUTES Total Malfunctions 6

Malfunctions after EOP Entry 1

Abnormal Events 3

Major Transients 1

EOPs 1

EOP Contingencies 2 (SG blowdown, Specific Rule 4)

Scenario Runtime 75 minutes EOP runtime 30 minutes Crew Critical Tasks 3

Technical Specifications Exercised 2

Page 14 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 CUE SHEET Event 1 - Manual Voltage Regulator operations Event 2 - SFAS Containment Pressure transmitter fails low Role play as Work Week Manager/I&C for investigating the transmitter failure Event 3 - Pressurizer Temperature fails mid-scale Role play as Work Week Manager/I&C for investigating the transmitter failure Event 4 - Turbine Plant Cooling Water Pump 3 trips Role Play as an Equipment Operator to report a 50/51A target, Alarm-Time and Instantaneous Overcurrent on Breaker AC208 is showing Role play as the Work Week Manager/Electrical Maintenance to begin trouble shooting AC208 Role Play as an Equipment Operator to report TPCW Pump 1 oil levels are normal Event 5 - RCP 2-1 Seal Cooler leak Role play as an Equipment Operator to WM 29 and WM 30 to drain the CCW Surge Tank Role play as an Equipment Operator to verify closed DW 3, DW 6, SW 234, SW 233, SW 236 and SW 232 Role play as Chemistry to sample the CCW System for activity Role play as the System Dispatcher to acknowledge the power reduction Role play as Chemistry to support the power reduction Role play as I&C for verifying //flow trips and resetting High Flux trips Event 6 - Steam Leak in Fan Alley Event 7 - AF 3872, AFW Level Control Valve, fails open Page 15 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2 Simulator Setup Instructions

1. Verify the following:

a. Previous data on Yokogawa recorders is cleared

b. Chart recorders are rolled forward

c. Applicable procedures are wiped cleaned

d. Used Alarm Typer paper is removed

e. Computer alarms are cleared/acknowledged

2. Initialize at 100% power

3. Equipment Status:

a. Hang License Requirement Sheet on the status board

b. Tag out Containment Spray Pump 1

c. Turn on the CTMT SPRAY blue status

d. Hang Protected Train 2 signs

e. Select SP16B for Turbine Throttle Pressure input

f. Reset SASS annunciators as required

4. Set Up Batch File

a. Initial Setup

- CTMT Spray Pump 1 out of service IRF BDP3A FALSE

- Fail open AF3872 IMF FKGFC TRUE

- Open CW 82, Gen Hydrogen Cooler Bypass valve for TPCW flow > 1 TPCW pump IRF KD73 0.5

- Fail SP16A low to put SP16B in service IMF L1T2N 0.0 Page 16 of 17

Appendix D, Rev. 9 Required Operator Actions Form ES-D-2

b. Triggers

- Close Generator H2 Cooler Bypass valve when TPCW Pump 1 is started TRGSET 7 "k30p71rd==1"

c. Events Event 1 - Manual Voltage Regulator exercise Event 2 - SFAS 2 CTMT Pressure transmitter fails low IMF L6P2D (2) TRUE Event 3 - Pressurizer Temperature fails mid-scale IMF H1C1C (3) 0.5 00:00:05 0.923 Event 4 - Turbine Plant Cooling Water Pump 3 trips IMF KHP309 (4) TRUE Event 5 - RCP 2-1 Seal Cooler leak IMF HN29A (5) 0.05 00:01:00 Event 6 - Steam leak in fan alley IMF SFEF (6) 0.05 Fan Alley Fire Alarms IMF KN618 (6 00:00:20)

IMF KN619 (6 00:00:25)

IMF KN620 (6 00:00:30)

IMF KN621 (6 00:00:35)

Event 7 - Close Generator H2 Cooler Bypass valve IRF KD73 (7) 0.0 Page 17 of 17