ML092180134

2008 Byron Station Initial License Examination Proposed Simulator Scenarios

ML092180134
Person / Time
Site:	Byron
Issue date:	05/19/2008
From:	Division of Nuclear Materials Safety III
To:	Exelon Generation Co, Exelon Nuclear
References
Download: ML092180134 (73)

Text

Appendix D Scenario Outline Form ES-D-1 Facility: Byron Scenario No: #1 Op-Test No: 2008-01 Examiners: Operators:

Initial Conditions: Rx Power ~ 100%.

Turnover: Drain PRT per BOP RY-4 and then ramp down to 95% Rx Power.

Event Malf. Event Event No. No. Type* Description RO 1 NONE N Drain PRT per RY-4, Draining the PRT SRO RO 2 NONE R Ramp from 100% down to 95%

SRO BOP 3 ED11A C Loss of Instrument Bus 111 SRO RO 4 Cv01a C Trip of 1A CV Pump SRO BOP 5 RX01E0 I Failure of 1PT-525 low 1B S/G pressure transmitter SRO RO Failure of Pzr Master Pressure Controller 1PK-455A 6 Rx15 2500 I SRO high 7 MS07A 3 120 M TEAM 1A Main Steam Line Break inside Cnmt.

8 TC03 M TEAM Failure of Turbine to Auto Trip MS01A&D 9 M TEAM MSIVs A & D fail to close 100 10 SI01B C BOP Failure of 1B SI Pump to start

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

SCENARIO NUMBER: #1___

TITLE: Respond to a Loss of Instrument Bus followed by a Main Steam Line Fault TURNOVER INFORMATION:

The unit is at full power, steady state, equilibrium xenon, MOL.

THIS SCENARIO CONTAINS: The following objectives/K/A's:

Drain PRT per BOP RY-4 Ramp Down from 100% to 95%

Response to Instrument Bus 111 Failure 004000A4.08 (3.8/3.4) IV.D.OA-06/VIII.D.OA-056-C Respond to 1A CV Pump Trip Respond to a Failed S/G Press Channel Fails Low Respond to Master Pzr Press Controller Failing high 000040AA2.04 (4.5/4.7) IV.D.EP-06/VIII.D.EP-001-E Respond to A Main Steam Line Break inside Cnmt

/012-B/

VIII.D.EP-007-B Respond to Failure of Turbine to Trip Respond to Failure of A & D MSIV to close COMPLETION CRITERIA: Terminate SI injection flow CRITICAL TASKS:

1. Manually Trip Turbine during immediate action steps of 1BEP-0.

2. Manually aligning the A Train of ESF equipment prior to transitioning out of 1BEP-0.

3. Terminate SI to prevent Pzr overfill and eliminate PTS concern.

Examinees: US RO BOP Evaluator: Date:

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10 CFR 55.45 X 1. Perform pre-startup procedures for the facility, including operation those controls associated with plant equipment that could affect reactivity.

X 2. Manipulate the console controls as required to operate the facility between shutdown and designated power levels.

X 3. Identify annunciators and condition-indicating signals and perform appropriate remedial action where appropriate.

X 4. Identify the instrumentation systems and the significance of facility instrument readings.

X 5. Observe and safely control the operating behavior characteristics of the facility.

X 6. Perform control manipulations required to obtain desired operating results during normal, abnormal, and emergency situations.

X 7. Safely operate the facility's heat removal systems, including primary coolant, emergency coolant, and decay heat removal systems and identify the relation of the proper operation of these systems to the operation of the facility.

X 8. Safely operate the facility's auxiliary and emergency systems, including operation of those controls associated with plant equipment that could affect reactivity or the release of radioactive materials to the environment.

X 9. Demonstrate or describe the use and function of the facility's radiation monitoring systems, including fixed radiation monitors and alarms, portable survey instruments, and personnel monitoring equipment.

10. Demonstrate knowledge of significant radiation hazards, including permissible levels in excess of those authorized, and ability to perform other procedures to reduce excessive levels of radiation and to guard against personnel exposure.

X 11. Demonstrate knowledge of the emergency plan for the facility, including, as appropriate, the operator's or senior operator's responsibility to decide whether the plan should be executed and the duties under the plan assigned.

X 12. Demonstrate the knowledge and ability as appropriate to the assigned position to assume the responsibility associated with the safe operation of the facility.

X 13. Demonstrate the applicant's ability to function within the control room team as appropriate to the assigned position, in such a way that the facility licensee's procedures are adhered to and that the limitations in its license and amendments are not violated.

Simulator Scenario Review Checklist

1. The scenario has clearly stated Yes 8. Operators have sufficient time to Yes objectives in the scenario summary. carry out expected activities without

2. The initial conditions are realistic, in Yes undue time constraints. Cues are given.

that some equipment and/or If time compression techniques are used, instrumentation may be out of service, but it scenario summary clearly indicates.

does not cue crew into expected events. 9. The simulator modeling is not altered. Yes

3. The scenario consists mostly of Yes 10. All crew competencies can be Yes related events. evaluated.

4. Each event description consists of: Yes 11. The scenario has been validated. Yes

• the point in the scenario when it 12. The sampling plan indicates that Yes is to be initiated the scenario was not used for training

• the malfunction(s) that are entered during the requal cycle. Evaluate the need to initiate the event to modify/replace scenario if used.

• the symptoms/cues that will be visible 13. Total malfunctions inserted: 4-8 8 to the crew 14. Malfunctions that occur after

• the expected operator actions EOP entry: 1-4 3 (by shift position) 15. Abnormal Events: 1-2 2

• the event termination point 16. Major Transients: 1-2 1

5. No more than one non-mechanistic Yes 17. EOPs used beyond primary failure (e.g., pipe break) is incorporated scram response EOP: 1-3 4 into the scenario without a credible preceding 18. EOP Contingency Procedures incident such as a seismic event. used: 0-3 1

6. The events are valid with regard to Yes 19. Approximate scenario run time: No physics and thermodynamics. 45-60 minutes

7. Sequencing/timing of events is Yes 20. EOP run time: Yes reasonable, and allows for the 40-70% of scenario run time examination team to obtain complete 21. Crew Critical Tasks: 2-5 3 evaluation results commensurate 22. Technical Specifications are Yes with the scenario objectives. exercised during the test.

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SCENARIO OVERVIEW The unit is at full power, steady state, equilibrium xenon, MOL.

The scenario begins with the operating crew draining the PRT per BOP RY-4 this action will account for the normal evolution. The reactivity requirement will be fulfilled with a unit ramp from 100% Rx power down to 95% Rx power in preparation for a Main Feedwater Pump swap.

Once the power change has been completed Instrument Bus 111 will de-energize and BOA ELEC-2, Loss of an Instrument Bus will be entered. The instr. bus is damaged will remain de-energized. Depending on the cause of the failure enter the applicable Tech Spec 3.8.7 & 3.8.9.

After the actions of BOA ELEC-2 are complete, the 1A CV pump trips. The crew should start the 1B CV pump per BAR 1-9-A3 and take actions to stabilize the plant. Technical Specification 3.5.2 and TRM 3.1.d apply.

S/G Pressure Channel 1PT-525 fails low. The crew enters BOA INST-2, the BOP needs to take manual control of the 1B Feed Reg Valve and manual control of the Feedwater P controller to restore adequate feedwater flow to all S/Gs. The applicable Tech Spec for this failure is 3.3.2. Crew will not be required to trip bi-stables since bi-stable switches are not modeled.

Master Pressurizer Pressure Controller 1PK-455A output fails high. PORV 1RY455A does not open due to the previous Instrument Bus failure. However, Pressurizer Spray valves fully open and Pzr pressure begins to drop. The RO takes manual control of the Master Pressurizer Pressure controller and restores Pzr Pressure.

The applicable Tech Specs are 3.3.1, 3.3.2, & 3.3.4.

The 1A Main Steam Line experiences a large break. Containment temperature and pressure increase and Main Steam Line Pressure decreases to the SI setpoint. 1BEP-0, Response to Reactor Trip of Safety Injection is entered. The Reactor automatically trips on the SI signal but the Turbine fails to trip automatically following the Reactor trip. A Manual Turbine trip is required to be actuated. Due to the Instrument Bus failure all A train ESF loads fail to start on the SI signal. A Train ESF loads must be manually started.

The A & D MSIVs fail to automatically or manually close causing both S/Gs to blow down. Upon completion of 1BEP-0 the crew transitions to 1BEP-2, Faulted S/G to isolate the faulted S/Gs then transitions to 1BEP-1 Loss of Reactor or Secondary Coolant, and then to 1BEP ES-1.1, SI Termination, completion criteria is stopping the RH pumps in 1BEP ES-1.1.

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SCENARIO SETUP GUIDE

- Initialize IC-22: "full power, steady state, equilibrium xenon, MOL."

- Lineup control boards.

- Place simulator in run (allow simulator to run during board walkdowns and turnover).

- Type bat a:/BY-46 and ensure the following insert:

- Perform TQ-BY-201-0113, Appendix A, Simulator Exam/ Scenario Reset Checklist EVENT TIME MALF NO. DESCRIPTION 1 0 N/A Drain PRT per BOP RY-4 2 4 N/A Ramp Unit from 100% to 95%

3 25  ???? Trip Instrument Bus 111 4  ??  ???? Trip of 1A CV Pump (SDG CV5) 5  ??  ???? Failure of 1PT-525 low 1B S/G pressure transmitter 6  ??  ???? Failure of PZR Master Press controller 1PK-455A High 7  ??  ???? 1A Main Steam Line Break inside Cnmt.

8  ??  ???? Failure of Turbine to Auto Trip 9  ??  ???? MSIVs A & D fail to close Note 1: Events 7, 8 & 9 should be tied to Main Steam Line Break.

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INSTRUCTOR/SIMULATOR RUN AID GUIDE EVENT ADDITIONAL INFORMATION 3 Report Bus 111 Inverter AC Output Bkr 4CB Open. Report Bus 111 Main Feed Bkr Open. Report Bus 111 is damaged, small fire has been put out. Enters INST-1, NI malfunction, need to trip bistables associated with N41. Operator needs to be dispatched to open 1AF005A-D. Allow ten minutes to accomplish this task.

Remote functions per event:

RP20 Open/Close Protection Cabinet Door #1 (SDG RX10)

RX013 TRIP OTT Rx Trip TB411C C1-124 BS-3 (SDG RX4)

RX135 TRIP OTT Runback TB411D C1-124 BS-4 (SDG RX4) 4 Acknowledge 1A CV pump trip/EP review request when contacted as SM (as required).

When requested to investigate, report a Phase A overcurrent flag at the 1A CV pump breaker. Report results 4 minutes after request.

EVENT 1 by-46\rev3 5

BRIEF DESCRIPTION Drain PRT per BOP RY-4 EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Perform the action to lower PRT level per BOP RY-4 (Cue) o Per the initial scenario cue.

o Annunciator A7 PRT LVL Hi-Low (Response)

• Refer to BOP RY-4 Draining the Pressurizer Relief Tank U-1

• CLOSE 1RY469 PRT to GW isol vlv U-1

• VERIFY approximately 3 psig on 1PI469 U-1

• VERIFY/OPEN 1AOV-RY8033 N2 Supply to PRT isol vlv U-1

• VERIFY/OPEN 1AOV-RE9170, RCDT Discharge header vlv U-1

• VERIFY/OPEN 1AOV-RE1003, RCDT Discharge header vlv U-1

• OPEN 1AOV-RY8031, PRT Drain vlv U-1

• VERIFY/START 1RE01PA/B, RCDT Pump 1A/B U-1

• CYCLE 1RY8031, PRT Drain vlv to control PRT pressure U-1

• CLOSE 1AOV-RY8031, PRT Drain vlv at desired PRT level U-1

• VERIFY/STOP 1RE01PA/B, RCDT Pump 1A/B U-1

• VERIFY/CLOSE 1AOV-RE1003, RCDT Discharge header vlv U-1 EXAMINERS NOTE:

COMMENTS by-46\rev3 6

EVENT 2 BRIEF DESCRIPTION Ramp Unit from 100% to 95%

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Re-activity manipulation for this scenario.

(Cue) o Per the initial scenario cue.

(Response)

• Refer to BGP 100-4, Power Descension CREW

• Direct actions to lower Rx Pwr US

• PROGRAM Turbine Controls to ramp down U-1 AST

• BORATE per BOP CV-6 to control Tave-Tref U-1 within desired limits

• ENERGIZE Second Pressurizer B/U Htr group. U-1

• INSERT Control Rods to maintain I and Tave-Tref U-1

• STOP ramp at 95% Rx Pwr US EXAMINERS NOTE:

COMMENTS by-46\rev3 7

EVENT 3 BRIEF DESCRIPTION Loss of Instrument Bus 111 EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Recognize symptoms and respond to a de-energized Instrument Bus 111 (Cue)

• Loss of Control and Instrument Power to:

• N31 Source Range Instrument

• N35 Intermediate Range Instrument

• N41 Power Range Instrument

• Annunciator (1-4-A5) "BUS 111 INVERTER TROUBLE"

• Annunciator (1-4-A3) "PROCESS I & C CAB PWR SUP FAILURE"

• Annunciator (1-4-B3) "SOLID STATE PROT CAB GENERAL WARNING"

• Annunciator (1-4-C2) "SEQUENCING CAB PWR FAILURE"

• Annunciator (1-13-A2) "RCP BUS UNDERVOLTAGE RX TRIP ALERT" and associated trip status light (Response)

• Instrument control channels checked for operability: CREW

• PZR pressure/level

• TAVE/Delta T

• PIMP

• SG level, steam flow & feed flow Do NOT attempt to energize Instrument Bus 111 CREW from CVT (bus is damaged)

• Dispatch operator to locally fail open 1AF005A-D U-1 AST

• Brief crew on effects of loss of inst. bus 111/Train A ESF US equipment manual start requirements per Table A

• Inform SM of unit status/loss of inst. bus 111/EP STA/US potential/shutdown required by Tech Specs

• Dispatch operator to investigate status of bus US

• Evaluate potential EP/ OLR SM EXAMINERS NOTE:

Implement 1BOA INST-1 "NUCLEAR INSTRUMENT US MALFUNCTION" to establish the following conditions:

• Control rods placed in manual U-1

• Plant conditions stabilized CREW

• Rod stop bypassed

• Tave restored to Tref (+ 1 degree)

• SG levels stable by-46\rev3 8

• Bypass associated functions for PR N-41 U-1 AST

• Upper current comparator

• Lower current comparator

• Power mismatch

• Rod stop

• Channel current comparator

• Trip bistables for PR N-41

• Pull control power fuses to trip: U-1 AST

• Lo Rx trip

• Hi Rx trip

• Positive Rate trip

• Dispatch operator to locally trip: CREW

• OTT Trip

• OTT Runback

• Select/verify operable channel to loop T recorder U-1

• Remove Point from Scan Input to PDMS U-1

• Restore automatic rod control U-1

• Inform SM of unit status/potential EP event US/STA

• Review Tech Spec 3.8.7, Inverters - Operating & 3.8.9, US/STA Dist. Systems - Operating (Restore power to inst. bus 111 within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> or be in hot standby in next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.)

COMMENTS by-46\rev3 9

EVENT 4 BRIEF DESCRIPTION 1A CV Pump Trip EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Recognize symptoms and respond to a tripped CV pump (Cue) o Annunciator (1-7-B2) "RCP SEAL WTR INJ FLOW LOW" o Annunciator (1-9-A3) "CHG PUMP TRIP" o Annunciator (1-9-D3) "CHG LINE FLOW HIGH LOW" o 1A CV pump trip light lit (Response)

• Direct actions to restore charging flow US

• Refer to BAR 1-9-A3 U-1 AST/U-1

• Isolate Letdown U-1 AST/U-1

• Ensure suction source to standby charging pump U-1

• Place 1CV121 in Manual at 10% Open U-1

• Start the 1B CV pump U-1 EXAMINERS NOTE:

The crew may elect to perform actions for loss of seal injection per 1BOA RCP-2 "LOSS OF SEAL COOLING".

Implement 1BOA RCP-2 "LOSS OF SEAL COOLING" to US direct operator actions to:

• Check RCP seal cooling U-1

• Start 1B CV pump U-1

• Throttle 1CV182 and 1CV121 to control seal injection flow U-1 EXAMINERS NOTE:

Instr. Bus 111 failure prevents auto make-up to VCT. Low VCT level will require manual action to Open make-up isolation valves per applicable BAR.

o Restore Letdown per BOP CV-17 U-1 AST/U-1

• Notify SM of unit status/EP potential US

• Refer to TRM 3.1.d, Charging Pumps - US Operating, and Tech Spec 3.5.2, ECCS - Operating (return to operable status within 7 days).

• Direct performance of 1BOSR 5.5.1-1 (Reference BOP CV-19) US

• Dispatch operators to locally check 1A CV pump/breaker CREW

• Notify EM Dept. to investigate 1A CV pump trip US

• Evaluate OLR (Yellow) US (Feedback) o 1B CV pump running o Charging flow restored o Seal injection flows normal COMMENTS by-46\rev3 10

EVENT 5 BRIEF DESCRIPTION Master PZR Pressure Controller EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Recognize symptoms and respond to a Master Pzr Press Controller failure (Cue) o Annunciator (1-12-D2) "PZR PRESS CONT DEV HIGH" o Annunciator (1-12-B2) "PZR PORV OR SAF VLV OPEN" Wont Open due to Bus 111 failure o PZR spray valves (1RY455B & C) open o Master PZR pressure controller output indication (1PK-455A) at 100%

o Actual PZR pressure dropping (Response)

• Check PZR pressure U-1

• Take manual control to restore PZR pressure

• Place Master PZR pressure controller in manual U-1

• Control PZR pressure

• Check PZR PORVs, spray valves and heaters U-1 (Pzr Htrs wont work due to Bus 111 failure)

• PZR PORVs - closed U-1

• PZR spray valves - normal U-1

• PZR heaters - normal U-1 (Pzr Htrs wont work due to Bus 111 failure)

• Review Tech Spec 3.4.1, US DNB Limits.

• Contact SM/maintenance to investigate 1PK-455A failure US (Feedback) o Appropriate annunciators clear o Associated trip status lights and annunciators lit o PZR pressure restored to normal COMMENTS by-46\rev3 11

EVENT 6 Brief

Description:

1A Main Steam line break inside of Cnmt.

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Recognize symptoms and respond to main steam line break inside of cnmt.

(Cue) o Cnmt temp and pressure increasing o Low S/G & Main Steam Line Pressure o Rx Trip and Safety Injection o Multiple Annunciator Alarms (Response)

Automatic Rx Trip CREW Implement 1BEP-0, Reactor Trip or Safety Injection

• Inform SM of unit status/potential EP event US/STA

• Reactor trip verified U-1

• Rod bottom lights

• Reactor trip/Bypass breakers

• Neutron flux dropping

• • Turbine MANUALLY TRIPPED by fast action GV CLOSED from OWS panel G-5512 U-1 AST * * *

• GVs closed

• TVs closed

• 4 KV ESF busses are energized U-1 AST

• Bus 141 energized

• Bus 142 energized

• SI Status

• SI is actuated/required CREW o SI ACTUATED permissive light lit o SI first out annunciator lit o SI equipment automatically actuated

• Actuate SI U-1/U-1 AST

• Feedwater Status CREW COMMENTS by-46\rev3 12

(NOTE)

Loss of Instrument Bus 111 causes failure of A train ESF load to automatically start on SI signal. A Train ESF loads must be manually aligned to complete critical task. RCP Trip criteria may also be met early during scenario.

• • Verify ECCS Status CREW

• Verify 1B CV Pp Running U-1 AST/U-1

• • START 1A SI Pp U-1 AST/U-1 * * *

• • START 1A RH Pp U-1 AST/U-1 * * *

• Verify RCFCs Running in Accident Mode

• *Manually align A Train components U-1 AST/U-1

• Verify Cnmt Isolation Phase A

• *Manually align A Train components U-1 AST/U-1

• Verify Cnmt Ventilation Isolation U-1 AST/U-1

• Verify Aux. Feed System

• *Manually align A Train components U-1 AST/U-1

• US should dispatch NLO to close open throttle vlvs US to isolate faulted S/G

• Verify CC Pps Running

• *Manually align A Train component Start 1A CC PpU-1 AST/U-1

• Verify SX Pps Running

• *Manually align A Train component Start 1A SX PpU-1 AST/U-1

• Main Steam Line Isolation

• Manually attempt to close 1A & 1D MSIVs U-1 AST/U-1

• Check if Cnmt Spray is Required

• *Manually align A Train if required U-1 AST/U-1

• Verify Total Aux. Feed System Flow

• *Manually align A Train components U-1 AST/U-1

• US should dispatch NLO to close open throttle vlvs US to isolate faulted S/G

• Verify ECCS Valve alignment

• *Manually align A Train components U-1 AST/U-1

• Verify ECCS Flow U-1 AST/U-1

• Verify one Pzr PORV relief path available U-1

• Verify Main Generator Tripped U-1 AST/U-1 by-46\rev3 13

• Verify D/Gs Running

• *Manually Start 1A D/G U-1 AST/U-1

• Verify Ventilation Equipment aligned for Emergency

• *Manually align A Train components U-1 AST/U-1

• Verify Pzr Spray Valves Closed U-1 AST/U-1 EXAMINERS NOTE:

Due to steam line break RCS temperature control will not be possible. The crew should stop dumping steam and close all MSIVs. They should also stop Aux Feed flow to the faulted S/Gs.

• Maintain RCS Temperature Control U-1 AST/U-1

• Check RCP Status U-1 AST/U-1

• Check S/G Secondary Pressure boundaries intact U-1 AST/U-1

• Crew determines Secondary Pressure Boundaries not intact and transitions to 1BEP-2, Faulted S/G Isolation EXAMINERS NOTE:

US directs transition from 1BEP-0 to 1BEP-2, Faulted S/G Isolation. The Critical Task in this procedure is to isolate the Non-Faulted S/Gs from the Faulted S/Gs. This is accomplished by closing the MSIVs on the Non-Faulted 1B &

1C S/Gs.

Announcement of faulted Steam Generator symptoms US Transition to 1BEP-2 "FAULTED SG ISOLATION"

• Implement STA function at transition from 1BEP-0 STA "RX TRIP OR SI"

• Monitor plant conditions using status trees STA Perform operator actions to establish the following conditions:

• Isolate/close MSIVs and bypass valves U-1 AST

• Identify at least 1 non-faulted S/G (1B & 1C) U-1 AST

• Faulted SG isolated (1A & 1D S/Gs) US/U-1 AST

• AF isolated (1AF013A&E closed & 1AF013D&H locally closed)

• Main feedwater isolated

• 1A & 1D SG PORV closed (1MS018A&D)

• Blowdown isolation valves closed (1SD002A-H)

• Blowdown sample valve closed (1SD005A-D)

• Monitor AF pump suction pressure U-1 AST

• Check Secondary Radiation

• Identify NO ruptured SGs U-1 AST by-46\rev3 14

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A

• Transition to 1BEP-1, Loss of Rx or Secondary Coolant US Transition from 1BEP-2 to 1BEP-1, "LOSS OF US REACTOR OR SECONDARY COOLANT" upon verification that a SGTR does not exist per 1BEP-2 Perform operator actions of 1BEP-1 to establish the following conditions:

• Check status of RCPs U-1

• Check SG pressure boundaries intact (1A & D SG faulted)U-1 AST

• Check intact SG levels U-1 AST

• SG levels > 10%

• Maintain SG NR levels between 10% - 50%

• SG levels not rising in an uncontrolled manner

• Check secondary radiation trends normal U-1 AST

• Check SJAE/gland steam exhaust and MS line radiation normal for plant conditions

• Check PZR PORVs and isolation valves U-1 Transition from 1BEP-1 to ES-1.1 "SI TERMINATION" US when the following conditions are met:

• Acceptable RCS subcooling

• Secondary heat sink

• SG NR levels > 10%

• > 500 gpm total flow

• RCS pressure is stable/rising

• PZR level > 12%

Direct operator actions to US establish the following conditions of ES-1.1:

• Reset SI U-1/U-1 AST

• Reset Containment Isolation U-1 AST

• Phase A

• Phase B

• Check SAC run light lit

• IA restored to Cnmt

• CV system realigned U-1

• 1B CV pump already running

• Check RCS pressure stable or rising U-1

• • Terminate high-head ECCS U-1 * * *

• CV pump suction aligned to RWST

• SI recirc sump/CV miniflows reset

• CV miniflow valves open

• • 1SI8801A & B closed by-46\rev3 15

• Establish charging flow U-1

• 1CV182 controller at 0%

• 1CV8105 and 1CV8106 opened

• 1CV182 throttled (8-13 gpm seal injection)

• Control charging to maintain PZR level U-1

• SI pumps stopped U-1/U-1 AST

• RH pumps stopped U-1/U-1 AST TERMINATE SCENARIO

• Classify conditions per minimum applicable EP SM description

• SITE EMERGENCY

• MU8,

• Identify reportability requirements SM

• SAF 1.1 - Declaration of an Emergency Class

• SAF 1.5 - ECCS Injection/Actuation

• SAF 1.6 - RPS actuation

• SAF 1.7 - System actuation not including RPS COMMENTS by-46\rev3 16

Appendix D Scenario Outline Form ES-D-1 Facility: Byron Scenario No: #2 Op-Test No: 2008-01 Examiners: Operators:

Initial Conditions: Rx Power ~ 100%.

Turnover: Ramp down to 95% Rx Power.

Event Malf. Event Event No. No. Type* Description msv1ms004a BOP 1 C 1MS004A Fails Open. Rx Power increases > 100%

=100 SRO RO 1a R Ramp from 102% down to 98%

SRO RO 2 Cv16 100 I 1LT-112 Failure High SRO BOP 3 Rx18f 650 I 1TE-445 Failure High SRO BOP 4 rm061 C Failure of 0PR031J to actuate VC Emergency Make-Up SRO BOP 5 Eg03 96 C Failure of Main Generator Voltage Regulator High SRO 6 Th04a 50000 M TEAM Sesmic event results in Large Break LOCA 7 Cs05 C TEAM 1B CS Train fails to align, Manual action required 8 Rh01b C TEAM 1B RH Pp Trips on OC at 49% RWST level 9 Ed053p open C TEAM 1SI8811A Fails to open on low RWST level

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

SCENARIO NUMBER: #2___

TITLE:

TURNOVER INFORMATION:

The unit is at 100% power, steady state, equilibrium xenon, MOL.

THIS SCENARIO CONTAINS: The following objectives/K/A's 1MS004A Steam Dump Valve Leak Load Ramp from 100% to 95% Rx Pwr 1TE-445 Failed High High Rad Alarm on 0PR31J with no Emergency Mode Actuation Signal - Manual alignment required Main Generator Voltage Regulator fails high Large Break LOCA Failure of 1B CS Train to properly align Failure of 1SI8811A Cnmt Recirc Sump Isolation Vlv to Open Failure of 1B RH Pp COMPLETION CRITERIA: Initiate RCS Cooldown to 200oF CRITICAL TASKS:

1. Manually align the 0A VC Train to Emergency Mode.

2. Manually align the 1B CS Train during 1BEP-0.

3. Initiate Make-Up flow to the RWST during 1BCA-1.1.

Examinees: US RO BOP Evaluator: Date:

by-46\rev3 1

10 CFR 55.45 X 1. Perform pre-startup procedures for the facility, including operation those controls associated with plant equipment that could affect reactivity.

X 2. Manipulate the console controls as required to operate the facility between shutdown and designated power levels.

X 3. Identify annunciators and condition-indicating signals and perform appropriate remedial action where appropriate.

X 4. Identify the instrumentation systems and the significance of facility instrument readings.

X 5. Observe and safely control the operating behavior characteristics of the facility.

X 6. Perform control manipulations required to obtain desired operating results during normal, abnormal, and emergency situations.

X 7. Safely operate the facility's heat removal systems, including primary coolant, emergency coolant, and decay heat removal systems and identify the relation of the proper operation of these systems to the operation of the facility.

X 8. Safely operate the facility's auxiliary and emergency systems, including operation of those controls associated with plant equipment that could affect reactivity or the release of radioactive materials to the environment.

X 9. Demonstrate or describe the use and function of the facility's radiation monitoring systems, including fixed radiation monitors and alarms, portable survey instruments, and personnel monitoring equipment.

10. Demonstrate knowledge of significant radiation hazards, including permissible levels in excess of those authorized, and ability to perform other procedures to reduce excessive levels of radiation and to guard against personnel exposure.

X 11. Demonstrate knowledge of the emergency plan for the facility, including, as appropriate, the operator's or senior operator's responsibility to decide whether the plan should be executed and the duties under the plan assigned.

X 12. Demonstrate the knowledge and ability as appropriate to the assigned position to assume the responsibility associated with the safe operation of the facility.

X 13. Demonstrate the applicant's ability to function within the control room team as appropriate to the assigned position, in such a way that the facility licensee's procedures are adhered to and that the limitations in its license and amendments are not violated.

Simulator Scenario Review Checklist

1. The scenario has clearly stated Yes 8. Operators have sufficient time to Yes objectives in the scenario summary. carry out expected activities without

2. The initial conditions are realistic, in Yes undue time constraints. Cues are given.

that some equipment and/or If time compression techniques are used, instrumentation may be out of service, but it scenario summary clearly indicates.

does not cue crew into expected events. 9. The simulator modeling is not altered. Yes

3. The scenario consists mostly of Yes 10. All crew competencies can be Yes related events. evaluated.

4. Each event description consists of: Yes 11. The scenario has been validated. Yes

• the point in the scenario when it 12. The sampling plan indicates that Yes is to be initiated the scenario was not used for training

• the malfunction(s) that are entered during the requal cycle. Evaluate the need to initiate the event to modify/replace scenario if used.

• the symptoms/cues that will be visible 13. Total malfunctions inserted: 4-8 8 to the crew 14. Malfunctions that occur after

• the expected operator actions EOP entry: 1-4 3 (by shift position) 15. Abnormal Events: 1-2 3

• the event termination point 16. Major Transients: 1-2 1

5. No more than one non-mechanistic Yes 17. EOPs used beyond primary failure (e.g., pipe break) is incorporated scram response EOP: 1-3 3-4 into the scenario without a credible preceding 18. EOP Contingency Procedures incident such as a seismic event. used: 0-3 1

6. The events are valid with regard to Yes 19. Approximate scenario run time: No physics and thermodynamics. 45-60 minutes

7. Sequencing/timing of events is Yes 20. EOP run time: Yes reasonable, and allows for the 40-70% of scenario run time examination team to obtain complete 21. Crew Critical Tasks: 2-5 3 evaluation results commensurate 22. Technical Specifications are Yes with the scenario objectives. exercised during the test.

by-46\rev3 2

SCENARIO OVERVIEW The unit is at 100% Rx power, steady state, equilibrium xenon, MOL.

The scenario begins with the operating crew preparing to ramp from 100% Rx Pwr to 95% Rx Pwr when Steam Dump valve 1MS004A fully opens. This pushes Rx Pwr above 100% and required the unit to be ramped down and the valve isolated.

Once 1MS004A has been isolated, the ramp to 95% can commence.

After enough of the actions to ramp to 95% have been completed or the ramp to 95% has been completed the Loop 2 Thot Channel will fail High. This failure will require the crew to place the Control Rods into Manual to stop outward rod motion. The crew enters 1BOA INST-2, stablizes the plant and trips the associated bistable. The applicable Tech Spec for this failure is 3.3.1. Crew will not be required to trip bi-stables since bi-stable switches are not modeled.

Following initiation of bistable tripping for the Thot Channel failure 0PR31J will go into High Rad Alarm without actuating the Emergency Make-Up Mode of Operation for the 0A VC Train. The crew will need to recognize the appropriate system response did not occur and will have to manually align the 0A VC Train into the Emergency Make-Up Mode.

The next failure to occur will be for the Main Generator Voltage Regulator output to fail high. This will result in increased excitation of the Main Generator which results in increased MVAR output and thus increased current flowing through the generator. The crew should recognize the failure respond to the applicable BAR procedures switch the voltage regulator to OFF and lower generator output to within limits.

The major failure for this scenario will be a seismic event that causes a Large Break LOCA. During 1BEP-0 it will be discovered that the 1B CS Train doesnt align properly. The crew must take manual actions to correctly align the 1B CS Train into operation.

When RWST water level reaches 49% the 1B RH Pp will trip due to a C overcurrent condition. When RWST water level reaches 46% the 1SI8811A Cnmt Sump Isolation Valve will not open. This results in a Loss of Emergency Recirculation capability and thus 1BCA-1.1 needs to be enetered from 1BEP ES-1.3.

by-46\rev3 3

SCENARIO SETUP GUIDE

- Initialize IC-22: "full power, steady state, equilibrium xenon, MOL."

- Lineup control boards.

- Place simulator in run (allow simulator to run during board walkdowns and turnover).

- Type bat a:/BY-46 and ensure the following insert:

- Perform TQ-BY-201-0113, Appendix A, Simulator Exam/ Scenario Reset Checklist EVENT TIME MALF NO. DESCRIPTION 1 0 N/A 1MS004A Fails Open, Ramp Unit to < 100% Rx Pwr 2 4 N/A Ramp Unit from 100% to 95%

3 25  ???? Failure of 1TE-445 High 4  ??  ???? Failure of 0PR31J to actuate Emergency Make-Up Mode 5  ??  ???? Failure of Main Generator Voltage Regulator High 6  ??  ???? Seismic event results in Large Break LOCA 7  ??  ???? 1B CS Train fails to align, Manual action required 8  ??  ???? 1B RH Pp trips on C overcurrent at 49% RWST level 9  ??  ???? 1SI8811A fails to open on low RWST level 46.7%

Note 1: Events 6 &7 can be tied to the seismic event and events 8 & 9 should be tied to RWST Level.

by-46\rev3 4

INSTRUCTOR/SIMULATOR RUN AID GUIDE EVENT ADDITIONAL INFORMATION 1

Remote functions per event:

2 Remote functions per event:

EVENT 1 by-46\rev3 5

BRIEF DESCRIPTION 1MS004A Fails Open EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Perform the action to determine cause of over power condition and take actions to reduce Rx Pwr to < 100%.

The crew should also determine cause of the overpower condition and take actions to isolate the failed open Steam Dump valve.

(Cue) o Annunicator Bank D Rod Stop C-11 o Annunicator Pwr Rng Flux High Rod Stop o Rx Power > 100%

o Crew notices 1MS004A Open sugar cube light lit (Response)

• Refer to 1BGP 100-4, Power Descension Crew

• Direct actions to lower Rx Pwr US

• PROGRAM Turbine Controls to ramp down U-1 AST

• BORATE per BOP CV-6 to control Tave-Tref U-1 within desired limits

• INSERT Control Rods to maintain I and Tave-Tref U-1

• STOP ramp when < 100% Rx Pwr US

• Direct NLO to Locally isolate 1MS004A U-1 AST EXAMINERS NOTE:

COMMENTS by-46\rev3 6

EVENT 2 BRIEF DESCRIPTION Ramp Unit from 100% to 95%

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Re-activity manipulation for this scenario.

(Cue) o Per the initial scenario cue.

(Response)

• Refer to BGP 100-4, Power Descension CREW

• Direct actions to lower Rx Pwr US

• PROGRAM Turbine Controls to ramp down U-1 AST

• BORATE to control Tave-Tref within desired limits U-1

• INSERT Control Rods to maintain I and Tave-Tref U-1

• STOP ramp at 95% Rx Pwr US EXAMINERS NOTE:

COMMENTS by-46\rev3 7

EVENT 3 BRIEF DESCRIPTION 1TE-445 Fails High EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Recognize symptoms and respond to a Failed High Tave Channel (Cue) o Annunciator o Annunciator o Annunciator o Annunciator o Annunciator o Annunciator (Response)

• Refer to BARs U-1 AST/U-1

• Direct actions to enter 1BOA INST-2 US

• PLACE Rod Bank Select Switch in Manual U-1

• Manually Defeat Failed RTD Channel

• SELECT failed Tave channel with Tave Defeat Switch U-1

• SELECT failed T channel with T defeat switch U-1

• SELECT an operable RTD channel to the T Recorder U-1

• Check if Rod Control can be placed in Auto

• Turbine Low Power Interlock C5 Not Lit U-1

• Tave-Tref deviation Stable and within 1oF U-1

• Place Rod Bank Select Switch in Auto if desired U-1

• Check Pzr Level normal and Stable U-1

• Locally trip Bistables for failed channel U-1 AST/U-1

• Check P12 Interlock in correct state for current RCS temp U-1

• Defeat affected channel input to PDMS (T0422 to Test) U-1

• Enter Tech Spec 3.3.1 for the failed channel US EXAMINERS NOTE:

COMMENTS by-46\rev3 8

EVENT 4 BRIEF DESCRIPTION 0PR31J High Alarm fails to align the 0A VC Train EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Recognize symptoms and respond to a 0PR31J High Rad Alarm (Cue) o RM-11-2-0PR31J Annunciator (0PB131) "Main Control Room Out Air In OA" (Response)

• Direct actions to respond to the RM-11 alarm US

• Enter BAR RM-11-2-0PR31J U-1 AST/U-1

• Determines Auto actions have not occurred U-1 AST

• STARTS Make-Up Fan 0VC03CA U-1 AST

• Aligns recirculation charcoal adsorber U-1 AST

• Direct NLO to STOP 0VV01CA & B at 0VV01J U-1 AST

• Notify RP to perform BRP 5820-13 US

• Enter Tech Spec 3.3.7, spec 3.7.10 not required US EXAMINERS NOTE:

The crew may elect to perform actions to swap trains of Main Control Room HVAC but this is not required or anticipated.

Implement 1BOP-VC-17 "Swapping Control Room Chillers US and HVAC Trains"

• Secure electric heaters U-1 AST

• Secure chiller U-1 AST

• Secure Ventilation system U-1 AST

• Start standby Ventilation system U-1 AST

• Start standby chiller U-1 AST

• Start standby electric heaters U-1 AST (Feedback)

COMMENTS by-46\rev3 9

EVENT 5 BRIEF DESCRIPTION Main Generator Voltage Regulator Output Fails High.

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Recognize symptoms and respond to the Main Generator Voltage Regulators output failing high.

(Cue) o Annunciator (1-19-B6) "Generator Field Forcing" (Response)

Implement BAR 1-19-B8

• PLACE Voltage Regulator Control Switch to OFF U-1 AST

• ADJUST Base Adjuster reduce exciter field current to U-1 AST LESS THAN 100 amps

• Notify Electric Operations U-1 AST

• Check U-2 for adverse Main Generator trends U-1 AST

• If Generator field current cannot be reduced to LESS U-1 AST THAN 109 amps THEN trip the Rx if above P-8 COMMENTS by-46\rev3 10

EVENT 6 BRIEF DESCRIPTION Large Break LOCA with failure of the 1B CS Train to properly align.

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Recognize symptoms and respond to a Large Break LOCA (Cue) o Annunciator () "Rx Trip" o Annunciator () "Safety Injection (Response)

Automatic Rx Trip CREW Implement 1BEP-0, Reactor Trip or Safety Injection

• Inform SM of unit status/potential EP event US/STA

• Reactor trip verified U-1

• Rod bottom lights

• Reactor trip/Bypass breakers

• Neutron flux dropping

• Turbine trip verified by U-1 AST

• GVs closed

• TVs closed

• 4 KV ESF busses are energized U-1 AST

• Bus 141 energized

• Bus 142 energized

• SI Status

• SI is actuated/required CREW o SI ACTUATED permissive light lit o SI first out annunciator lit o SI equipment automatically actuated

• Actuate SI U-1/U-1 AST

• Feedwater Status CREW COMMENTS by-46\rev3 11

• Verify ECCS Status CREW

• Verify CV Pps Running U-1 AST/U-1

• Verify SI Pps Running U-1 AST/U-1

• verify RH Pps Running U-1 AST/U-1

• Verify RCFCs Running in Accident Mode U-1 AST/U-1

• Verify Cnmt Isolation Phase A U-1 AST/U-1

• Verify Cnmt Ventilation Isolation U-1 AST/U-1

• Verify Aux. Feed System U-1 AST/U-1

• Verify CC Pps Running U-1 AST/U-1

• Verify SX Pps Running U-1 AST/U-1

• Main Steam Line Isolation U-1 AST/U-1 Note: Not exactly sure what failure will be input or what actions will be required to manually re-align the B CS Train

• • Check if Cnmt Spray is Required

• Manually align B Train U-1 AST/U-1 * *

• Test Switch to Test Position

• Verify Total Aux. Feed System Flow U-1 AST/U-1

• Verify ECCS Valve alignment U-1 AST/U-1

• Verify ECCS Flow U-1 AST/U-1

• Verify one Pzr PORV relief path available U-1

• Verify Main Generator Tripped U-1 AST/U-1 COMMENTS by-46\rev3 12

• Verify D/Gs Running U-1 AST/U-1

• Verify Ventilation Equipment aligned U-1 AST/U-1 for Emergency

• Verify Pzr Spray Valves & PORVs Closed U-1 AST/U-1

• Maintain RCS Temperature Control U-1 AST/U-1

• Check RCP Status U-1 AST/U-1

• Check S/G Secondary Pressure boundaries Intact U-1 AST/U-1

• Check S/G Tubes are Intact U-1 AST/U-1 EXAMINERS NOTE:

US directs transition from 1BEP-0 to 1BEP-1, Loss of Reactor of Secondary Coolant. When RWST Level get to 46%

the Crew will transition to 1BEP ES-1.3, Cold Leg Recirculation.

• Check if RCS is Intact U-1 AST/U-1 (Crew will transition to 1BEP-1, Loss of Rx or Secondary Coolant)

Announcement of faulted Steam Generator symptoms US Transition to 1BEP-1 "Loss of Rx or Secondary Coolant"

• Implement STA function at transition from 1BEP-0 STA "RX TRIP OR SI"

• Monitor plant conditions using status trees STA Operator actions of 1BEP-1 establish the following conditions:

• RCPs tripped (RCP should have been tripped earlier) U-1

• Steam Generator boundaries intact U-1 AST

• All Steam Generator pressures stable

• SG levels maintained between 10%(31%) - 50% U-1 AST

• Check secondary radiation normal U-1 AST

• All secondary radiation trends normal for plant conditions

• Acceptable RCS subcooling U-1

• Secondary heat sink U-1 o SG NR levels > 10%(31%)

o > 500 gpm total flow

• RCS pressure is stable/rising U-1

• PZR level > 12%(28%) U-1 COMMENTS by-46\rev3 13

• Check if CS should be Stopped U-1

• CS Pumps running

• Reset CS signal

• Spray Add Tank Lo-2 level lights lit (answer should be no)

• Cnmt pressure less than 15 psig (it may be)

• Sprays operating time greater than 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> (it will not be)

• Check if RH Pumps should be Stopped U-1

• Reset SI

• Verify SI ACTUATED permissive light NOT LIT

• Verify AUTO SI BLOCKED permissive light LIT

• Check RCS pressure greater than 325 psig (it wont be so go to step 10)

• Check if DGs should be stopped U-1

• Check 4 KV ESF busses energized by offsite power

• Check 4 KV Non-ESF busses energized by offsite power

• Stop any unloaded DG

• Initiate evaluation of plant status U-1

• Verify power to a least on RH pump

• Verify CNMT sump isol valve position lights LIT

• Check Aux Bldg radiation trends NORMAL for PLANT CONDITIONS

• Reset CNMT Isol Phase A

• Place Hydrogen Monitors in service per BOP PS-9

• Consult TSC for obtaining samples

• Evaluate plant equipment

• Prepare Hydrogen Recombiners to run per BOP OG-10

• Align SX MDCT for long term cooling per BOP SX-T2

• Shutdown all HD Pumps

• Shutdown FW Pumps per BOP FW-2

• Shutdown all unnecessary CD/CB Pumps per BOP CD/CB-2

• Align NDCT for temperature and level control

• Shutdown all unnecessary CW Pumps per BOP CW-2

• Shutdown chiller on non-operating VC train

• Check if RCS cooldown and depressurization is required U-1

• Check RCS pressure greater than 325 psig

• Check if transfer to cold leg recirculation is required U-1

• Check ECCS in INJECTION MODE

• Check RWST level less than 46% if yes go to 1BEP ES-1.3 by-46\rev3 14

EXAMINERS NOTE:

US directs transition from 1BEP-0 or 1BEP-1 when RWST Level get to 46%. The Crew will transition to 1BEP ES-1.3, Cold Leg Recirculation.

• Recommend US transitions to 1BEP ES-1.3 "TRANSFER STA TO COLD LEG RECIRCULATION" Transition to 1BEP ES-1.3 "TRANSFER TO COLD LEG US RECIRCULATION" Direct operator actions of 1BEP ES-1.3 to establish US the following conditions:

• Establish CC flow to RH HXs U-1/U-1 AST

• Check U-0 CC HX aligned to U-1

• Check 2 CC Pumps running

• Open 1CC9412A/B

• Check CC to RH HX flows > 5000 GPM

• Check Cnmt floor water level > 8"(13") U-1 AST

• Align RH pumps suction to Cnmt sumps U-1 AST

• Place Train B SVAG valve control switch to CLOSE

• Check RH Pumps both running (1B RH not running)

• 1SI8811A NOT open (GO TO Att. A)

• Check if RH Pump 1A needs to be aligned to CNMT Sump U-1 AST

• 1SI8811A closed

• Check Train A Recirc flowpath from CNMT Sump available U-1 AST

• 1A RH pump running

• 1SI8811A energized (1SI8811A is NOT energized)

• Transfer to cold leg recirculation and establish ECCS U-1 AST/U-1 recirculation flow before RWST level reaches 7%

• Place 1A RH pump in PULL OUT

• Close 1SI8812A o Place 1A CS pump in PULL OUT

• Close 1CS001A

• Open 1SI8811A (It will not Open) o Reopen 1CS001A o Restart 1A CS pump (will NOT start)

• Check if RH Pump 1B needs to be aligned to CNMT Sump U-1 AST

• 1SI8811B closed (open)

• Close 1SI8812B

• Check at least one CNMT Sump Recirc flowpath Established U-1 AST

• 1SI8811A Not Open

• 1B RH Pp Not Running

• Close 1SI8812B

• Close 1SI8812B

• Trip SVAG valve C/Ss and then transition to1 BCA-1.1 EXAMINERS NOTE:

US directs transition from 1BCA-1.1 since neither train of Emergency Coolant Recirculation could be established.

COMMENTS by-46\rev3 15

Transition to 1BCA-1.1 "Loss of Emergency Coolant Recirculation US Direct operator actions of 1BCA-1.1 to establish US the following conditions:

• Check Emergency Coolant Recirc Equip Available U-1 AST

• At Least One Train Available

• 1A RH Pp

• 1SI8811A

• 1B RH Pp

• 1SI8811B

• RWST level LO-2 Alarm Lit U-1 AST

• CNMT sump isol valves OPEN (Dispatch NLOs) U-1 AST

• CNMT Floor water level at least 8 (13 adverse) U-1 AST

• CHECK at least one train of Emergency Recirc U-1 AST Equipment Restored (Answer will be NO)

• RESET SI U-1 AST

• DEPRESS both SI reset Pushbutton

• RESET RWST Auto Swapover U-1 AST

• Depress SI recirc sump isol valve reset pushbuttons

• • ADD Make-up to RWST as necessary U-1 AST * * *

• Initiate BOP SI-13, Filling the RWST

• CHECK Intact S/G Levels U-1 AST

• Narrow range level > 10% (31% adverse)

• Feed flow maintaining BETWEEN 10-50% S/G level

• Initiate RCS Cooldown to 200oF U-1 AST TERMINATE SCENARIO COMMENTS by-46\rev3 16

• Classify conditions per minimum applicable EP US description

• SITE EMERGENCY

• FS-1

• Identify reportability requirements US

• SAF 1.1 - Declaration of an Emergency Class

• SAF 1.5 - ECCS Injection/Actuation

• SAF 1.6 - RPS actuation

• SAF 1.7 - System actuation not including RPS by-46\rev3 17

Appendix D Scenario Outline Form ES-D-1 Facility: Byron Scenario No: #3 Op-Test No: 2008-01 Examiners: Operators:

Initial Conditions: Rx Power ~ 100%.

Turnover: Continue to operate at 100% Rx Power.

Event Malf. Event Event No. No. Type* Description BOP 1 NONE C Shutdown the 1A CW Pp SRO RO Ramp down 50 MW to account for secondary 2 NONE R SRO inefficiencies resulting from CW Pp shutdown MF CV23B RO 3 C Failure of 1B Letdown Hx 20 SRO BOP 4 MF FW22C C 1C CD/CB Pp Trip with Failure of STBY to Auto Start SRO MF CV10 0 RO 5 I Failure of 1CV121 Controller Low 60 SRO BOP 6 MF FW02A C 1FW012B Fails Open SRO 7 MF RP09B M TEAM Rx Trip switch on 1PM05J Fails 8 MF TC03 C TEAM Turbine Trip Fails requires Manual Turbine Trip 9 MF FW43 C TEAM 1A AF Pp Trips 10 MF FW44 C TEAM 1A AF Pp trips after 1 minute run

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

SCENARIO NUMBER: #3___

TITLE: Loss of Heat Sink requiring Bleed and Feed TURNOVER INFORMATION:

The unit is at 100% power, steady state, equilibrium xenon, MOL.

THIS SCENARIO CONTAINS: The following objectives/K/A's Start the 1A CW Pp per BOP CW-1 D/G Lube oil leak (Tech. Spec. only)

Load Ramp from 100% down 100 MW Letdown Hx tube leak (Tech. Spec.)

1C CD/CB Pump trips standby fails to start 1CV121 Controller Fails Low 1B TDFWP Trips, 1A MDFWP doesnt start Rx Fails to trip from 1PM05J Turbine Fails to trip must use manual trip pushbutton 1A & 1B AFW Pumps fails to start COMPLETION CRITERIA: Re-initiate feed flow to the hot dry S/Gs CRITICAL TASKS:

1. Manually Trip Rx from 1PM06J.

2. Manually Trip Turbine with manual trip pushbutton.

3. Initiate Bleed and Feed during 1BFR - H.1 when required.

Examinees: US RO BOP Evaluator: Date:

by-46\rev3 1

10 CFR 55.45 X 1. Perform pre-startup procedures for the facility, including operation those controls associated with plant equipment that could affect reactivity.

X 2. Manipulate the console controls as required to operate the facility between shutdown and designated power levels.

X 3. Identify annunciators and condition-indicating signals and perform appropriate remedial action where appropriate.

X 4. Identify the instrumentation systems and the significance of facility instrument readings.

X 5. Observe and safely control the operating behavior characteristics of the facility.

X 6. Perform control manipulations required to obtain desired operating results during normal, abnormal, and emergency situations.

X 7. Safely operate the facility's heat removal systems, including primary coolant, emergency coolant, and decay heat removal systems and identify the relation of the proper operation of these systems to the operation of the facility.

X 8. Safely operate the facility's auxiliary and emergency systems, including operation of those controls associated with plant equipment that could affect reactivity or the release of radioactive materials to the environment.

X 9. Demonstrate or describe the use and function of the facility's radiation monitoring systems, including fixed radiation monitors and alarms, portable survey instruments, and personnel monitoring equipment.

10. Demonstrate knowledge of significant radiation hazards, including permissible levels in excess of those authorized, and ability to perform other procedures to reduce excessive levels of radiation and to guard against personnel exposure.

X 11. Demonstrate knowledge of the emergency plan for the facility, including, as appropriate, the operator's or senior operator's responsibility to decide whether the plan should be executed and the duties under the plan assigned.

X 12. Demonstrate the knowledge and ability as appropriate to the assigned position to assume the responsibility associated with the safe operation of the facility.

X 13. Demonstrate the applicant's ability to function within the control room team as appropriate to the assigned position, in such a way that the facility licensee's procedures are adhered to and that the limitations in its license and amendments are not violated.

Simulator Scenario Review Checklist

1. The scenario has clearly stated Yes 8. Operators have sufficient time to Yes objectives in the scenario summary. carry out expected activities without

2. The initial conditions are realistic, in Yes undue time constraints. Cues are given.

that some equipment and/or If time compression techniques are used, instrumentation may be out of service, but it scenario summary clearly indicates.

does not cue crew into expected events. 9. The simulator modeling is not altered. Yes

3. The scenario consists mostly of Yes 10. All crew competencies can be Yes related events. evaluated.

4. Each event description consists of: Yes 11. The scenario has been validated. Yes

• the point in the scenario when it 12. The sampling plan indicates that Yes is to be initiated the scenario was not used for training

• the malfunction(s) that are entered during the requal cycle. Evaluate the need to initiate the event to modify/replace scenario if used.

• the symptoms/cues that will be visible 13. Total malfunctions inserted: 4-8 6 to the crew 14. Malfunctions that occur after

• the expected operator actions EOP entry: 1-4 3 (by shift position) 15. Abnormal Events: 1-2 3

• the event termination point 16. Major Transients: 1-2 1

5. No more than one non-mechanistic Yes 17. EOPs used beyond primary failure (e.g., pipe break) is incorporated scram response EOP: 1-3 2 into the scenario without a credible preceding 18. EOP Contingency Procedures incident such as a seismic event. used: 0-3 0

6. The events are valid with regard to Yes 19. Approximate scenario run time: No physics and thermodynamics. 45-60 minutes

7. Sequencing/timing of events is Yes 20. EOP run time: Yes reasonable, and allows for the 40-70% of scenario run time examination team to obtain complete 21. Crew Critical Tasks: 2-5 3 evaluation results commensurate 22. Technical Specifications are Yes with the scenario objectives. exercised during the test.

by-46\rev3 2

SCENARIO OVERVIEW The unit is at 100% Rx power, steady state, equilibrium xenon, MOL.

The scenario begins with the operating crew preparing to start the standby Circulating Water Pump. The crew then starts the 1A CW Pp.

TSO calls and orders an emergency load drop of 100 MW. The crew refers to the load Follow Curve to determine the correct amount of boric acid that they will add during the ramp. The crew will reduce turbine load and control reactor parameters during the load reduction.

After the actions to ramp down 100 MW have been completed the online Letdown Heat Exchanger will develop a tube leak into the CC system. The crew will be alerted to the failure by the CC surge tank hi rad alarm. The crew will implement BOA PRI-6, CC Malfunction procedure to address the failure. The SRO should realize that the crew needs to enter the RCS Leakage Tech Spec 3.4.13 for excessive (> 10 gpm) RCS leakage. Once the crew identifies the online Letdown Heat Exchanger as the problem the crew will swap to the standby Letdown Heat Exchanger and isolate both the CV and CC sides of the leaking Letdown Heat Exchanger.

The next failure to occur will be for the 1C CD/CB pump to trip with a failure of the standby pump to start.

The crew will take actions to manually start the standby pump while entering BOA SEC-1, Secondary Pump Trip procedure to address any other plant concerns.

Following the CD/CB pump trip the output of the controller for 1CV121 will fail low causing 1CV121 to drift closed reducing charging header flow. The reactor operator will need to take manual control of the controller and restore charging flow so that pressurizer level can be restored.

The 1B TDFWP Trips and the 1A MDFWP doesnt start to provide replacement feedwater flow. The crew will take actions per BOA SEC-1 to runback the Unit to 780 MW however the runback function on the turbine generator will not work so the crew will have to manually reduce turbine load.

The crew will not be able to maintain SG water levels and will have to trip the unit. This is the start of the major transient in which the reactor will not trip from the front panel 1PM05J. The reactor operator will have to use the alternate reactor trip switch located on 1PM06J. The turbine will also fail to trip and must be manually tripped using the trip pushbutton.

The reduction in feedwater results in lowering SG levels and a signal to automatically start the Aux. Feedwater Pumps.

The 1A AFW pump starts but trips on overcurrent immediately after its start. The 1B AFW will start and run for 1 minute and then trip. With no AFW pumps running once the crew transitions out of 1BEP-0, the crew should enter 1BFR - H.1.

The crew will need to initiate an RCS bleed and feed once SG wide range levels fall below 27% (43% adverse). The scenario will be terminated when feedwater flow is re-initiated to a hot dry SG.

by-46\rev3 3

SCENARIO SETUP GUIDE

- Initialize IC-22: "full power, steady state, equilibrium xenon, MOL."

- Lineup control boards.

- Place simulator in run (allow simulator to run during board walkdowns and turnover).

- Type bat a:/BY-46 and ensure the following insert:

- Perform TQ-BY-201-0113, Appendix A, Simulator Exam/ Scenario Reset Checklist EVENT TIME MALF NO. DESCRIPTION 1 0 N/A Start Standby CW Pp 2 4 N/A Ramp Unit from 100% down 100 MW 3 25  ???? Failure of A Letdown Hx 4  ??  ???? 1C CD/CB Pp trips Failure of STBY to start 5  ??  ???? Failure of 1CV121 Controller Low 6  ??  ???? 1B TDFWP Trips 1A MDFWP fails to start 7  ??  ???? Rx Trip switch on 1PM05J fails 8 Turbine trip fails requires trip via manual trip pushbutton 9  ??  ???? 1A AFW Pp trips on C overcurrent immediately after starting 10  ??  ???? 1B AFW Pp trips after 1 minute run by-46\rev3 4

INSTRUCTOR/SIMULATOR RUN AID GUIDE EVENT ADDITIONAL INFORMATION 1

Remote functions per event:

2 Remote functions per event:

EVENT 1 by-46\rev3 5

BRIEF DESCRIPTION Start Standby CW pump EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A (Cue)

Initial cue is to start standby Circulating Water Pump (Response)

• Refer to 1BOP CW-1, Circulating Water System Startup Crew

• Direct actions to start 1A CW Pp US

• BOP refers to 1BOP CW-1 step F.2 U-1 AST

• Verify local parameters are within spec

• Start 1CW01PA CW Pp

• Verify discharge valve 1CW001A is opening

• Throttle 1CW001A to obtain 38-50 psid across 1A CW Pp EXAMINERS NOTE:

COMMENTS by-46\rev3 6

EVENT 2 BRIEF DESCRIPTION Ramp Unit from 100% to 95%

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Re-activity manipulation for this scenario.

(Cue) o Per the initial scenario cue.

(Response)

• Refer to BGP 100-4, Power Descension CREW

• Direct actions to lower Rx Pwr US

• PROGRAM Turbine Controls to ramp down U-1 AST

• BORATE per BOP CV-6 to control Tave-Tref U-1 within desired limits

• INSERT Control Rods to maintain I and Tave-Tref U-1

• STOP ramp at 95% Rx Pwr US EXAMINERS NOTE:

COMMENTS by-46\rev3 7

EVENT 3 BRIEF DESCRIPTION Failure of the 1A Letdown Heat Exchanger (Tube Leak)

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Recognize symptoms and respond to a tube leak in the 1A Letdown Heat Exchanger.

(Cue) o Annunciator RM-11 alarm CC Surge Tank Hi-Rad o CC Surge Tank level increasing o Indicated letdown line flow decreases (Response)

• Refer to BARs U-1 AST/U-1

• Check CC Surge Tank level

• Surge tank level > 13% U-1

• Surge tank level stable U-1

• Check CC System status

• At least one CC Pp running U-1

• CC Pp discharge pressure low alarm not lit U-1

• Check Pzr Level normal and Stable U-1

• Check CC System Temperature

• CC Pp suction temp high alarm not lit U-1

• CC Hx outlet temp < 120oF U-1 o

• CC Hx outlet temp < 105 F U-1

• Check RCP Cooling

• RCP running U-1

• CC flow to RCPs normal with no alarms lit U-1

• CC Hx outlet rad monitor trends normal (wont be normal) U-1 Will go to Att B, Step 5

• Check for inleakage from RCP Thermal Barrier

• RCP Therm Barr CC Wtr Flow alarms Lit OR U-1

• Seal inj flow abnormally Hi (Both will be no goto step 6) U-1

• Isolate CC System Inleakage

• Check inleakage from RCS (cc rad trends rising) U-1

• Notify Chem to sample CC system for activity U-1

• Locate and Isolate inleakage from 1A L/D Hx U-1

• Locally Isolate CV side of 1A L/D Hx U-1

• Locally Isolate CC side of 1A L/D Hx U-1 EXAMINERS NOTE:

COMMENTS by-46\rev3 8

EVENT 4 BRIEF DESCRIPTION 1C CD/CB Pp Trips with failure of Standby Pp to auto start EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Recognize symptoms and respond to a trip of the 1C CD/CB Pp with a failure of the standby Pp to auto start.

(Cue) o Annunciator 1PM03J "CD/CB Pp Trip" (Response)

• Direct actions to respond to the tripped CD/CB Pp US

• Enter 1BOA SEC-1, Secondary Pump Trip Crew

• Check Turbine Load

• Check Turbine Load > 700 MW U-1 Ast

• Check Standby CD/CB Pp Running (failed to auto start) U-1 Ast

• Start Aux Oil Pp for Standby CD/CB Pp U-1 Ast

• Start Standby CD/CB Pp U-1 Ast

• Check at least 3 CD/CB Pps running U-1 Ast

• Check FW flow > or = to Steam Flow U-1 Ast

• Check FW Pps NOT Cavitating

• Close recirc valve on tripped CD/CB Pp U-1 Ast

• Check FW Pp discharge flows Oscillating (shouldnt be) U-1 Ast

• Check CD/CB Pp Flow Restored

• Check Alarm Not Lit CB Pp Dsch Flow Hi (1-17-B11) U-1 Ast

• Check Alarm Not Lit FW Pp NPSH Low (1-16-E1) U-1 Ast

• Check Plant Status

• Check Alarm Not Lit PDMS Inop (1-10-E8) U-1

• Check 1BOL 3.h Pwr Dist Monitoring Sys Not Entered U-1 Ast

• Check Alarm Not Lit PDMS Limit Exceeded (1-10-D7) U-1 Ast

• Check Delta I near target U-1 Ast

• Check Alarm Not Lit Rod Bank Lo Insert Limit (1-10-B6)U-1 Ast

• Check Alarm Not Lit Turbine runback U-1 Ast

• Check Alarm Not Lit Loss of Turb Load C7 (1-BP-4.6) U-1 Ast

• Restore Plant Conditions

• Adjust Boron Conc. as necessary U-1

• Verify control in Auto U-1 Ast

• Review BOP CD/CB-1 & CD/CB-2 U-1 Ast

• Adjust SG blowdown flows and calorimetric inputs U-1 Ast

• Verify DEHC feedback loop In Service U-1 Ast

• Notify Chemistry to monitor secondary systems U-1 Ast

• Return to Procedure and Step in Effect US by-46\rev3 9

EVENT 5 BRIEF DESCRIPTION The controller for 1CV121 fails low.

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Recognize symptoms and respond to the 1CV121 control valve controller output failing low.

(Cue)

• Charging Flow starts lowering.

• RCP seal injection low starts lowering.

• VCT level starts increasing.

(Response)

• PLACE Flow Controller 1FK-121 in Manual U-1

• ADJUST Controller Output to re-open 1CV121 U-1 EXAMINERS NOTE:

Depending on how fast the Reactor Operator catches the failure the crew may not enter a procedure to correct the failure. The SRO may direct the RO to m place the failed controller to manual and re-establish charging flow. If the crew delays they may enter the BAR for low charging low BAR 1-9-D3, 1BOA PRI-1 Excessive Primary Plant Leakage, or 1BOA RCP-2 Loss of Seal Injection.

COMMENTS by-46\rev3 10

EVENT 6 BRIEF DESCRIPTION 1B TDFWP Trips and the 1A MDFWP does not start.

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Recognize symptoms and respond Main Feedwater Pump trip.

(Cue)

• Annunciator (1-16-B1) "FW Pump 1B Trip"

• Annunciator (1-15-A4) SG 1A Flow Mismatch FW Flow Low

• Annunciator (1-15-B4) SG 1B Flow Mismatch FW Flow Low

• Annunciator (1-15-C4) SG 1C Flow Mismatch FW Flow Low

• Annunciator (1-15-D4) SG 1D Flow Mismatch FW Flow Low (Response)

Implement 1BOA SEC-1, Secondary Pump Trip

• Inform SM of unit status/potential EP event US/STA

• Close FW Pp Recirc Valve

• Close 1FW012B U-1 Ast

• Check Turbine Load

• Check Turbine Load > 700 MW U-1 Ast

• Check At Least One FW Pp Running U-1 Ast

• Restore Feed Flow

• Check FW Pp 1A Available U-1 Ast

• Start Aux Oil Pp for 1A FW Pp U-1 Ast

• Verify 1FW016 controller in Manual at 20% demand U-1 Ast

• Start 1A FW Pp (Pp Trips on OC immediately) U-1 Ast

• Reduce Turbine Load

• Initiate CD/FW Runback U-1 Ast

• Runback Pushbutton (Will not work) U-1 Ast

• OWS panel G-5512 U-1 Ast

• Check Turbine Load Dropping U-1 Ast

• Verify Rod Control in AUTO U-1

• Initiate Boration as necessary U-1 EXAMINERS NOTE:

US directs transition from 1BOA SEC-1 to 1BEP-0, Reactor Trip Response or Safety Injection when he realizes SG levels can not be maintained.

by-46\rev3 11

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Implement 1BEP-0, Reactor Trip Response or Safety Injection

• Manually actuate Reactor Trip from 1PM05J U-1 (Trip switch does not work on 1PM05J)

• • Manually actuate Reactor Trip from 1PM06J U-1 (Trip switch works on 1PM06J)

• Reactor trip verified U-1

• Rod bottom lights

• Reactor trip/Bypass breakers

• Neutron flux dropping

• Turbine trip verified by (Auto trip fails) U-1 AST

• GVs closed

• TVs closed

• Must use Manual trip pushbutton to actuate Turbine trip

• 4 KV ESF busses are energized U-1 AST

• Bus 141 energized

• Bus 142 energized

• SI Status

• SI is not actuated or required CREW o SI ACTUATED permissive light lit (Not Lit) o SI first out annunciator (Not Lit) o SI equipment automatically actuated (Not running)

• Transition to 1BEP ES-0.1, Reactor Trip Response CREW COMMENTS by-46\rev3 12

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A EXAMINERS NOTE:

The 1A AFW Pp trips on Overcurrent after initially starting. The 1B AFW Pp trips after a two minute run. US directs transitions to 1BEP ES-0.1 because SI has not actuated and is not required. The Crew will transition to 1BFR H-1 when all SG narrow range levels are < 10% (31% Adverse).

1BEP ES-0.1, Reactor Trip Response

• Verify Generator Trip U-1 AST

• Main Transformer Output Breakers Open

• Verify GCB 3-4

• Verify OCB 4-5

• Maintain RCS Temperature Control U-1

• RCP Running RCS Temp stable at or trending to 557F

• Determine if Boration is Required U-1 AST/U-1

• RCPs Running

• Check FW Status U-1 AST/U-1

• FW isol monitor lights LIT

• Trip all HD Pps

• Total Feed Flow to SGs > 500 gpm

• SG Blowdown isol valves closed 1SD002A-H

• Verify all Control Rods Fully Inserted U-1

• Check PZR Level > 17% U-1

• Check Charging and Letdown in Service

• PZR Level Trending to Program Level

• Check PZR Pressure Control U-1

• PZR Pressure > 1829 psig

• PZR Pressure Stable at or Trending to 2235 psig

• Check SG Level U-1

• Check Narrow range SG Level > 10% in any SG

• Control Feed flow to maintain between 10%-50% SG lvl

• Transition to 1BFR H-1, Loss of Heat Sink when all SG CREW narrow range levels drop below 10% and AF flow is < 500 gpm by-46\rev3 13

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A EXAMINERS NOTE:

US will direct transitions to Step 13 and initiate Bleed and Feed when three SG wide range levels are < 27% (43%

Adverse).

• Check if Secondary Heat Sink is Required U-1

• RCS Pressure > any Non-Faulted SG Pressure

• RCS Temperature > 350F

• Check Cent Chg Pp Status U-1

• Cent Chg Pp at least one Running

• Check if Bleed and Feed is Required U-1

• SG Wide range level in any three SGs < 27% (43% adverse) or

• PZR pressure > than 2335 psig due to Loss of Heat Sink

• Try to Establish AF to at least one SG U-1

• Check SG Blowdown isol Valves Closed 1SD002A-H

• Check SG Blowdown sample isol Valves Closed 1SD005A-D

• Prior to initiating feed flow review Att B

• Check AF Pp SX Suct Vlvs ARMED alarm Not Lit

• Check AF Pps Both Running (Attempt manual start)

• Check AF test valves OPEN 1AF004A&B

• Check AF isol Valves OPEN 1AF013A-H

• Check AF Throttle Valves OPEN 1AF005A-H

• Check Total AF flow > 500 gpm (It wont be)

• Reduce RCP Heat Input Stop all RCPs U-1

• Prepare FW System for Restoration

• Check at least one CD/CB Pp Running

• Place FW Reg valve in Manual at Zero Demand

• Place FW Bypass Reg Valve in Manual at Zero Demand

• Place Tempering flow control Valve in Manual at Zero Demand by-46\rev3 14

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A

• Reset FW Isolation Signal U-1

• Check FW isolation Aux Relay lights Lit

• Check SI Not Actuated

• Depress both FW Isolation Reset Pushbuttons

• Check FW Isol Actd relay lights Not Lit

• Dispatch an operator to pull FW Isol Relay Fuses

• Try to Establish Main FW flow to at least one SG U-1

• Check Startup FW Pp or 1A MDFWP available

• Open FW tempering isol valves 1FW035A-D

• Check at least two CD/CB Pps running

• Check Bus 159 Energized

• Verify Startup FW Pp Aux Oil Pp Running

• Verify Discharge Valve 1FW059 Open

• Open recirc valve 1FW076 and place c/s to Modulate

• Close Main FW Pp recirc valves 1FW012A-C

• Start Startup FW Pp (Pp wont start)

• Try to establish 1A MDFWP (Unavailable previously) U-1

• Try to establish Condensate Booster Pp flow U-1

• Close FW Pp recirc valves

• Start Aux Oil Pp for selected Pp

• Open selected FW Pp discharge valve 1FW002A-C, 1FW016, & 1FW059

• Check SI Not Actuated

• Check RCS Pressure < 1930 psig P-11 Lit ( It wont be)

• Depressurize RCS to 1880 psig by Opening one PZR PORV to drop SG pressure So CB Pps can inject into the SG EXAMINERS NOTE:

by-46\rev3 15

US will direct transitions to Step 13 and initiate Bleed and Feed when three SG wide range levels are < 27% (43%

Adverse). Step 13 through 16 must be perform without delay to ensure adequate core cooling is maintained.

• • Establish RCS Feed Path U-1 * * *

• Stop all RCPs

• Actuate SI

• • Verify RCS Feed Path U-1 AST/U-1 * * *

• Check Cent Chg Pps at least one running or

• Check SI Pps at least one running

• Check ECCS Valve Alignment Group 2 Injection lights Lit

• • Establish RCS Bleed Path U-1 AST/U-1 * * *

• Verify PZR PORV isol Valves Energized and OPEN

• Open PZR PORVs 1RY455A &1RY456

• • Verify Adequate RCS Bleed Path U-1 AST/U-1 * * *

• Verify PZR PORV Both Open

• Verify PZR PORVs isolation valves Both Open EXAMINERS NOTE:

Once RCS Bleed and Feed has been established the 1B AF Pp will become available. The scenario will end when the crew re-establishes feed flow to a Hot Dry SG per Att B.

Attachment B Feed Flow Limitations:

3 After Initiation of Bleed and Feed with Stable or Dropping Core Exit Temperatures A. Feed any non-dry SGs as follows:

• If SG feedlines are not voided, then feed non-dry SG at desired rate

• If SG feedlines are voided, then feed the non-dry SG between 60-80 gpm for 10 minutes prior to restoring desired feedwater flow.

B. If all SGs are dry, then feed one SG as follows:

• Feed associated SG between 60-80 gpm for 10 minutes

• After the 15 minutes, feed at a rate NOT to exceed 100 gpm

• When associated SG Wide Range level is > 10% feed flow may be raised as desired TERMINATE SCENARIO COMMENTS by-46\rev3 16

• Classify conditions per minimum applicable EP US description

• SITE EMERGENCY

• FS-1

• Identify reportability requirements US

• SAF 1.1 - Declaration of an Emergency Class

• SAF 1.5 - ECCS Injection/Actuation

• SAF 1.6 - RPS actuation

• SAF 1.7 - System actuation not including RPS by-46\rev3 17

Appendix D Scenario Outline Form ES-D-1 Facility: Byron Scenario No: #4 Op-Test No:

Examiners: Operators:

Initial Conditions: Rx Power ~ 4%.

Turnover: Rx is at ~ 4% power steady state, MOL.

Event Malf. Event Event No. No. Type* Description BOP 1 NONE N Perform Main Turbine Oil Checks per 1BGP 100-2 SRO RO 2 IMF NI35B I Intermediate Range NI N-35 fails low SRO RO 3 NONE R Increase or decrease Rx Pwr to > 10% or < P-6 SRO BOP 4 IMF SPT01B I 1D S/G Steam Pressure Transmitter 1PT-544 fails low SRO IMF IPP05 RO 5 I Turbine Impulse Pressure Detector 1PT-505 fails high 600 SRO IOR ZDI1CV BOP 6 CL C L/D Hx TCV 1CC130A fails closed SRO IMF FW19B 7 M TEAM 1C SG Feed Line Break inside Cnmt.

3.5 8 IMF DG08B C TEAM 1B D/G fails to start 9 IMF THO3C M TEAM 1C SGTR at 400gpm

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

SCENARIO NUMBER: #4___

TITLE:

TURNOVER INFORMATION:

The unit is at 4% power, steady state, MOL.

THIS SCENARIO CONTAINS: The following objectives/K/A's Perform Main Turbine Oil Checks per 1BGP 100-2 Intermediate Range NI N-35 becomes INOP (fails down scale)

Increase Rx Power to >10% or Decrease Rx Power to < P-6 1D S/G Steam Pressure Transmitter 1PT-544 fails low Turbine Impulse Pressure Detector 1PT-505 Fails High L/D Hx TCV 1CC130A fails closed Respond to a Feedline Break Inside Cnmt on 1C S/G Respond to a Failure of the 1A MSIV to Close Respond to a Failure of 1B D/G to Start Respond to a SGTR on 1C S/G COMPLETION CRITERIA: Re-initiate feed flow to the hot dry S/Gs CRITICAL TASKS:

1. Manually Trip Rx from 1PM06J.

2. Manually Trip Turbine with manual trip pushbutton.

3. Initiate Bleed and Feed during 1BFR - H.1 when required.

Examinees: US RO BOP Evaluator: Date:

by-46\rev3 1

10 CFR 55.45 X 1. Perform pre-startup procedures for the facility, including operation those controls associated with plant equipment that could affect reactivity.

X 2. Manipulate the console controls as required to operate the facility between shutdown and designated power levels.

X 3. Identify annunciators and condition-indicating signals and perform appropriate remedial action where appropriate.

X 4. Identify the instrumentation systems and the significance of facility instrument readings.

X 5. Observe and safely control the operating behavior characteristics of the facility.

X 6. Perform control manipulations required to obtain desired operating results during normal, abnormal, and emergency situations.

X 7. Safely operate the facility's heat removal systems, including primary coolant, emergency coolant, and decay heat removal systems and identify the relation of the proper operation of these systems to the operation of the facility.

X 8. Safely operate the facility's auxiliary and emergency systems, including operation of those controls associated with plant equipment that could affect reactivity or the release of radioactive materials to the environment.

X 9. Demonstrate or describe the use and function of the facility's radiation monitoring systems, including fixed radiation monitors and alarms, portable survey instruments, and personnel monitoring equipment.

10. Demonstrate knowledge of significant radiation hazards, including permissible levels in excess of those authorized, and ability to perform other procedures to reduce excessive levels of radiation and to guard against personnel exposure.

X 11. Demonstrate knowledge of the emergency plan for the facility, including, as appropriate, the operator's or senior operator's responsibility to decide whether the plan should be executed and the duties under the plan assigned.

X 12. Demonstrate the knowledge and ability as appropriate to the assigned position to assume the responsibility associated with the safe operation of the facility.

X 13. Demonstrate the applicant's ability to function within the control room team as appropriate to the assigned position, in such a way that the facility licensee's procedures are adhered to and that the limitations in its license and amendments are not violated.

Simulator Scenario Review Checklist

1. The scenario has clearly stated Yes 8. Operators have sufficient time to Yes objectives in the scenario summary. carry out expected activities without

2. The initial conditions are realistic, in Yes undue time constraints. Cues are given.

that some equipment and/or If time compression techniques are used, instrumentation may be out of service, but it scenario summary clearly indicates.

does not cue crew into expected events. 9. The simulator modeling is not altered. Yes

3. The scenario consists mostly of Yes 10. All crew competencies can be Yes related events. evaluated.

4. Each event description consists of: Yes 11. The scenario has been validated. Yes

• the point in the scenario when it 12. The sampling plan indicates that Yes is to be initiated the scenario was not used for training

• the malfunction(s) that are entered during the requal cycle. Evaluate the need to initiate the event to modify/replace scenario if used.

• the symptoms/cues that will be visible 13. Total malfunctions inserted: 4-8 6 to the crew 14. Malfunctions that occur after

• the expected operator actions EOP entry: 1-4 3 (by shift position) 15. Abnormal Events: 1-2 3

• the event termination point 16. Major Transients: 1-2 1

5. No more than one non-mechanistic Yes 17. EOPs used beyond primary failure (e.g., pipe break) is incorporated scram response EOP: 1-3 2 into the scenario without a credible preceding 18. EOP Contingency Procedures incident such as a seismic event. used: 0-3 0

6. The events are valid with regard to Yes 19. Approximate scenario run time: No physics and thermodynamics. 45-60 minutes

7. Sequencing/timing of events is Yes 20. EOP run time: Yes reasonable, and allows for the 40-70% of scenario run time examination team to obtain complete 21. Crew Critical Tasks: 2-5 3 evaluation results commensurate 22. Technical Specifications are Yes with the scenario objectives. exercised during the test.

by-46\rev3 2

SCENARIO OVERVIEW The unit is at 4% Rx power, steady state, MOL.

The scenario begins with the operating crew preparing to perform the Main Turbine Oil System Checks per 1BGP 100-2. This will complete 1BGP 100-2 in preparation for the Mode change to MODE 1.

Intermediate Range Nuclear Instrumentation channel N-35 fails low. The down scale alarm will come in and N-35 will need to be declared inoperable. Crew will perform 1BOA Instr-1 for the failed NI channel. Tech Spec 3.3.1 conditions A and F must be entered. Condition F requires Thermal Power be decreased < P-6 or be increased > P-10 within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. The crew will have to decide which action to take. Whichever action the crew takes, it will account for the reactivity manipulation for this scenario.

The scenario should be set up to have one TDFWP running when the crew takes the shift. The crew may also want to roll the main turbine while increasing reactor power. This may be a distraction with only three crew members, need to ensure they complete reactivity manipulation. After reactivity manipulation has been completed, the crew will respond to a failure of 1PT-544, the 1D S/G steam pressure channel failing low.

The BOP will take manual control of the 1D Feed Reg Valve and restore S/G level to normal. The Unit Supervisor will enter Tech Spec 3.3.2 and 3.3.4.

TSO calls and orders an emergency load drop of 100 MW. The crew refers to the load Follow Curve to determine the correct amount of boric acid that they will add during the ramp. The crew will reduce turbine load and control reactor parameters during the load reduction.

After the actions to ramp down 100 MW have been completed the online Letdown Heat Exchanger will develop a tube leak into the CC system. The crew will be alerted to the failure by the CC surge tank hi rad alarm. The crew will implement BOA PRI-6, CC Malfunction procedure to address the failure. The SRO should realize that the crew needs to enter the RCS Leakage Tech Spec 3.4.13 for excessive (> 10 gpm) RCS leakage. Once the crew identifies the online Letdown Heat Exchanger as the problem the crew will swap to the standby Letdown Heat Exchanger and isolate both the CV and CC sides of the leaking Letdown Heat Exchanger.

The next failure to occur will be for the 1C CD/CB pump to trip with a failure of the standby pump to start.

The crew will take actions to manually start the standby pump while entering BOA SEC-1, Secondary Pump Trip procedure to address any other plant concerns.

Following the CD/CB pump trip the output of the controller for 1CV121 will fail low causing 1CV121 to drift closed reducing charging header flow. The reactor operator will need to take manual control of the controller and restore charging flow so that pressurizer level can be restored.

by-46\rev3 3

The 1B TDFWP Trips and the 1A MDFWP doesnt start to provide replacement feedwater flow. The crew will take actions per BOA SEC-1 to runback the Unit to 780 MW however the runback function on the turbine generator will not work so the crew will have to manually reduce turbine load.

The crew will not be able to maintain SG water levels and will have to trip the unit. This is the start of the major transient in which the reactor will not trip from the front panel 1PM05J. The reactor operator will have to use the alternate reactor trip switch located on 1PM06J. The turbine will also fail to trip and must be manually tripped using the trip pushbutton.

The reduction in feedwater results in lowering SG levels and a signal to automatically start the Aux. Feedwater Pumps.

The 1A AFW pump starts but trips on overcurrent immediately after its start. The 1B AFW will start and run for 1 minute and then trip. With no AFW pumps running once the crew transitions out of 1BEP-0, the crew should enter 1BFR - H.1.

The crew will need to initiate an RCS bleed and feed once SG wide range levels fall below 27% (43% adverse). The scenario will be terminated when feedwater flow is re-initiated to a hot dry SG.

by-46\rev3 4

SCENARIO SETUP GUIDE

- Initialize IC-22: "full power, steady state, equilibrium xenon, MOL."

- Lineup control boards.

- Place simulator in run (allow simulator to run during board walkdowns and turnover).

- Type bat a:/BY-46 and ensure the following insert:

- Perform TQ-BY-201-0113, Appendix A, Simulator Exam/ Scenario Reset Checklist EVENT TIME MALF NO. DESCRIPTION 1 0 N/A Perform Main Turbine Oil Checks per 1BGP 100-2 2 4 N/A Intermediate Range NI N-35 fails low 3 25  ???? Increase Rx Power to >10% or Decrease Rx Power to < P-6 4  ??  ???? S/G Steam Pressure Transmitter 1PT-544 fails low 5  ??  ????

6  ??  ????

7  ??  ????

8 9  ??  ????

10  ??  ????

by-46\rev3 5

INSTRUCTOR/SIMULATOR RUN AID GUIDE EVENT ADDITIONAL INFORMATION 1

Remote functions per event:

2 Remote functions per event:

EVENT 1 by-46\rev3 6

BRIEF DESCRIPTION Main Turbine Oil Checks per 1BGP 100-2 EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A (Cue)

Initial cue is to perform Main Turbine Oil Checks per 1BGP 100-2.

(Response)

• Refer to 1BGP 100-2, Plant Startup Crew

• Direct actions to perform step F.24 Main Turbine Oil Checks US

• BOP refers to 1BGP 100-2 step F.24 U-1 AST

• Stop 1TG06E, Turning Gear Motor and Ensure zero speed

• Place 1TO08P, Turbine Lift Oil Pps to OFF

• Place 1TO5P, Emergency Oil Pp in Auto(After-Trip)

• Place 1TO07P, Turbine Seal Oil Backup pump in Pull Out

• Place 1TO06P, Bearing Oil Pp in Auto (After-Trip)

• Place 1TO05P, Emergency Oil Pp in Pull Out.

Ensure that the Bearing Oil Pp starts at approx. 12 psig

• PLACE 1TO07P, Turb Seal Oil Backup Pp, in AUTO (AFTER-TRIP).

• PLACE 1TO06P, Bearing Oil Pump, in PULL OUT. ENSURE that the Turbine Seal Oil Backup Pp starts at approximately 12 psig.

• PLACE the switch for 1TO07P, Turbine Seal Oil Backup Pp, in the START (AFTER-CLOSE) position.

• START 1TO06P, Bearing Oil Pump. ENSURE bearing oil pressure is 14 - 18 psig.

• PLACE 1TO05P, Emergency Oil Pump, in AUTO (AFTER-TRIP).

NOTE:

This switch position is necessary to permit automatic stopping of the Bearing Lift Pumps when Main Turbine speed is increased above approximately 600 rpm.

• PLACE 1TO08P, Turbine Brng Lift Pps, in the AUTO position.

• VERIFY that the Main Turbine Shaft is not rotating, then START 1TG06E, Turning Gear Motor, per BOP TG-15.

• VERIFY 1TG06E, Turning Gear, GEAR ENGD light is ON and that the ZERO SPEED light goes OFF.

COMMENTS 2

by-46\rev3 7

BRIEF DESCRIPTION Intermediate Range NI N-35 becomes INOP (fails down scale)

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A (Cue)

Intermediate Range NI N-35 fails down scale.

(Response)

• Enter 1BOA INST-1 for N-35 failure US

• Check Power Range Permissive P-10 LIT RO

• Check IR Channels Only One Failed RO

• Check reactor power > 1x10-5% RTP (> P-6) RO

• Within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> the crew must RO

• Reduce Rx Pwr to < 1x10-5% RTP (< P-6) OR

• Raise Rx Pwr to > 10%

• Refer to Tech Specs 3.3.1 and 3.3.4 RO COMMENTS by-46\rev3 8

EVENT 3 BRIEF DESCRIPTION Increase Reactor Power to > 10% within the next 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Re-activity manipulation for this scenario.

(Cue) o Per Tech Spec 3.3.1 Cond. F (Response)

• Refer to BGP 100-3, Power Ascension CREW

• Direct actions to Raise Rx Pwr to > 10% US

• Pull control rods to increase Rx Pwr U-1

• Verify Steam Dump valves open in Steam Pressure U-1 AST Mode when Rx Pwr increases

• Maintain I on target U-1

• STOP Rx Pwr increase when > 10% US EXAMINERS NOTE: I control should start as early in the power range as practical. It is desirable to have I on target. This will help reduce the potential of a I transient. Controlling I at low power with CBC may lead to a I transient as the reactor is increased in power.

COMMENTS by-46\rev3 9

EVENT 4 BRIEF DESCRIPTION 1D S/G Steam Pressure Transmitter 1PT-544 fails low EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Recognize symptoms and respond to the failure of 1D S/G Steam Pressure Transmitter 1PT-544.

(Cue) o o

o (Response)

• Refer to 1BOA INST-2 US

• S/G Level Normal

• Place Feed Reg Valve in Manual U-1

• Verify adequate Feedwater P U-1

• Restore S/G Level to a stable condition U-1

• Locally Trip Bistables for Affected Channel

• 1PT-544 Lo Press SI / Stm Line Isol PB544B U-1

• 1PT-544 Hi Stm Rate Isol PB544A U-1

• Refer to Tech Specs 3.3.2 and 3.3.4 US COMMENTS by-46\rev3 10

EVENT 5 BRIEF DESCRIPTION Turbine Impulse Pressure Detector (1PT-505) Fails High.

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Recognize symptoms and respond to 1PT-505 failure (Cue) o Annunciator (1-14-D1) "TAVE CONT DEV HIGH" o Control rod outward motion o TREF rising on 1TR-0412 (Response)

Implement 1BOA ROD-1 "UNCONTROLLED ROD MOTION US and direct operator actions to establish the following conditions:

• Check turbine power stable U-1 AST

• Check Rod Control Status U-1

• Place Rod Control in manual

• Check Rod Control inputs U-1 AST

• Identify 1PT-505 failure Implement 1BOA INST-2 "OPERATION WITH A FAILED US INSTRUMENT CHANNEL" Attachment D and direct operator actions to establish the following conditions:

• Place rod control in MANUAL U-1

• Restore steam dumps U-1 AST

• 1PT-505 channel defeated U-1/U-1 AST

• Operator dispatched to trip bistable for 1PT-505 U-1

• Check TAVE-TREF deviation U-1

• Rod control returned to AUTO (NO auto withdrawal available) U-1

• Check ATWS Mitigation System U-1

• Trip AMS bistable

• Check P-13 interlock NOT lit U-1 AST

• Review Tech Spec 3.3.1, Rx Trip Instrumentation US/STA (Verify or place P-13 in required state in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />)

• Inform SM of unit status/EP potential US/STA

• Notify IM Dept. to investigate 1PT-505 failure US/STA

• Acknowledges failure report and performs EP eval SM EXAMINERS NOTE:

COMMENTS by-46\rev3 11

EVENT 6 BRIEF DESCRIPTION Letdown Heat Exchanger Temperature Control valve fails closed.

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Recognize symptoms and respond Main Feedwater Pump trip.

(Cue)

• Annunciator (1-8-C5) "LTDWN Hx OUTLET TEMP HIGH" (Response)

Implement BAR 1-8-C5

• U-1 RO will have to determine cause of problem U-1

• U-1 RO Takes Manual control of 1CC130A and Opens U-1 Control valve

• U-1 RO may have to re-align letdown flow through demins U-1 By placing 1CV129 into demin position and back to Auto by-46\rev3 12

EVENT BRIEF DESCRIPTION 1B SG Feedline Break Inside CNMT EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Recognize symptoms and respond to conditions requiring a Rx trip (Cue) o Cnmt pressure rising o 1B SG level dropping o Annunciator (1-15-B9) "S/G 1B LEVEL DEVIATION HIGH LOW" o 1B SG FW flow > steam flow o Annunciator (1-1-A2) "CNMT DRAIN LEAK DETECT FLOW HIGH" (Response)

Initiate a manual Rx trip/announce a Rx trip CREW Implement 1BEP-0 "REACTOR TRIP OR SI" US Immediate operator actions of 1BEP-0 establish the following conditions:

• Reactor is tripped U-1

• All rod bottom lights lit

• Rx Trip and Bypass breakers open

• Neutron flux dropping

• Turbine is tripped AST

• TVs closed

• GVs closed

• 4 KV ESF busses are energized AST

• Bus 141 energized

• Bus 142 energized

• SI Status

• SI is actuated/required CREW o SI ACTUATED permissive light lit o SI first out annunciator lit o SI equipment automatically actuated

• Actuate SI U-1/AST COMMENTS by-46\rev3 13

EVENT B (con't.)

BRIEF DESCRIPTION 1B SG Feedline Break Inside CNMT EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A

• FW isolated AST

• FW pumps tripped

• FWI monitor lights lit

• FW pump discharge valves closed (1FW002A-C)

• ECCS pumps running U-1

• CV pumps running

• RH pumps running

• SI pumps running

• RCFCs running in accident mode AST

• RCFC accident mode status lights lit

• CNMT Phase A valves closed AST

• Group 3 monitor lights lit

• CNMT VENT isolation valves closed AST

• Group 6 monitor lights lit

• AF pumps running AST

• AF pumps running

• 1AF013 valves open

• 1AF005 valves throttled

• CC pumps running AST

• SX pumps running AST

• Main Steamlines are isolated (1A MSIV does NOT close) U-1/AST

• Attempt to close 1A MSIV

• Containment Spray is not required AST

• Cnmt pressure < 20 psig

• Verify total AF flow AST

• > 500 gpm

• Control feed flow to maintain SG NR level between 10%(31%) - 50%

• No SG level rising in an uncontrolled manner (may identify rising level and isolate 1AF013A/E)

COMMENTS by-46\rev3 14

EVENT B (con't.)

BRIEF DESCRIPTION 1C SG Feedline Break Inside CNMT EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A

• ECCS valves aligned with flow U-1

• Group 2 cold leg injection monitor lights lit

• > 100 gpm on indicator 1FI-917

• Check at least 1 PZR PORV relief path available U-1

• Generator tripped AST

• Switch yard breakers open

• PMG breaker open

• Diesel Generators running AST * * *

• 1A Diesel Generator running

• • Attempt to start 1B Diesel Generator

• 1SX169A open

• Operator dispatched

• Ventilation aligned for emergency operation U-2 AST /AST

• PZR PORVs and spray valves closed U-1

• RCS temperature < 557°F U-1

• RCPs running U-1

• Inform SM of unit status/potential EP event US/STA Recognize symptoms and respond to a faulted steam generator in accordance with 1BEP-0 "REACTOR TRIP OR SAFETY INJECTION" (Cue) o 1B SG depressurizing in an uncontrolled manner o 1B SG is completely depressurized.

(Response)

Announcement of faulted steam generator symptoms CREW Transition to 1BEP-2 "FAULTED SG ISOLATION" US Coordinate/direct operator actions to: US

• Isolate/close MSIVs & MSIV bypass valves (1A MSIV open) AST

• Identify at least 1 non-faulted SG AST

• • Isolate 1C SG before transition out of 1BEP-2 US/AST * * *

• AF valves closed (1AF013B/F) o Main feedwater isolated o 1B SG PORV closed (1MS018B) o Blowdown isolation/sample valves closed (1SD002E/F, 1SD005C)

• Monitor AF pump suction pressure AST

• Transition to 1 BEP-1 LOSS OF REACTOR OR SECONDARY COOLANT Examiners Note: Crew may transition to BEP-3, SGTR, based on radiation monitor trends from BEP-2.

SGTR will occur when 1AF013C is closed.

by-46\rev3 15

EVENT C BRIEF DESCRIPTION SGTR - 1C SG (450 gpm)

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A Recognize and diagnose/respond to a SGTR in accordance with 1BEP-1 "LOSS OF REACTOR OR SECONDARY COOLANT" OAS (Cue) o 1C Steam Generator Level / Pressure rising in an uncontrolled manner (Response)

Announce indications of a SGTR CREW Transition from 1BEP-1 "LOSS OF REACTOR OR US SECONDARY COOLANT" to 1BEP-3 "SGTR"

• RCPs running U-1

• Identify the 1C SG as the ruptured SG and isolate US/AST * *

• prior to transition to 1BCA-3.1 o 1A SG PORV in auto and closed AST o 1SD002A & B closed AST o Attempt closure of 1A MSIV - MSLI AST o Main FW pump turbine HP stop valves closed AST o Steam dump valves closed AST

• 1MS067A-D and 1MS009A-D closed AST

• 1GS001 and 1GS004 closed AST

• 1MS107A and B closed (local operation) AST o 1B/1D SG PORVs used to stabilize RCS temp. at 557°F AST

• 1AF013A/E closed AST Examiners Note: Crew should not feed ruptured S/G if Narrow range level is < 10% (31% Adverse Cnmt).

• Check Ruptured S/G Pressure Greater than 320 psig U-1 Transition from 1BEP-3 SGTR to 1BCA-3.1, SGTR with Loss of Reactor Coolant Subcooled Recovery Desired.

COMMENTS by-46\rev3 16

EVENT C BRIEF DESCRIPTION SGTR - 1C SG (450 gpm)

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A

• Reset SI if Necessary U-1

• Depress both SI reset pushbuttons

• Verify SI Actuated permissive light NOT LIT

• Verify Auto SI Blocked permissive light LIT

• Reset Containment Isolation U-1

• Reset Cnmt Isol Phase A if necessary

• Reset Cnmt Isol Phase B if necessary

• Check SACs any running

• Open instrument air Cnmt Isol Valves

• Open 1IA065

• Open 1IA066

• Verify all AC Busses Energized by Offsite Power AST

• Bus 141

• Bus 156

• Bus 142

• Bus 157

• Bus 143

• Bus 158

• Bus 144

• Bus 159

• Check if CS should be Stopped AST

• CS pumps run lights LIT

• Reset CS signal

• Spray Add Tank Lo-2 Level lights LIT Examiners Note: Crew should not feed ruptured S/G if Narrow range level is < 10% (31% Adverse Cnmt).

• Check Ruptured S/G Level AST

• Narrow Range level > 10% (31%)

• Check if RH Pps should be Stopped U-1

• RCS pressure > 325psig (It will be)

• RCS pressure Stable or Rising (It will be)

• Stop RH Pps and place in standby COMMENTS by-46\rev3 17

EVENT C BRIEF DESCRIPTION SGTR - 1C SG (450 gpm)

EXPECTED OPERATOR/PLANT RESPONSE SAT UNSAT N/A

• Initiate Evaluation of Plant Status Crew

• Check Aux Bldg Radiation Trends

• Place Hydrogen Monitors in service per BOP PS-9

• Consult TSC for obtaining samples

• Evaluate equipment needed to assist in plant recovery

• At Shift Managers discretion prepare Hydrogen Recombiners to run per BOP OG-10

• Check if S/G Secondary Pressure Boundaries are Intact Crew

• No S/G Pressure Dropping in an Uncontrolled Manner

• No S/G Completely Depressurized

• Check Intact S/G Levels Crew

• Narrow range levels > 10%

• Control feed flow to maintain narrow ranges 18%-50%

• Initiate RCS Cooldown to 200oF Crew

• Maintain C/D rate in RCS Cold Legs < 100 oF / Hr

• Check PZR Pressure < 1930 psig P-11 LIT

• Block Steamline Isol Signal

• Dump Steam from Intact S/Gs to initiate a Cooldown Examiners Note: Crew should use Intact S/Gs to establish a 100 oF / Hr cooldown rate. Based on cold leg temperatures the crew may have already exceeded the 100 oF / Hr due to the SGTR.

TERMINATE SCENARIO COMMENTS by-46\rev3 18

• Classify conditions per minimum applicable EP US description

• SITE EMERGENCY

• FS-1

• Identify reportability requirements US

• SAF 1.1 - Declaration of an Emergency Class

• SAF 1.5 - ECCS Injection/Actuation

• SAF 1.6 - RPS actuation

• SAF 1.7 - System actuation not including RPS by-46\rev3 19