Text

Proposed Scenarios
	ML20054A536
Person / Time
Site:	Byron
Issue date:	12/16/2019
From:	Joseph Demarshall; Exelon Generation Co
To:	; NRC/RGN-III/DRS/OLB
	Demarshall J
Shared Package
ML17214A839	List: ML20054A024; ML20054A142; ML20054A158; ML20054A485; ML20054A536; ML20054A571; ML20054A653; ML20054A682; ML20054A700;
References
	Download: ML20054A536 (107)
	v • d • e

1 Facility: Byron_____________ Scenario No.: N19-1________

Op-Test No.: 2019-302_

Examiners: ___________________________ Operators:

Initial Conditions: 42% RTP, BOL, 1B CV Pump OOS for oil change; expected RTS in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

Turnover: Crew is directed to start 3rd CD/CB pump per BOP CD/CB-1, and raise power to 50% for calorimetric hold, IAW 1BGP 100-3. 1C Feedwater pump final clear in progress. 1B CV Pump is OOS for an oil change, expected RTS in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . Tech Spec 3.5.2 Condition A (ECCS trains) has been entered in addition to LCO 3.1.d. Condition A (Charging pumps-operating) 1BOL 5.2 and 1BOL 1.d have been initiated.

Event No.

Malf. No.

Event Type*

Event Description Preload ED050G OPEN CV Pp 1B Out of Service 1

None N - BOP N - SRO BOP starts 3rd CD/CB Pump IAW BOP CD/CB-1.

2 None R - ATC R - SRO Raise power to 50% per 1BGP 100-3. ATC will dilute and withdraw control rods IAW the ReMA.

3 RX010G 1300 30 I - BOP I - SRO TS - SRO S/G pressure transmitter 1PT-534 (controlling channel) fails high. Tech Specs 3.3.2 and 3.3.4 will be entered.

4 TH10B 100 30 C - ATC C - SRO 1PK-455C PZR Spray controller fails to full demand (1RY455C full open).

5 ZDI1CC685 CLS CC49 10 ZDI1CC685 AUTO C - BOP C - SRO TS - SRO 1CC685 spurious closure; valve can be successfully reopened, but will start to spuriously reclose and mechanically bind in an intermediate position. Tech Spec 3.6.3 will be entered.

6 CV01A C - ATC C - SRO TS - SRO 1A CV Pump trip (requires manual isolation of L/D, no seal injection or thermal barrier cooling, requires manual Rx trip) [TCA#35]

7 RP02A (preload)

RP02B (preload)

M - ALL Reactor Trip Breaker Fails To Open RTA Reactor Trip Breaker Fails To Open RTB Results in an ATWS (Rx fails to trip from either MCB C/S)

[CT-52]

2 8

ZAI1PK507 0 RP34 OUT (preload)

RP35 OUT (preload)

RP60 OUT (preload)

RP61 OUT (preload)

ZDI1HSMS103 STM_PRESS RP21A RP21B C - BOP C - SRO Uncontrolled RCS cooldown. Steam dumps controller fails high in auto.

Slave Relay K623 MS ISOL TRN A Slave Relay K616 MS ISOL TRN A Slave Relay K623 MS ISOL TRN B Slave Relay K616 MS ISOL TRN B Stm Dump Cont. Mode Select Lo-Lo Tavg P-12 Fails to Actuate Train A Logic Lo-Lo Tavg P-12 Fails to Actuate Train B Logic (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

3 SCENARIO N19-1 OVERVIEW Scenario will start at approximately 42% RTP, BOL, steady state, with 1BGP 100-3, POWER ASCENSION, in progress at Step F.52. The 1B CV pump is OOS for an oil change and will be returned to service in approximately 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . LCOAR 3.5.2 Cond A and TLCO 3.1.d Cond A have been initiated. Online risk is green.

Event 1:

The crew will place the 3rd CD/CB pump in service per BOP CD/CB-1.

Event 2:

The crew will then continue power ascension raising power to 50% to perform a calorimetric hold. The crew may desire to continue placing a 2nd HD pump in service due to a rising Heater Drain Tank level, however, prior to the crew taking action to place the 2nd HD pump in service, insert Event 3.

Event 3:

The crew will identify a failure of S/G pressure transmitter 1PT-534 (controlling channel) failing high and take prompt operator action per BHC 1-SG. The crew should hold the ramp at this time as the crew will take 1C S/G FRV to manual and stabilize 1C S/G level. The crew will take follow-up actions per 1BOA INST-2 and select an operable controlling channel. The crew should enter LCO 3.3.2 Cond A and D (functions 1.e and 4.d.1) and LCO 3.3.4 Cond A (function 6).

1PT-534 will remain unavailable for the remainder of the scenario. At lead examiner discretion, insert Event 4.

Event 4:

The crew will identify a failure of 1PK-455C PZR spray controller in Auto (valve fails full open). The crew will take prompt action per BAR 1-12-C1 or BHC 1-RY-P to stabilize PZR pressure. The crew may enter LCO 3.4.1 Cond A if RCS pressure drops below 2209 psig. 1PK-455C will remain non-functional in auto for the remainder of the scenario. At lead examiner discretion, insert Event 5.

Event 5:

The crew will identify 1CC685 spurious closure by the valve indicating lights or by status light, GRP6 6.2, as well as rising RCP temperatures due to a loss of thermal barrier cooling. The crew should reference BAR 1-7-A4 through D4 for RCP 1_ Therm Barr CC Wtr Flow Low due to 1CC685 failing closed. The crew should attempt to reopen 1CC685 IAW BAR 1-7-A4 through D4. The valve will reopen at this time and clear the thermal barrier low flow alarms. After flow is restored, the crew will identify that 1CC685 has failed to an intermediate condition (sufficient enough to again bring in all four RCP thermal barrier CC flow low alarms). If the crew attempts to close or open the valve, the valve will not move (mechanically bound). The crew should enter LCO 3.6.3 Cond A due to 1CC685 being not fully closed and not being able to fully close the valve. The crew will take action per required action A.1 to manually close and de-energize 1CC9438 to isolate the flowpath within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . The crew may opt to enter 1BOA PRI-6, Component Cooling Malfunction and/or 1BOA RCP-2, Loss of Seal Cooling. At lead examiner discretion, insert Event 6.

Event 6:

The crew will identify a trip of the 1A CV pump. The crew will take prompt action to isolate normal letdown IAW BHC 1 A3. The crew may enter LCO 3.0.3 for LCO 3.5.2 NOT met (neither CV pump operable and 100% ECCS flow equivalent is NOT available to a single OPERABLE ECCS train) and shut the plant down to Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . However, prior to shutting down the RCPs, the crew should exercise 1BOA RCP-2, Step 1 RNO to manually trip the reactor, verify the reactor tripped, and then trip all RCPs, as no seal injection is available and RCP thermal barrier low flow alarms are lit.

Event 7:

The crew will attempt to manually trip the Rx, which will fail from both MCB switches. The crew will enter 1BFR S.1.

RCPs should not be tripped until the reactor power is < 5%, per 1BFR S.1. The crew will be unable to emergency borate per 1BFR S.1 step 4. When the reactor is tripped locally or power is < 5%, the crew should transition to 1BEP-0 and trip all RCPs.

4 Event 8 The crew will identify an uncontrolled RCS cooldown in progress by Step 10 of 1BEP-0. The MSIVs will fail to automatically Close and the steam dump controller will fail high, causing excessive steam dumps to be open. The crew should terminate the excessive cooldown by isolating MSIVs or by taking the steam dump controller to manual and closing the steam dumps to mitigate the uncontrolled cooldown.

The scenario will be terminated after the crew has mitigated the uncontrolled cooldown.

Critical Tasks:

CT-52: Insert negative reactivity into the core by inserting control rods at > 48 steps/minute prior to dispatching operators to locally trip the reactor.

(K/A number - EPE 029-EA1.14; importance 4.2/3.9)

TCA #35: Trip RCPs within 10 minutes of loss of CC (UFSAR 7.3.2.3) (K/A: APE 015/017-AA1.06; importance - 3.1/2.9)

5 SIMULATOR SETUP GUIDE:

Verify/perform TQ-BY-201-0113, Appendix A, Simulator Ready for Training Checklist.

Establish the conditions of IC 171, 42% power, BOL, equilibrium xenon Place Simulator in RUN Initiate Smart Scenario:

o Open SMART SCENARIO (Extreme Ace icon) o Open file Scenario N192-1.ssf o

Load Initial values for instrument failures o

Event 3, 1PT-534 failure high o

Event 4, 1PK-455C PZR Spray controller fails high o

Click on the MODE button (near top of screen) and pick EXECUTE o

Click on the PLAY button (bottom left of screen)

Verify the following are included in the Smart Scenario:

6 Ensure Steam Flow Channel F-532 selected as controlling SF channel for 1C Steam Generator Place the following control switches in PTL:

1B CV Pp Place clearance order INFO/CAUTION tags on the following COMPONENTS:

1B CV Pp C/S 1C Feedwater Pump Place Protected Equipment placards on the following control switches:

1A CV Pp Set AB Pot to 3.74 for 952 ppm boron Ensure REMA is available at the Unit Desk Provide marked-up copies of the following documents:

1BGP100-3T1, POWER ASCENSION FLOWCHART 1BOL 5.2, LCOAR ECCS - OPERATING 1BOL 1.d, LCOAR CHARGING PUMP - OPERATING

7 Turnover Information Unit 1 is at 42% BOL 485 MWe RCS boron concentration is 952 ppm Control bank D @ 135 steps 1B CV pump is OOS for an oil change; it is expected back in service in six hours.

1BOL 3.5.2, ECCS Operating for Condition A has been initiated 1BOL 1.d, Charging Pumps - Operating for Condition A has been initiated Crew is to start 3rd CD/CB pump per BOP CD/CB-1 (1BGP100-3, step F.52)

When complete, continue power ascension and raise power to 48% for a calorimetric hold, IAW 1BGP 100-3, step F.55.

Online Risk is Green Protected Equipment:

1A CV Pump Unit 2 FC Train

8 INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1 BOP starts 3rd CD/CB Pump IAW BOP CD/CB-1 If contacted as EO to perform CD/CB pump pre-start checks and alignment per BOP CD/CB-1, report as requested:

proper lube oil levels are verified; lube oil pressure is 12psig; local checks and alignment per steps F.1.e through F.1.k are complete, pump is vented per F.1.l.

If contacted as Chemistry, acknowledge request to monitor Dissolved Oxygen (D.O.) at the secondary panel for up to 25 minutes.

If contacted as EO to perform CD/CB pump post-start checks and alignment per BOP CD/CB-1, report as requested:

speed reducer oil pressure is 28psig; lube oil pressure is greater than 6 psig Event 2 Raise power to 50% per 1BGP 100-3 Acknowledge as Power Team/SM initiation of ramp.

Event 3 S/G pressure transmitter 1PT-534 (controlling channel) fails high At Lead Evaluators cue, use Smart Scenario to fail 1PT-534 to 1300 psig over a 30 second period by right clicking on the box titled, 1PT534 failure high, and select, Release As SM/WEC acknowledge the failure, on line risk assessment, request for maintenance support, and IR requests.

Event 4 1PK-455C PZR Spray controller fails to full demand At Lead Evaluators cue, use Smart Scenario to fail 1PK-455C to 100% over a 30 second period by right clicking on the box titled, 1PK-455C PZR Spray Controller fails, and select, Release As SM/WEC acknowledge the failure, on line risk assessment, request for maintenance support, and IR requests.

Event 5 1CC685 spurious closure At Lead Evaluators cue, use Smart Scenario to fail 1CC685 by right clicking on the box titled, 1CC685 fails closed, and select, Release As SM/WEC acknowledge the failure, on line risk assessment, request for maintenance support, and IR requests.

As SM acknowledge 1BOA PRI-6 entry and to evaluate for EMERGENCY PLAN conditions.

AS EO, if requested to locally de-energize 1CC9438; acknowledge request. Request first check for 1CC9438 breaker at MCC131X2 cubicle D4, then use Smart Scenario to de-energize 1CC9438 by right clicking on the box titled, Remove Power from 1CC9438, and select, Release

9 Event 6 1A CV Pump trip At Lead Evaluators cue, use Smart Scenario to trip 1A Charging Pump by right clicking on the box titled, 1A CV Pump trip, and select, Release Event 7 ATWS (Rx fails to trip from either MCB C/S)

As EO, acknowledge request for local trip of Reactor Trip Breakers. After the crew has directed the performance of step 6.RNO in 1BFR-S.1 to locally Trip the Reactor; use Smart Scenario to locally Trip the Reactor by right clicking on the box titled, Open Rx Trip Bkrs, and select, Release. Report breaker opening to MCR.

As SM acknowledge procedure entry and to evaluate for EMERGENCY PLAN conditions.

Event 8 Uncontrolled RCS cooldown As SM acknowledge procedure entry and to evaluate for EMERGENCY PLAN conditions.

10 Op-Test No.: 2019-302 _

Scenario No.: _N19-1_

Event No.: _ 1__

Event

Description:

BOP starts 3rd CD/CB Pump IAW BOP CD/CB-1 Time Position Applicants Actions or Behavior CUE Directed at turnover to start 3rd CD/CB pump per BOP CD/CB-1 BOP VERIFY/PLACE Stby Pp Selector Switch to OFF, at 1PM03J CONTACT EO to perform CD/CB pump pre-start checks and alignment per BOP CD/CB-1 VERIFY/START the Lube Oil Pump at PM03J for the selected CD/CB Pump CHECK OIL PRESS UP light LIT at Aux Oil Pump Control Switch on 1PM03J o

NOTIFY Chemistry to monitor Dissolved Oxygen (D.O.) at the secondary panel for up to 25 minutes PLACE 1CB113C/D, CB Recirc Vlv, C/S in OPEN for the pump being started and ENSURE it OPENS START 1CD05PC/D, 1CD/CB Pump C/D, at 1PM03J.

VERIFY/PLACE 1CB113C/D, CB Recirc Vlv, C/S in AUTO for the pump that was started CONTACT EO to perform CD/CB pump post-start checks and alignment per BOP CD/CB-1 PLACE the Lube Pump control switch for the CD/CB Pump that was started in the AFTER-TRIP position o

TREND the motor and pump temperatures and COMPARE them to the parameters listed in the Limitations and Actions US Directs BOP to perform the start of the 3rd CD/CB Pump per BOP CD/CB-1 o

Acknowledges the start of CD/CB pump EVALUATOR NOTE:

After start of the 3rd CD/CB Pump the crew should proceed with the next event.

11 Op-Test No.: 2019-302 _

Scenario No.: _N19-1_

Event No.: _ 2__

Event

Description:

Raise power to 50% per 1BGP 100-3 Time Position Applicants Actions or Behavior CUE Directed at turnover to continue power ascension and raise power to 50% for a calorimetric hold.

US Direct Power ascension per turnover.

Implement actions of 1BGP 100-3, POWER ASCENSION to raise power to 50%

per step F.55.

o Perform pre-job brief per OP-BY-101-0001 ATTACHMENT 9 REACTIVITY CHANGE BRIEF SHEET for load ramp.

ATC Verify rod position and boron concentration.

Conducts reactivity brief Initiate dilution IAW ReMA and BOP CV-5 or BOP CV-5T1 Select STOP on RMCS Makeup Control Switch Select DIL or ALT DIL on RMCS Mode Select Switch o

Enter desired flowrate o

Verify Prescaler set to 1.0 o

Reset PW/ Total Flow counter Enter desired dilution amount in PW counter Place RMCS Makeup Control Switch to START o

Verify 1CV110B OPEN if in ALT DIL Verify 1CV111A and B OPEN Verify proper PW flow on flow recorder 1CD-CX4102 Monitors effects of dilution Turn on PZR backup heaters.

BOP Raise turbine load at 1PM02J or OWS drop 210 by performing the following:

Select SETPOINT.

Enter ~2.2 MW/min into the RATE window.

Select ENTER.

Enter ~620 MW into REF DEMAND window.

Select ENTER.

Select EXIT.

o Notify US and RO of pending ramp.

Select GO/HOLD.

Verify GO/HOLD button illuminates.

Verify HOLD illuminated RED.

Select GO.

Verify GO illuminates RED.

Verify main turbine load begins to rise.

o When actual turbine load (Q2800A) reaches approximately 620 MW VERIFY/HOLD ramp.

12 Op-Test No.: 2019-302 _

Scenario No.: _N19-1_

Event No.: _ 2__

Event

Description:

Raise power to 50% per 1BGP 100-3 Time Position Applicants Actions or Behavior ATC Monitor reactor power and load ascension:

Monitor NIs, Tave, I, Pzr press/level.

During dilution, monitor the following at 1PM05J and HMI:

VCT level.

RCS Tave rising/RCS boron concentration lowering.

PW/Total flow counter responding correctly.

Verify dilution auto stops at preset value.

o Return Reactor Makeup System to automatic.

o Withdraw control rods per ReMA.

EVALUATOR NOTE:

After measurable change in power and with lead examiners concurrence, initiate the next event.

13 Op-Test No.: 2019-302 _

Scenario No.: _N19-1_

Event No.: _ 3__

Event

Description:

S/G pressure transmitter 1PT-534 (controlling channel) fails high Time Position Applicants Actions or Behavior CUE:

Annunciators:

o 1-15-C3 S/G 1C FLOW MISMATCH STM FLOW LOW 1-15-C4 SG 1C FLOW MSMATCH FW FLOW LOW o

1-15-C9 S/G 1C LEVEL DEVIATION HIGH LOW 1C SG steam pressure indication off-scale high on 1PT534A 1C SG steam flow rising 1C SG feedwater flow rising 1B FW Pump Speed rising 1C SG Level rising BOP/US o

Address 1-15-C9 Alarm response Identify/report failure of 1PT-534A, 1C steam generator steam pressure channel.

Implement BHC 1-SG, STEAM GENERATOR LEVEL Take Manual control feed flow to 1C SG.

Adjust feedwater flow to pre-failed value Check 1C SG level, steam flow, feed flow, and determine failed input.

Select operable steam flow channel o

Determine impact on FW pump speed controller and place in manual US Enter and direct actions of 1BOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL Attachment F Notifies SM of BOA entry Requests Emergency Plan evaluation Orders ramp to HOLD BOP Check affected SG level:

o Determine SG level not normal Take manual control of 1FW530 M/A station and restore SG level to normal o

Take manual control of 1SK-509A M/A station to maintain MFPs speed to maintain MFRV D/P Select an operable steam flow channel Restore Automatic level control o

Restore Automatic MFP speed control ALL o

Identify/flag TSLB lights associated with failed channel Identify/flag failed channel o

Request operator to locally trip bistables for the affected channel

14 Op-Test No.: 2019-302 _

Scenario No.: _N19-1_

Event No.: _ 3__

Event

Description:

S/G pressure transmitter 1PT-534 (controlling channel) fails high Time Position Applicants Actions or Behavior US (RF 6a) Recognize malfunction of TS Related Instrumentation (RF 6b) Locate/Determine Applicable LCOs LCO 3.3.2 Engineered Safety Feature Actuation System Instrumentation Function 1, Safety Injection

e. Steam Line Pressure-Low Function 4, Turbine Trip and Feedwater Isolation

d. Steam Line Pressure

1) Low LCO 3.3.4 Remote Shutdown System Function 6, Steam Generator Pressure (per SG)

(RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME LCO 3.3.2, CONDITION A - One or more Functions with one or more required channels or trains inoperable o

A.1 RA - Enter the Condition referenced in Table 3.3.2-1 [CONDITION D]

CT - Immediately LCO 3.3.2 CONDITION D - One channel inoperable o

D.1 RA - Place channel in trip CT - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR o

D.2.1 RA - Be in Mode 3 CT 78 - hours AND o

D.2.2 RA - Be in Mode 4 CT - 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months LCO 3.3.4 CONDITION A - One or more required Functions inoperable o

A.1 RA - Restore required Function to OPERABLE status CT - 30 days US Notify SM of plant status, request IR and maintenance notification and risk evaluation o

Considers recommencing ramp ATC Monitor plant response to FW transient and take actions directed by the US EVALUATOR NOTE:

After the actions for the 1PT-534 failure are complete, and with the lead examiners concurrence, initiate the next event.

15 Op-Test No.: 2019-302 _

Scenario No.: _N19-1_

Event No.: _ 4__

Event

Description:

1PK-455C PZR Spray controller fails to full demand Time Position Applicants Actions or Behavior CUE PZR pressure is lowering 1RY455C OPEN light is LIT 1RY455C CLOSED light is NOT LIT 1RY455B OPEN light is NOT LIT 1RY455B CLOSED light is LIT 1PK-455A Master PZR Press Controller demand rising o

Annunciator PZR PRESS CONT DEV LOW HTRS ON (1-12-C1) is LIT ATC Identify 1RY455C is OPEN Perform action of Hard Card BHC 1-RY-P Place 1PK-455C in manual and reduce demand to 0 Adjust PZR pressure to pre-failed value Monitor PZR pressure US Monitor NSO prompt actions using BHC 1-Summary Notify SM of plant status, request IR and maintenance notification and risk evaluation EVALUATOR NOTE:

Tech Spec 3.4.1 only applicable if pressure lowers to <DNB limits of 2209 psig)

US (RF 6a) Recognize operation outside of TS Related parameters (RF 6b) Locate/Determine Applicable LCOs LCO 3.4.1 RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME CONDITION A, One or more RCS DNB parameters not within limits o

A.1 RA - Restore RCS DNB parameter(s) to within limit CT - 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months BOP Assist with BAR response Monitor panels with failure in progress EVALUATOR NOTE:

After response to PZR spray valve failure is complete and with lead examiners concurrence, continue with the next event.

16 Op-Test No.: 2019-302 _

Scenario No.: _N19-1_

Event No.: _ 5__

Event

Description:

1CC685 spurious closure Time Position Applicants Actions or Behavior CUE Annunciators:

1-7-E4 RCP THERM BARR CC WTR FLOW HIGH LOW 1-7-A/B/C/D4 RCP 1A/B/C/D THERM BARR CCWTR FLOW LOW 1CC685 CLOSED BOP Ensure 1CC9413A, 1CC9413B, 1CC685 and 1CC9438 are fully OPEN.

OPEN 1CC685 Determine 1CC685 opened then returned to an intermediate position and cannot be further manipulated US Monitor/Direct NSO actions using BARs and 1BOA PRI-6 Notify SM of plant status, request IR and maintenance notification and risk evaluation Notify SM of 1BOA PRI-6 entry and to evaluate for EMERGENCY PLAN conditions.

BOP Implement 1BOA PRI-6, COMPONENT COOLING MALFUNCTION MONITOR RCP SEAL COOLING:

o Seal injection flow to all RCPs - AVAILABLE o

RCP seal outlet temperatures - LESS THAN 235°F o

RCP lower bearing temperatures - LESS THAN 225°F CHECK CC SURGE TANK LEVEL:

o Surge tank level - GREATER THAN 13% and STABLE CHECK CC SYSTEM STATUS:

o CC pumps - AT LEAST ONE RUNNING o

CC PUMP DSCH PRESS LOW (1-2-B5) - NOT LIT CHECK CC SYSTEM TEMPERATURE o

Check CC PUMP SUCT TEMP HIGH (1-2-D5) - NOT LIT o

CC HX outlet temperature - LESS THAN 120°F o

CC HX outlet temperature - LESS THAN 105°F CHECK RCP COOLING o

Unit in Mode 1 o

Any RCP in operation CC flow to RCPs - NOT NORMAL RCP THERM BARR CC WTR FLOW LOW (1-7-_4) LIT RCP THERM BARR CC WTR FLOW HIGH LOW (1-7-E4) LIT Verify CC to RCP isol valves OPEN 1CC9413A 1CC9413B Verify CC from RCP isol valves OPEN 1CC9414 1CC9416

17 Op-Test No.: 2019-302 _

Scenario No.: _N19-1_

Event No.: _ 5__

Event

Description:

1CC685 spurious closure Time Position Applicants Actions or Behavior 1CC94138 Check CC HX outlet rad monitor trends - NORMAL Check RCP thermal Barrier Isol valve 1CC685 OPEN OPEN(attempt) 1CC685 Determine CC Surge Tank level - Stable between 50 and 65%

CHECK FOR INLEAKAGE FROM RCP THERMAL BARRIER Check RCP THERM BARR CC WTR FLOW HIGH LOW (1-7-E4) LIT Check Seal Injection - BETWEEN 8 GPM and 13 GPM PER PUMP Determine 1CC685 - NOT CLOSED Close 1CC685 Determine 1CC685 - Can NOT be CLOSED Close 1CC9438 Check CC Surge Tank level - Stable between 50 and 65%

US (RF 6a) Recognize operation outside of TS Related parameters (RF 6b) Locate/Determine Applicable LCOs LCO 3.6.3 Containment Isolation Valves (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME CONDITION A - One or more penetration flow paths with one containment isolation valve inoperable except for purge valve leakage not within limit o

A.1 RA - Isolate the affected penetration flow path by use of at least one closed and de-activated automatic or remote manual valve, closed manual valve, blind flange, or check valve with flow through the valve secured CT - 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months AND o

A.2 RA - Verify the affected penetration flow path is isolated CT - Once per 31 days for isolation devices outside containment AND Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment US/ATC o

CLOSE 1CC9438 o

Dispatch EO to locally de-energize 1CC9438 EVALUATOR NOTE:

After the actions for the 1CC685 spurious closure are complete and with lead examiners concurrence, insert the next event.

18 Op-Test No.: 2019-302 _

Scenario No.: _N19-1_

Event No.: _ 6__

Event

Description:

1A CV Pump trip Time Position Applicants Actions or Behavior CUE:

All CV pumps tripped Annuciators:

1-9-A3 CHG PUMP TRIP 1-9-D3 CHG FLOW HIGH LOW 1-7-B2 RCP SEAL WTR INJ FLOW LOW ATC Identify/report loss of all CV pumps Identify/report loss of all RCP seal cooling o

VERIFY/CLOSE 1CV8149A, B & C, Letdown Orifice Valves o

CLOSE 1CV459 Letdown Line Isol Valve.

o CLOSE 1CV460 Letdown Line Isol Valve EVALUATOR NOTE:

Due to scenario progression from loss of second CV pump to an ATWS event, Technical Specifications determination may be required as a follow-up question.

US (RF 6a) Recognize malfunction of TS Related Instrumentation (RF 6b) Locate/Determine Applicable LCOs LCO 3.0.3, When an LCO is not met and the associated ACTIONS are not met, an associated ACTION is not provided, or if directed by the associated ACTIONS, the unit shall be placed in a MODE or other specified condition in which the LCO is not applicable.

(RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME CONDITION - LCO 3.5.2 NOT met RA - Action shall be initiated within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to place the unit, as applicable, in:

RA - MODE 3 CT - within 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months RA - MODE 4 CT - within 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months RA - MODE 5 CT - within 37 hours4.282407e-4 days 0.0103 hours 6.117725e-5 weeks 1.40785e-5 months EVALUATOR NOTE:

Crew may attempt to trip the reactor and subsequently RCPs utilizing BAR 1 A3 NOTE: The RCPs are required to be IMMEDIATELY tripped following a loss of all seal cooling US Implement 1BOA RCP-2, LOSS OF SEAL COOLING, and directs operator actions.

Notifies SM of 1BOA RCP-2 entry.

Requests Emergency Plan evaluation

19 Op-Test No.: 2019-302 _

Scenario No.: _N19-1_

Event No.: _ 6__

Event

Description:

1A CV Pump trip Time Position Applicants Actions or Behavior ATC Determines Seal injection flow - is NOT AVAILABLE Determines RCP 1A/B/C/D THERM BARR CC WTR FLOW LOW alarms (1 A4/B4/C4/D4) - are LIT Attempts to manually Trip the reactor 1PM05J 1PM06J EVALUATOR NOTE:

Crew will be directed to trip the reactor, verify immediate actions per 1BEP-0 and to subsequently trip reactor coolant pumps. When it is determined that the reactor cannot be tripped, the crew will transition to 1BFR-S.1 and the RCPs will be tripped when reactor power is less than 5%.

ATC Attempts to manually Trip the reactor 1PM05J 1PM06J US Implement 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, and directs operator actions.

Notifies SM of 1BEP-0 entry.

Requests Emergency Plan evaluation.

ATC Verify Reactor Trip o

Rod bottom lights - ALL LIT o

Reactor trip & Bypass breakers - OPEN o

Neutron flux DROPPING Determines the Reactor did NOT TRIP Manually trip the reactor 1PM05J 1PM06J CREW Transition to 1BFR-S.1, RESPONSE TO NUCLEAR POWER GENERATION/ATWS EVALUATOR NOTE:

Crew actions of 1BFR-S.1 continue on next page.

20 Op-Test No.: 2019-302 _

Scenario No.: _N19-1_

Event No.: _ 7 & 8__

Event

Description:

ATWS (Rx fails to trip from either MCB C/S) & Uncontrolled RCS cooldown Time Position Applicants Actions or Behavior EVALUATOR NOTE:

Actions for 1BFR-S.1, RESPONSE TO NUCLEAR POWER GENERATION/ATWS, begin on this page.

US Notify SM of plant status and procedure entry Request evaluation of Emergency Plan conditions Enter/Implement 1BFR-S.1 and direct operator actions of 1BFR-S.1 EVALUATOR NOTE:

RCPs should NOT be tripped with reactor power greater than 5%.

Manual SI actuation at this time, would result in possible loss of heat sink due to feedwater isolation while Reactor is at power.

EVALUATOR NOTE:

Control rods may be placed back to AUTO after the turbine is tripped and will insert automatically. When rod speed lowers to less than 48 steps per minute action will be required to manually insert control rods.

[CT]

ATC

[CT-52]

Perform immediate operator actions of 1BFR-S.1:

VERIFY REACTOR TRIP Rod bottom lights - LIT Determines Rod Bottom lights are Not LIT Reactor trip & Bypass breakers - OPEN Determines Reactor Trip Breakers are Not OPEN Determines Neutron flux - NOT DECREASING Manually trip the reactor 1PM05J 1PM06J Identifies when control rods control are NOT inserting automatically at greater than or equal to 48 steps per minute Manually insert control rods at greater than or equal to 48 steps per minute BOP Perform immediate operator actions of 1BFR-S.1 VERIFY TURBINE TRIP All Turbine throttle valves - CLOSED All Turbine governor valves - CLOSED BOP CHECK AF PUMPS RUNNING AF pump run lights status (May be LIT or NOT LIT) o Manually start the 1A AF pump if it did not yet have an auto start signal.

o Manually start the 1B AF pump if it did not yet have an auto start signal.

ATC/BOP INITIATE EMERGENCY BORATION OF THE RCS CV pumps - Determines NONE RUNNING No pump can be started BOP VERIFY CNMT VENTILATION ISOLATION Group 6 CNMT vent isolation monitor lights - LIT

21 Op-Test No.: 2019-302 _

Scenario No.: _N19-1_

Event No.: _ 7 & 8__

Event

Description:

ATWS (Rx fails to trip from either MCB C/S) & Uncontrolled RCS cooldown Time Position Applicants Actions or Behavior EVALUATOR NOTE:

The Reactor will be Tripped locally during the performance of the next step when directed.

ATC/BOP CHECK IF THE FOLLOWING TRIPS HAVE OCCURRED Reactor Trip Determines Reactor Trip has NOT occurred.

Dispatch operator to locally trip reactor Turbine Trip All Turbine governor valves - CLOSED All Turbine throttle valves - CLOSED ATC CHECK IF REACTOR IS SUBCRITICAL PR channels - LESS THAN 5%

IR channels - NEGATIVE STARTUP RATE EVALUATOR NOTE:

When reactor power is verified less than 5%, actions for loss of seal cooling per 1BOA RCP-2 to Trip RCP(s) may be performed.

[CT]

ATC

[TCA#35]

Manually trip RCP(s).

CREW Transition to 1BEP-0, REACTOR TRIP OR SAFETY INJECTION EVALUATOR NOTE:

Crew actions of 1BEP-0 continue on next page.

22 Op-Test No.: 2019-302 _

Scenario No.: _N19-1_

Event No.: _ 7 & 8__

Event

Description:

ATWS (Rx fails to trip from either MCB C/S) & Uncontrolled RCS cooldown Time Position Applicants Actions or Behavior EVALUATOR NOTE:

Actions for 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, begin on this page.

US Implement 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, and directs operator actions.

Notifies SM of 1BEP-0 entry.

Requests Emergency Plan evaluation.

ATC Verify Reactor Trip Rod bottom lights - ALL LIT Reactor trip & Bypass breakers - OPEN Neutron flux DROPPING BOP Verify Turbine Trip Turbine throttle valves - CLOSED Turbine governor valves - CLOSED BOP Verify power to 4KV busses Bus 141 - ENERGIZED Bus 142 - ENERGIZED ATC Check SI status SI actuated SI First OUT annunciator lit (1-11-B1, 1-11-C1, 1-11-D1, 1-11-E1)

SI ACTUATED lit (1-BP-4.1)

SI Equipment running (SI pumps running, CV Cold leg injection SI8801A/B open)

Determine if SI required:

o Check PZR pressure < 1829 psig o

Check Steamline pressure < 640 psig o

Check CNMT pressure > 3.4 psig If SI is required:

Actuate SI from both SI switches (1PM05J and 1PM06J) and continue in 1BEP-0 US Directs BOP to perform Attachment B, SI VERIFICATION of 1BEP 0.

EVALUATOR NOTE:

Crew actions of 1BEP-0 continue below.

BOP actions of 1BEP-0, Attachment B continue on page 24.

23 Op-Test No.: 2019-302 _

Scenario No.: _N19-1_

Event No.: _ 7 & 8__

Event

Description:

ATWS (Rx fails to trip from either MCB C/S) & Uncontrolled RCS cooldown Time Position Applicants Actions or Behavior ATC/BOP Verify AF system:

AF pumps - BOTH RUNNING AF isolation valves 1AF13A-H - OPEN AF flow control valves 1AF005A-H - THROTTLED AF flow - GREATER THAN 500 GPM Check SG tubes intact:

Secondary radiation level - NORMAL AND STABLE Narrow range levels - NOT RISING IN AN UNCONTROLLED MANNER ATC/BOP Check PZR PORVs and Spray Valves PORVs - CLOSED PORV isol valve - at least one ENERGIZED PORV relief path - at least one AVAILABLE PORV in - AUTO Isol valve - open Normal spray valves - CLOSED ATC/BOP ADJUST AF FLOW:

Lower total Feed Flow to approximately 600 gpm EVALUATOR NOTE:

Crew may recognize that steam dumps are failed open and take action to close them.

ATC/BOP Check steam dumps - AVAILABLE C-9 Permissive light - NOT LIT CW Pump - AT LEAST ONE RUNNING EVALUATOR NOTE:

MSIVs may have been previously closed while performing 1BEP-0, attachment B, step 9.

ATC/BOP Control RCS Temperature per table:

Stop dumping steam If cooldown continues, Reduce/Stop Feed Flow If cooldown continues, close MSIVs

[CT]

ATC/BOP

[TCA#35]

Check if RCPs should be stopped:

All RCPs - ALL RUNNING.

Manually trip RCP(s) due to loss of seal cooling.

EVALUATOR NOTE:

The scenario will be terminated after the crew has mitigated the uncontrolled cooldown and taken actions to trip the RCP(s).

24 Op-Test No.: 2019-302 _

Scenario No.: _N19-1_

Event No.: _ 7 & 8__

Event Description ATWS (Rx fails to trip from either MCB C/S) & Uncontrolled RCS cooldown Time Position Applicants Actions or Behavior EVALUATOR NOTE: 1BEP-0, Attachment B, SI VERIFICATION actions begin on this page.

BOP Attachment B action Verify ECCS pumps running CENT CHG pumps - Identifies None Running RH pumps SI pumps BOP Attachment B action Verify ECCS valve alignment Group 2 Cold Leg Injection monitor lights lit BOP Attachment B action Verify ECCS flow HHSI flow >100 gpm - Identifies zero flow due to No CV pumps are running RCS pressure NOT <1700 psig If RCS pressure <1700 psig check SI pp flow > 200 gpm BOP Attachment B action Verify RCFCs running in Accident Mode - Group 2 RCFC Accident Mode status lights lit Verify CNMT isolation Phase A - Group 3 CNMT isolation monitor lights lit Verify CNMT Ventilation isolation - Group 6 CNMT Vent Isol monitor lights lit Verify CC Pumps running Verify SX Pump running Check if Main Steamline Isolation is required Check SG pressure < 640 psig o

Check CNMT pressure > 8.2 psig Determines MSIVs and MSIV Bypass valves are NOT closed Manually actuate Main Steamline Isolation Verify MSIV and MSIV bypass valves are closed Check if CS is required (NOT required)

BOP Attachment B action Verify FW isolated FW pumps tripped FW isolation monitor lights lit FW pumps discharge valves closed 1FW002A-C Trip all running HD pumps

25 Op-Test No.: 2019-302 _

Scenario No.: _N19-1_

Event No.: _ 7 & 8__

Event Description ATWS (Rx fails to trip from either MCB C/S) & Uncontrolled RCS cooldown Time Position Applicants Actions or Behavior BOP Attachment B action Verify both DGs running SX valves open 1SX169A and B Dispatch operator locally to check operation BOP Attachment B action Verify Generator Trip GCB 3-4 and OCB 4-5 open PMG output breaker open BOP Attachment B action Verify Control Room ventilation aligned for emergency operations:

Control Room Outside Air Intake radiation monitors < High Alarm setpoints Operating VC train equipment running Train A Supply fan Return fan M/U fan Chilled water pump MCR chiller 0A Operating VC train dampers M/U fan outlet damper NOT full closed 0VC24Y VC train M/U filter light LIT Operating VC train Charcoal Absorber aligned for train A 0VC43Y closed 0VC21Y open 0VC22Y open Operating VC train M/U filter alignment:

0VC25Y - open 0VC312Y-closed Control Room pressure greater than +0.125 inches water on 0PDI-VC038 BOP Attachment B action Verify Auxiliary Building ventilation aligned Two inaccessible filter plenums aligned Plenum A fan 0VA03CB running Damper 0VA023Y not fully closed Damper 0VA436Y closed Plenum C fan 0VA03CF running Damper 0VA072Y not fully closed Damper 0VA438Y closed Check Aux Building Supply and Exhaust fans One Exhaust Fan running for every Supply Fan running

26 Op-Test No.: 2019-302 _

Scenario No.: _N19-1_

Event No.: _ 7 & 8__

Event Description ATWS (Rx fails to trip from either MCB C/S) & Uncontrolled RCS cooldown Time Position Applicants Actions or Behavior BOP Attachment B action Verify FHB ventilation aligned Train B fan 0VA04CB running 0VA055Y open 0VA062Y not fully closed 0VA435Y closed BOP Attachment B action Maintain UHS Basin level > 80%

Initiate periodic checking of Spent Fuel Cooling Dispatch operator to locally check SFP level and temperature Notify Unit Supervisor of Manual actions taken Failed equipment status Attachment B completed CREW Attachment B action Shutdown unnecessary plant equipment As time allows refer to 1BGP 100-4T4, REACTOR TRIP POST RESPONSE GUIDELINE As time allows refer to 1BGP 100-5, PLANT SHUTDOWN AND COOLDOWN

1 Facility: Byron_____________ Scenario No.: N19-2________

Op-Test No.: 2019-302_

Examiners: ___________________________ Operators:

Initial Conditions: 100% RTP, MOL, steady state conditions.

Turnover: 100% RTP, MOL, steady state. Crew is directed to maintain power operations and perform 1BOSR FW-M4. 1B SI Pump OOS. Expected RTS in 26 hours3.009259e-4 days 0.00722 hours 4.298942e-5 weeks 9.893e-6 months . LCO 3.5.2 Cond A has been entered. 0B WS Pump is OOS. Expected RTS in 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . Severe weather is forecasted for the shift, currently no watches or warnings are in effect.

Event No.

Malf. No.

Event Type*

Event Description Preload ZDI1SI23B CLS ZLO1SI23B1 OFF ZLO1SI23B2 OFF ED050B OPEN ED052B OPEN SI Pump 1B Out of Service 1

None N - BOP N - SRO Perform 1BOSR FW-M4, 1A FW Pump AOP Test 2

RX13A 0 30 I - ATC I - SRO TS - SRO 1LI-459 PZR level instrument fails low (controlling channel) 3 RX10A 0 60 I - ATC I - BOP I - SRO TS - SRO 1PT-505, turbine impulse pressure channel fails low 4

RP 10B ZDI1SD005C OPEN (preload)

C - ATC C - BOP C - SRO TS - SRO Spurious Phase A Isolation, with a failure of 1SD005C to close 5

FW34A 3 60 C - BOP C - SRO 6A FW heater string leak (requires reducing turbine load in preparation for removing an intermediate pressure string from service per BOP HD-10) 6 None R - ATC R - SRO Ramp down < 1050 MW due to removing intermediate pressure FW heater string from service 7

TH06A 600 120 M - ALL SBLOCA inside containment [CT-16]

2 8

RP30A (preload)

RP26A (preload)

RP26B (preload)

RP26C (preload)

RP26D (preload)

RP26E (preload)

RP26F (preload)

RP26G (preload)

RP26H (preload)

C - ATC C - SRO A-Train SI, RH and AF pumps fail to automatically start (must manually start 1A SI pump) [CT-2]

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

3 SCENARIO N19-2 OVERVIEW Scenario will start at 100% RTP, MOL, steady state. Crew is directed to maintain power operations and perform 1BOSR FW-M4. 1B SI Pump OOS; expected RTS in 26 hours3.009259e-4 days 0.00722 hours 4.298942e-5 weeks 9.893e-6 months . LCO 3.5.2 Cond A has been entered. 0B WS Pump is OOS; expected RTS in 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . Severe weather is forecasted for the shift. Online risk is green.

Event 1 The crew will perform 1BOSR FW-M4, 1A FW Pump Aux Oil Pump Pressurization Test.

Event 2 The crew will identify a 1LI-459, controlling pressurizer level channel failing low. The crew will respond to rising pressurizer level and take manual control of the Master Pressurizer Level controller to stabilize pressurizer level at program. The crew would most likely take this action IAW BAR 1-12-B4. Additionally, the crew will identify automatic letdown isolation. The crew will enter 1BOA INST-2 to further address the failure, including selecting an operable controlling channel. The crew should enter LCO 3.3.1 Cond A & K (functions 9). The crew will re-establish letdown using BOA ESP-2. At the lead examiner discretion, continue to Event 3.

Event 3 The crew will identify a failure of 1PT-505, turbine impulse pressure channel failing low. The crew will take action per BHC 1-RD to stop the uncontrolled rod insertion (due to a false low Terror signal). The crew will implement 1BOA INST-2 and take followup actions to select an operable impulse pressure channel, place steam dumps in Steam Presssure Mode, and restore rods back to the pre-transient position. The crew will enter LCO 3.3.1 Cond A & P (functions 17b and 17e).

At lead examiner discretion, continue to Event 4.

Event 4 The crew will identify a Train B spurious phase A actuation and respond using 1BOA PRI-13. The crew will take make control of charging to minimize pressurizer level rise and will start available RCFCs in high speed. The crew will identify that 1SD005C failed to close on the actuation signal and enter LCO 3.3.2 Cond C (function 3a) and LCO 3.6.3 Cond C.

The crew will close 1SD005C to satisfy the TS requirement. At the lead examiner discretion, continue to Event 5.

Event 5 The crew will identify that a leak has occurred in the 6A intermediate pressure FW heating string, as evidence by BAR 1-17-B2, HTR 16 LEVEL HIGH LOW, and, subsequently cascading to, BAR 1-17-A2, HTR 16 LEVEL HI-2. The crew should take action to promptly initiate the HTR ISOL RUNBACK via DEHC in accordance with BAR 1-17-A2 to reduce turbine load to 1050 MW (Event 6). The crew should initiate action per BOP HD-10 to remove the 16A intermediate pressure FW heater string and determine per BOP HD-6T1, turbine load is limits.

Event 6 The crew will take action to reduce turbine load using the heater isolation runback via DEHC (see Event 5). At the lead examiner discretion, continue to Event 7.

Event 7 The crew will experience a SBLOCA. Degrading RCS pressure and level will exceed the capacity of a single charging pump. The crew may opt to enter 1BOA PRI-1, maximize charging and isolate letdown, however, this will prove incapable of mitigating the leak. The crew will trip the reactor, verify the reactor is tripped and actuate SI. The crew will enter 1BEP-0 and actuate SI. The crew will determine that A-train SI, RH and AF pumps fail to automatically start on the SI sequence.

(Event 8). The A-train SI pump must be manually started. It is critical that the 1A SI pump is started as the 1B SI pump is OOS. The crew will transition to 1BEP-1 and then to 1BEP ES-1.2.

Terminate the scenario when the crew has transitioned to 1BEP ES-1.2 Post-LOCA Cooldown and Depressurization.

4 Critical Tasks:

CT-16: Trip RCPs within 10 minutes of meeting RCP trip criteria.

(K/A number EPE 009-EA1.09; importance 3.6/3.6)

CT-7: Start Train A SI pump before transition to 1BEP-1.

(K/A number 006-A4.07; importance 4.4/4.4)

5 SIMULATOR SETUP GUIDE:

Verify/perform TQ-BY-201-0113, Appendix A, Simulator Ready for Training Checklist.

Establish the conditions of IC 182, 100% power, MOL, equilibrium xenon o

(IC-22 with 0B WS Pump Out of Service)

Ensure Stopwatch is available for performance of 1BOSR FW-M4, 1A FW Pump AOP Test Place Simulator in RUN Initiate Smart Scenario:

o Open SMART SCENARIO (Extreme Ace icon) o Open file Scenario N19-4.ssf o

Load Initial values for instrument failures o

Event 2, 1LI-459 failure low o

Event 3, 1PT-505 failure low o

Click on the MODE button (near top of screen) and pick EXECUTE o

Click on the PLAY button (bottom left of screen)

Verify the following are included in the Smart Scenario:

6 Place the following control switches in PTL:

1B SI Pp Place clearance order INFO/CAUTION tags on the following COMPONENTS:

1B SI Pp C/S PTL 1SI8923B C/S Closed 0B WS Pp C/S PTL Place Protected Equipment placards on the following control switches:

1A SI Pp 1SI8821A 1SI8823A 0A WS Pp 0C WS Pp Set AB Pot to 3.30 for 843 ppm boron Ensure MOL REMA is available at the Unit Desk Provide marked-up copies of the following documents:

1BOL 5.2, LCOAR ECCS - OPERATING Provide copies of the following documents:

1BOSR FW-M4, 1A FW PUMP AUX OIL PUMP PRESSURIZATION TEST

7 Turnover Information Unit 1 is at 100% MOL 1246 MWe RCS boron concentration is 843 ppm Control bank D @ 221 steps 1B SI pump is OOS; it is expected back in service in 26 hours3.009259e-4 days 0.00722 hours 4.298942e-5 weeks 9.893e-6 months .

1BOL 5.2, ECCS Operating for Condition A has been initiated 0B WS pump is OOS; it is expected back in service in 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

Severe weather is forecasted for the shift, currently no watches or warnings are in effect.

Crew is to perform 1BOSR FW-M4, 1A FW Pump AOP Test Online Risk is Green Protected Equipment:

1A SI Pump 1SI8821A 1SI8823A 0A WS Pump 0C WS Pump Unit 2 FC Train

8 INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1 Perform 1BOSR FW-M4, 1A FW Pump AOP Test If contacted as EO to report on oil pump test; report pump and pressures are normal.

Event 2 1LI-459 PZR level instrument fails low (controlling channel)

At Lead Evaluators cue, use Smart Scenario to initiate Pressurizer Level Transmitter 1LI459 to fail low by right clicking on the box titled, 1LI 459 failure low, and select, Release As EO, if requested to verify Variable Heater SCR fan operation; respond if prior to reenergizing of variable heaters that the SCR fans are off.

As SM acknowledge the failure, EAL evaluation for BOA entry, on line risk assessment, request for maintenance support, and IR requests As SM, Acknowledge entry into TS 3.3.1 As SM, Acknowledge request for writing IR, performing on line risk assessment, request for maintenance support and making appropriate notifications.

Event 3 1PT-505, turbine impulse pressure channel fails low At Lead Evaluators cue, use Smart Scenario to fail 1PT-505 low over a 30 second period by right clicking on the box titled, 1PT-505 failure low, and select, Release As SM acknowledge the failure, EAL evaluation for BOA entry, on line risk assessment, request for maintenance support, and IR requests As SM, Acknowledge entry into TS 3.3.1 As SM, Acknowledge request for writing IR, performing on line risk assessment, request for maintenance support and making appropriate notifications As SM, concur with the plan to restore Tave.

Event 4 Spurious Phase A Isolation, with a failure of 1SD005C to close At Lead Evaluators cue, use Smart Scenario to cause a spurious Phase A Isolation low by right clicking on the box titled, Spurious Phase A Isolation, and select, Release As SM acknowledge the failure, E-Plan evaluation, LCO 3.6.3 and LCO 3.3.2 entry, on line risk assessment, request for maintenance support, and IR requests.

Event 5 16A FW heater string leak At Lead Evaluators cue, use Smart Scenario to cause a 16A FW Tube Leak by right clicking on the box titled, 16A FW Tube Leak, and select, Release As EO requested to check heater operation, report valves are positioning as required, Heater 16A high level.

As SM acknowledge request for risk assessment, initiate IR, and contact maintenance to investigate/correct failure.

9 Event 6 Ramp down < 1050 MW due to removing intermediate pressure FW heater string from service As SM acknowledge load reduction and request for risk assessment, initiate IR, and contact maintenance to investigate/correct failure.

Event 7 SBLOCA inside containment At Lead Evaluators cue, use Smart Scenario to cause Small Break LOCA by right clicking on the box titled, SBLOCA, and select, Release As SM acknowledge procedure entry and to evaluate for EMERGENCY PLAN conditions.

As EO, acknowledge requests to perform actions as NSO directs during performance of EOPs.

As Chemistry, acknowledge request to sample all SGs for activity.

As STA, respond to request to start monitoring Status trees.

As WEC, acknowledge request to Place Hydrogen Monitors in service per BOP PS-9, POST LOCA CONTAINMENT HYDROGEN MONITORING SYSTEM OPERATION As TSC, acknowledge request to obtain samples Event 8 A-Train SI, RH and AF pumps fail to automatically start (must manually start 1A SI pump)

As SM acknowledge procedure entry, equipment failures, and to evaluate for EMERGENCY PLAN conditions.

10 Op-Test No.: 2019-302 _

Scenario No.: _N19-2_

Event No.: _ 1__

Event

Description:

Perform 1BOSR FW-M4, 1A FW Pump AOP Test Time Position Applicants Actions or Behavior CUE Directed at turnover to perform 1BOSR FW-M4, 1A FW Pump AOP Test BOP Simultaneously START 1FW01PA-B, FW Pump 1A Aux Oil Pump, at 1PM04J and START the stopwatch.

WHEN the FW Pump 1A Aux Oil Pump Oil Press Up light ILLUMINATES, STOP the stopwatch.

RECORD the Pressurization time on the Data Sheet D2.

Verify Pressurization Time seconds (< 10 seconds PLACE 1FW01PA-B, FW Pump 1A Aux Oil Pump C/S, in AFTER TRIP, at 1PM04J.

o ROUTE a copy of the completed Data Sheet to PED for Trending purposes.

US Directs BOP to perform 1BOSR FW-M4, 1A FW Pump AOP Test o Acknowledges satisfactory completion of 1BOSR FW-M4 EVALUATOR NOTE:

After completion of 1BOSR FW-M4, and with lead examiners concurrence, enter next event.

11 Op-Test No.: 2019-302 _

Scenario No.: _N19-2_

Event No.: _ 2__

Event

Description:

1LI-459 PZR level instrument fails low (controlling channel)

Time Position Applicants Actions or Behavior CUE Annunciator 1-12-B4, PZR LEVEL CONT DEV LOW Annunciator 1-9-D3, CHG LINE FLOW HIGH LOW o

Annunciator 1-12-A4, PZR LVL LOW HTRS OFF LTDWN SECURED o

Annunciator 1-12-A5, PZR HTR TRIP o

Annunciator 1-12-C5, PZR PHASE LOSS OR REVERSAL o

Annunciator 1-12-D5, PZR HTR SCR CLG FAN FAILURE Master PZR Level controller 1LK-459 demand is 100%

Charging Flow rising Variable Heaters Group C are tripped 1CV459, 1CV8149A and 1CV8149B are Closed PZR level indicators 1LI-460 and 461 rising.

ATC o

Implement BHC for Letdown Malfunction.

Identify 1LT-459 is failing low.

Identify letdown is isolated.

Report failure to US.

ATC Implement BAR 1-12-B4:

Place 1FK-121, CV pumps flow control valve OR 1LK-459, PZR master level controller, in manual.

Lower demand on 1FK-121 OR 1LK-459 in conjunction with lowering demand on 1CV182 to lower charging flow to the minimum required for RCP seal injection.

Maintain 6-13 gpm RCP seal injection flow.

Operate 1FK-121 OR 1LK-459 in manual to minimize PZR level rise.

Select operable PZR level control channel:

o Place PZR level control select C/S to CH-461/CH-460 US

Implement 1BOA INST-2 OPERATION WITH A FAILED INSTRUMENT CHANNEL, Attachment C PRESSURIZER LEVEL CHANNEL FAILURE and direct operator actions of 1BOA INST -2 to establish the following conditions:

Notify SM of plant status and procedure entry.

Request evaluation of Emergency Plan conditions.

ATC Perform the following at 1PM05J:

Select operable recorder at 1PM05J:

Place PZR level channel to recorder select switch to CH-460 or CH-461.

o Restore PZR heaters to normal.

o Verify PZR backup heaters in auto o

Cycle PZR variable heater control switch to restore to auto.

EVALUATOR NOTE:

The unit supervisor may elect to continue on in 1BOA INST-2 while the BOP reestablishes CV letdown per 1BOA ESP-2.

12 Op-Test No.: 2019-302 _

Scenario No.: _N19-2_

Event No.: _ 2__

Event

Description:

1LI-459 PZR level instrument fails low (controlling channel)

BOP Restore normal letdown flow per 1BOA ESP-2, REESTABLISHING CV LETDOWN DURING ABNORMAL CONDITIONS.

Perform the following at 1PM05J:

Check Letdown Isolated:

Verify 1CV8149A, B, & C closed.

Verify 1CV459 & 1CV460 closed.

o Manually close 1CV460 Check letdown flow path:

Verify 1CV8401A, 1CV8324A, 1CV8389A, 1CV8152, and 1CV8160 open.

Verify BTRS mode select switch OFF.

Align letdown controllers:

Place 1CV-131 in MANUAL and raise demand to 40%.

Place 1CV-130 in MANUAL and raise demand to 60%.

Verify charging flow established:

Verify 1CV8105 & 1CV8106 open.

Throttle 1CV182 and 1CV121 to establish 8-13 gpm seal inj and 100 gpm charging flows.

Establish letdown flow:

Open 1CV459 and 1CV460.

Open 1CV8149A/B/C to establish 120 gpm letdown.

Adjust 1CV131 controller to 360 psig and place in AUTO Adjust 1CC130A/B controller to 90° to 115°F and place in AUTO Verify 1PR06J in service at RM-11 console.

ATC /

BOP Check PZR level control in auto:

Place 1CV-121 and 1CV-459 in automatic when PZR level is restored to normal.

US o

Request extra NSOs to bypass bistables for the failed channel.

Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct instrument failure

13 Op-Test No.: 2019-302 _

Scenario No.: _N19-2_

Event No.: _ 2__

Event

Description:

1LI-459 PZR level instrument fails low (controlling channel)

US (RF 6a) Recognize malfunction of TS Related Instrumentation (RF 6b) Locate/Determine Applicable LCOs LCO 3.3.1 Reactor Trip System (RTS) Instrumentation o

Function 9, Pressurizer Water Level - High (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME CONDITION A - One or more Functions with one or more required channels or trains inoperable o

A.1, Enter the Condition referenced in Table 3.3.1-1 [CONDITION K]

RA - Enter the Condition referenced in Table 3.3.1-1 [CONDITION K]

CT - Immediately CONDITION K o

K.1 RA - Place channel in trip CT - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR o

K.2 RA - Reduce THERMAL POWER to < P-7 CT - 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months o

Determine TS 3.3.3 and 3.3.4 are NOT applicable - minimum channels operable requirement is met EVALUATOR NOTE:

After the actions for PZR level instrument failure are complete and with lead examiners concurrence, continue with the next event

14 Op-Test No.: 2019-302 _

Scenario No.: _N19-2_

Event No.: _ 3__

Event

Description:

1PT-505, turbine impulse pressure channel fails low Time Position Applicants Actions or Behavior CUE Annunciator 1-14-D1, TAVE CONT DEV HIGH Control rod inward motion.

1PI-505, first stage pressure, indication lowering.

ATC /

BOP Determine control rods inserting.

o Identify 1PT-505 is failing low.

Report failure to US Implement BHC 1-RD, UNCONTROLLED ROD MOTION

Check turbine power stable

Place rod control in manual o

Implement 1BOA ROD-1 UNCONTROLLED ROD MOTION to diagnose the reason for the control rod motion.

CREW o

Reference BAR 1-14-D1.

Identify entry conditions for 1BOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL.

US Notify SM of plant status and procedure entry Request evaluation of Emergency Plan conditions Implement 1BOA INST-2 OPERATION WITH A FAILED INSTRUMENT CHANNEL, Attachment D TURBINE IMPULSE PRESSURE CHANNEL FAILURE and direct operator actions of 1BOA INST -2 ATC /

BOP

Restore steam dumps.

Check C-7 bypass permissive NOT LIT.

Perform the following:

Place 1PK-507, MS header pressure controller, in manual.

Lower 1PK-507 demand to 0%.

Place steam dump mode select switch to STM PRESS mode.

Place 1PK-507 in auto.

Check reactor power < 100% RTP Defeat 1PT-505:

Place 1PS505Z, turbine impulse pressure defeat C/S, to DEFEAT 505 ATC Check Tave - Tref stable and within 1°F Check if rod control can be placed in auto Check C-5 bypass permissive NOT LIT.

Check Tave/Tref stable and within 1°F.

1TR-412 at 1PM05J HMI display o

Adjust Tave - Tref within 1°F by manually withdrawing control rods Place rod bank select switch in AUTO when Tave/Tref stable and within 1°F.

15 Op-Test No.: 2019-302 _

Scenario No.: _N19-2_

Event No.: _ 3__

Event

Description:

1PT-505, turbine impulse pressure channel fails low Time Position Applicants Actions or Behavior ATC/BOP Check P13 interlock Turbine power > 10%

Check P-13 bypass permissive NOT LIT at 1PM05J US (RF 6a) Recognize malfunction of TS Related Instrumentation (RF 6b) Locate/Determine Applicable LCOs LCO 3.3.1 Reactor Trip System (RTS) Instrumentation o

Function 17 Reactor Trip System Interlocks

b. Low Power Reactor Trips Block, P-7 (2) P-13 Input

e. Turbine Impulse Pressure, P-13 (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME CONDITION A - One or more Functions with one or more required channels or trains inoperable.

o A.1 RA - Enter the Condition referenced in Table 3.3.1-1 [CONDITION P]

CT - Immediately CONDITION P - One or more channels inoperable o

P.1 RA - Verify interlock is in required state for existing unit conditions CT - 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months EVALUATOR NOTE:

After the actions for the turbine impulse pressure channel failure are complete, and with lead examiners concurrence, insert the next event.

16 Op-Test No.: 2019-302 _

Scenario No.: _N19-2_

Event No.: _ 4__

Event

Description:

Spurious Phase A Isolation, with a failure of 1SD005C to close Time Position Applicants Actions or Behavior CUE Annunciator 1-5-B7, CNMT PHASE A Group 3 CNMT isolation monitor lights LIT Phase A CNMT isolation valve indications -CLOSED CREW Identify CNMT isolation valves closed Recognize inadvertent CNMT Phase A Isolation CREW Identify entry conditions for 1BOA PRI-13, RECOVERY FROM INADVERTANT PHASE A CONTAINMENT ISOLATION US

Acknowledge report of inadvertent CNMT Phase A Isolation.

Contact SM to perform E-Plan evaluation, risk assessment, initiate IR, and contact maintenance to investigate/correct failure.

Implement 1BOA PRI-13, RECOVERY FROM INADVERTANT PHASE A CONTAINMENT ISOLATION" and direct NSO to perform actions of 1BOA PRI-13.

ATC Take manual control of charging Control 1CV121 to minimize PZR level rise Turn off PZR heaters BOP Start available RCFCs in HIGH speed Determine actuated Train:

1CV8112 CLOSED 1WO006B CLOSED 1WO020B CLOSED Identify Train B actuated Check affected train isolated:

Refer to ATTACHMENT B to verify associated valves CLOSED Identify 1SD005C, S/G 1B BLWDN SAMPLE ISOL VLV, indicates open Place control switch for 1SD005C to CLOSE Verify 1SD005C Closes Report 1SD005C failure to automatically close to US

17 Op-Test No.: 2019-302 _

Scenario No.: _N19-2_

Event No.: _ 4__

Event

Description:

Spurious Phase A Isolation, with a failure of 1SD005C to close Time Position Applicants Actions or Behavior US (RF 6a) Recognize malfunction of TS Related Instrumentation (RF 6b) Locate/Determine Applicable LCOs LCO 3.3.2 Engineered Safety Feature Actuation System Instrumentation Function 3a(2), Containment Phase A Isolation Automatic Actuation Logic and Actuation Relays LCO 3.6.3 Containment Isolation Valves (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME LCO 3.3.2, CONDITION A - One or more Functions with one or more required channels or trains inoperable o

A.1 RA - Enter the Condition referenced in Table 3.3.2-1 [CONDITION C]

CT - Immediately LCO 3.3.2 CONDITION C - One train inoperable o

C.1 RA - Restore train to OPERABLE status CT - 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR o

C.2.1 RA - Be in Mode 3 CT 30 - hours AND o

C.2.2 RA - Be in Mode 5 CT - 60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME LCO 3.6.3 CONDITION C - One or more penetration flow paths with one containment isolation valve inoperable o

C.1 RA - Isolate the affected penetration flow path by use of at least one closed and de-activated automatic or remote manual valve, closed manual valve, blind flange, or check valve with flow through the valve secured CT - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND o

C.2 RA - Verify the affected penetration flow path is isolated CT - Once per 31 days Notify SM of TS entry BOP Reset CNMT Isol Phase A ATC Place PZR spray valve controllers in MANUAL at ZERO DEMAND

18 Op-Test No.: 2019-302 _

Scenario No.: _N19-2_

Event No.: _ 4__

Event

Description:

Spurious Phase A Isolation, with a failure of 1SD005C to close Time Position Applicants Actions or Behavior BOP Open instrument air to CNMT isolation valves 1IA065 and 1IA066 ATC/BOP ESTABLISH NORMAL CHARGING AND LETDOWN ;

Open 1CV8105 and 1CV8106 Verify Regen HX isolation valves open - 1CV8324A or 1CV8324B o

Establish letdown per 1BOA ESP-2, RE-ESTABLISHING CV LETDOWN ATC/BOP CHECK IF RCP SEAL RETURN FLOW SHOULD BE ESTABLISHED:

All of the following SATISFIED:

SEAL WATER HX CC FLOW LOW (12A7) NOT LIT o

RCS pressure GREATER THAN 100 PSIG o

VCT pressure BETWEEN 15 PSIG AND 65 PSIG Open seal water return CNMT isol valves to establish seal return flow:

o 1CV8100 1CV8112 Check No. 1 seal leakoff isol valves OPEN:

o 1CV8141A - D ATC RESTORE CNMT COOLING:

Open all CNMT chilled water valves:

o 1WO006A 1WO006B o

1WO020A 1WO020B 1WO056A o

1WO056B EVALUATOR NOTE:

After the actions for restoring CV charging are complete and with lead examiners concurrence, insert the next event.

19 Op-Test No.: 2019-302 _

Scenario No.: _N19-2_

Event No.: _ 5__

Event

Description:

16A FW heater string leak Time Position Applicants Actions or Behavior CUE o

Annunciator 1-16-E1, FEEDWATER NPSH LOW o

Standby CD/CB Pump automatically started Annunciator 1-16-B2, HTR 16 LEVEL HIGH LOW Annunciator 1-17-B2, HTR 16 EMERGENCY DRAIN VLV OPEN Annunciator 1-17-A2, HTR 16 LEVEL HI-2 1HD041A, HD EMER DRN VLV - OPEN 1HD011A, HD OUTLET VLV - OPEN EVALUATOR NOTE:

The following actions may be implemented prior to receiving Annunciator 1 A2, HTR 16 LEVEL HI-2.

BOP o

Verify actions for Feedwater NPSH Low o

1AOV-CD157A & B, Gland Condenser Bypass Valves, OPEN.

o 1AOV-CD152, Condensate Pumps Recirculating Valve, CLOSES.

o 1AOV-HD046A & B, Heater Drain Pump Combined Discharge Valves, OPEN o

RAMP Unit down in power to decrease FW Flow requirements (~10MW initially)

EVALUATOR NOTE:

Alternatively, the applicant may program a load reduction to 1050 MW at 100 MW/min on OWS 5501.

BOP INITIATE HTR ISOL RUNBACK from OWS graphic 5512 if, to 1050 MW at 100MW/min o

ENSURE automatic actions occur as applicable o

Normal Level Control and Emergency Drain Valves Full OPEN.

o 1AOV-HD008A/B, HP Htr 17A/B Norm Lvl Cont Vlvs, CLOSE.

o 1MOV-ES001, LP Htr 16A/B, Extraction Stem Isol Vlv, CLOSES.

o 1AOV-ES002, LP Htr 16A/B, Extraction Steam Check Vlv, CLOSES.

o 1AOV-ES019, LP Htr 16A/B, Extraction Steam Drain Vlv, OPENS o

When ramp is complete and steam dumps are closed RESET steam dumps by temporarily placing Steam Dump Mode Selector Switch in RESET EVALUATOR NOTE:

Per BOP HD-6T1, the applicant will determine the Load Power Limit as 1159 MW with the heater bypass open or as 610 MW elects to maintain the bypass closed and isolate the 16A FW heater.

BOP Determine maximum power level per BOP HD-6T1, Turbine Operations Limitation Table Concerning the Isolation of Various Strings of Feedwater Heaters EVALUATOR NOTE:

After the actions to respond to a 16A Heater failure are complete (events 5 and

6) and with lead examiners concurrence, insert the event 7.

20 Op-Test No.: 2019-3012 _

Scenario No.: _N19-2_

Event No.: _ 6__

Event

Description:

Ramp down < 1050 MW due to removing intermediate pressure FW heater string from service Time Position Applicants Actions or Behavior CUE 16A Heater failure requires HTR ISOL RUNBACK US Acknowledge 16A Heater failure.

Direct turbine load reduction ATC Control I near target.

Verify control rods in Automatic as maintain I to desired value at 1PM05J.

Monitor RCS parameters.

o If RCS pressure lowers < 2209 psig, notify US to enter TS 3.4.1, RCS DNB Limits.

o If control rods < low - 2 rod insertion limit, notify US to enter TS 3.1.6, Control Bank Insertion Limits.

ATC Initiate RCS boration at 1PM05J:

Determine required boric acid volume.

o Determine from ReMA placard (~195 gal).

Determine desired boric acid flow rate.

Set 1FK-110 BA Flow Control to desired boration rate.

Set 1FY-0110 BA Blender Predet Counter to desired volume.

Place MAKE-UP MODE CONT SWITCH to STOP position.

Place MODE SELECT SWITCH to BORATE position.

Place MAKE-UP MODE CONT SWITCH to START.

Verify proper operation of valves and BA transfer pump (1CV110B open, Boric Acid Transfer Pump running, 1CV110A throttles open, proper BA flow indicated on recorder).

o Turn on PZR backup heaters.

EVALUATOR NOTE:

After the actions to respond to a 16A Heater failure are complete (events 5 and

6) and with lead examiners concurrence, insert the event 7.

21 Op-Test No.: 2019-302 _

Scenario No.: _N19-5_

Event No.: _ 7/8__

Event

Description:

SBLOCA inside containment with A-Train SI, RH and AF pumps fail to automatically start (must manually start 1A SI pump)

Time Position Applicants Actions or Behavior CUE Annunciator 1-1-A2, CNMT DRAIN LEAK DETECT FLOW HIGH 1FT-RF008 CNMT FLR DRAIN SUMP - rate rising 1FT-RF010 RX CAVITY SUMP - rate rising Charging flow - rising Pressurizer pressure - dropping Pressurizer level - dropping greater than 2%/minute US Directs Manual Reactor Trip and Implements 1BEP-0, REACTOR TRIP OR SAFETY INJECTION.

Notifies SM of 1BEP-0 entry.

Requests Emergency Plan evaluation.

ATC o

Manually Initiate Reactor Trip Verify Reactor Trip Rod bottom lights - ALL LIT Reactor trip & Bypass breakers - OPEN Neutron flux DROPPING BOP Verify Turbine Trip Turbine throttle valves - CLOSED Turbine governor valves - CLOSED BOP Verify power to 4KV busses Bus 141 - ENERGIZED Bus 142 - ENERGIZED ATC Check SI status SI actuated SI First OUT annunciator lit (1-11-B1, 1-11-C1, 1-11-D1, 1-11-E1)

SI ACTUATED lit (1-BP-4.1)

SI Equipment running (SI pumps running, CV Cold leg injection SI8801A/B open)

Determine if SI required:

o Check PZR pressure < 1829 psig o

Check Steamline pressure < 640 psig o

Check CNMT pressure > 3.4 psig If SI is required:

Actuate SI from both SI switches (1PM05J and 1PM06J) and continue in 1BEP-0 US Directs BOP to perform Attachment B, SI VERIFICATION of 1BEP 0.

EVALUATOR NOTE:

Crew actions of 1BEP-0 continue on next page.

BOP actions of 1BEP-0, Attachment B continue on page 27.

22 Op-Test No.: 2019-302 _

Scenario No.: _N19-5_

Event No.: _ 7/8__

Event

Description:

SBLOCA inside containment with A-Train SI, RH and AF pumps fail to automatically start (must manually start 1A SI pump)

Time Position Applicants Actions or Behavior ATC/BOP Verify AF system:

AF pumps - Identifies only Train B RUNNING Manually starts 1A Auxiliary Feedwater Pump AF isolation valves 1AF13A-H - OPEN AF flow control valves 1AF005A-H - THROTTLED AF flow - GREATER THAN 500 GPM Check SG tubes intact:

Secondary radiation level - NORMAL AND STABLE Narrow range levels - NOT RISING IN AN UNCONTROLLED MANNER ATC/BOP Check PZR PORVs and Spray Valves PORVs - CLOSED PORV isol valve - at least one ENERGIZED PORV relief path - at least one AVAILABLE PORV in - AUTO Isol valve - open Normal spray valves - CLOSED ATC/BOP ADJUST AF FLOW:

Lower total Feed Flow to approximately 600 gpm ATC/BOP Check steam dumps - AVAILABLE C-9 Permissive light - NOT LIT CW Pump - AT LEAST ONE RUNNING ATC/BOP Control RCS Temperature per table:

Continue to monitor Steam Dump/SG PORV operation Feed at desired rate EVALUATOR NOTE:

Scenario contains a Critical Task to Trip RCPs within 10 minutes of meeting RCP trip criteria. It is anticipated that RCP Trip criteria will not yet have been reached when performing this step.

[CT]

ATC/BOP

[CT-16]

Check if RCPs should be stopped:

All RCPs - ALL RUNNING.

HHSI flow (1FI-917) >100 gpm OR o

SI PP discharge flow (1FI-918/922) >200 gpm RCS pressure NOT <1425 psig (If less than 1425 psig, then Trip RCPs)

ATC/BOP CHECK IF SG SECONDARY PRESSURE BOUNDARIES ARE INTACT:

NO SG PRESSURE DROPPING IN AN UNCONTROLLED MANNER NO SG COMPLETELY DEPRESSURIZED

23 Op-Test No.: 2019-302 _

Scenario No.: _N19-5_

Event No.: _ 7/8__

Event

Description:

SBLOCA inside containment with A-Train SI, RH and AF pumps fail to automatically start (must manually start 1A SI pump)

Time Position Applicants Actions or Behavior ATC/BOP CHECK IF SG TUBES ARE INTACT:

SJAE/Gland Steam Exhaust Gas radiation - HAS REMAINED LESS THAN ALERT ALARM SETPOINT SG Blowdown Liquid radiation - HAS REMAINED LESS THAN ALERT ALARM SETPOINT Main Steamline radiation - HAS REMAINED LESS THAN ALERT ALARM SETPOINT CHECK IF RCS IS INTACT o

CNMT area radiation monitors - LESS THAN ALERT ALARM SETPOINTS o

CNMT pressure - LESS THAN 3.4 PSIG o

CNMT floor drain sump level - LESS THAN 46 INCHES Determines RCS is Not intact CREW TRANSITIONS TO 1BEP-1, LOSS OF REACTOR OR SECONDARY COOLANT, Step 1.

EVALUATOR NOTE:

Actions for 1BEP-1, LOSS OF REACTOR OR SECONDARY COOLANT, continue on the next page.

24 Op-Test No.: 2019-302 _

Scenario No.: _N19-2_

Event No.: _ 7/8__

Event

Description:

A-Train SI, RH and AF pumps fail to automatically start (must manually start 1A SI pump)

Time Position Applicants Actions or Behavior EVALUATOR NOTE:

1BEP-1, LOSS OF REACTOR OR SECONDARY COOLANT, actions begin on this page.

US Enter and direct actions of 1BEP-1 Notifies SM of BEP entry Requests Emergency Plan evaluation Maintains Seal injection flow to all RCPs EVALUATOR NOTE:

Scenario contains a Critical Task to Trip RCPs within 10 minutes of meeting RCP trip criteria. It is anticipated that RCP Trip criteria exists at this point of procedure performance or will shortly thereafter BOTH of the following conditions exists:

RCS pressure <1425 PSIG

-AND-

High head SI flow indicator (1FI-917) >100 GPM or SI pump discharge flow

>200 GPM

[CT]

ATC

[CT-16]

Check if RCPs should be stopped:

All RCPs - ALL RUNNING.

HHSI flow (1FI-917) >100 gpm OR o

SI PP discharge flow (1FI-918/922) >200 gpm RCS pressure NOT <1425 psig (If less than 1425 psig, then Trip RCPs)

ATC Check if SG secondary pressure boundaries are intact No SG pressure dropping in an uncontrolled manner No SG completely depressurized BOP Check intact SG levels Control feed flow to maintain between 10% (31%) and 50%

BOP Check secondary radiation normal Reset CNMT Isol Phase A (if necessary)

Sample all SGs for activity Check secondary radiation trends NORMAL FOR PLANT CONDITIONS Secondary activity samples NORMAL (WHEN AVAILABLE)

25 Op-Test No.: 2019-302 _

Scenario No.: _N19-2_

Event No.: _ 7/8__

Event

Description:

A-Train SI, RH and AF pumps fail to automatically start (must manually start 1A SI pump)

Time Position Applicants Actions or Behavior ATC CHECK PZR PORVs AND ISOLATION VALVES PORV isol valves - ENERGIZED 1RY8000A 1RY8000B PORVs - CLOSED 1RY455A 1RY456 PORV isol valves - AT LEAST ONE OPEN o

1RY8000A o

1RY8000B ATC CHECK IF ECCS FLOW SHOULD BE REDUCED o

RCS subcooling - ACCEPTABLE o

Secondary heat sink o

RCS pressure - STABLE OR RISING o

PZR level - GREATER THAN 12% (28% ADVERSE CNMT)

Determines that ECCS flow should not be reduced.

BOP CHECK IF CS SHOULD BE STOPPED:

CS pumps - Determines NONE RUNNING BOP CHECK IF RH PUMPS SHOULD BE STOPPED:

Reset SI Depress both SI reset pushbuttons Verify SI ACTUATED permissive light - NOT LIT Verify AUTO SI BLOCKED permissive light - LIT Check RCS pressure:

Pressure - GREATER THAN 325 PSIG Determines Pressure - is NOT STABLE OR RISING BOP CHECK RCS AND SG PRESSURES FOR FAULTED SG INDICATIONS:

Check pressure in all SGs - STABLE OR RISING Check RCS pressure - STABLE OR DROPPING BOP CHECK IF DGs SHOULD BE STOPPED:

4KV busses - ENERGIZED BY OFFSITE POWER:

Bus 141 Bus 142 Bus 143 Bus 144 Dispatch Operator to Stop any unloaded DG and place in standby per BOP DG-12, DIESEL GENERATOR SHUTDOWN

26 Op-Test No.: 2019-302 _

Scenario No.: _N19-2_

Event No.: _ 7/8__

Event

Description:

A-Train SI, RH and AF pumps fail to automatically start (must manually start 1A SI pump)

Time Position Applicants Actions or Behavior US/BOP INITIATE EVALUATION OF PLANT STATUS:

Check cold leg recirculation capability:

Train A - AVAILABLE:

RH pump 1A 1SI8811A, CNMT sump isol valve position lights - LIT Train B - AVAILABLE:

RH pump 1B 1SI8811B, CNMT sump isol valve position lights - LIT Check CC Pumps - TWO RUNNING Check Aux Bldg radiation trends (PPC or Rad Monitoring System) - NORMAL FOR PLANT CONDITIONS Obtain samples:

o Place Hydrogen Monitors in service per BOP PS-9, POST LOCA CONTAINMENT HYDROGEN MONITORING SYSTEM OPERATION o

Consult TSC for obtaining samples:

o RCS boron concentration o

Containment sump pH o

Containment sump activity o

Consult TSC for assessing additional sampling requirements for fuel damage o

Evaluate plant equipment for long term recovery:

o ESF equipment o

Post accident monitoring instrumentation o

Radiation monitoring o

Other equipment as necessary o

Shutdown chiller on non-operating VC train:

o For SI start - MOMENTARILY PLACE CONTROL SWITCH IN TRIP/PTL CREW CHECK IF RCS COOLDOWN AND DEPRESSURIZATION IS REQUIRED:

RCS pressure - GREATER THAN 325 PSIG TRANSITIONS TO 1BEP ES-1.2, POST LOCA COOLDOWN AND DEPRESSURIZATION, Step 1 EVALUATOR NOTE:

The scenario will be terminated when the crew transitions to 1BEP ES-1.2, POST LOCA COOLDOWN AND DEPRESSURIZATION, and the actions of 1BEP-0, Attachment B are complete.

27 Op-Test No.: 2019-302 _

Scenario No.: _N19-2_

Event No.: _ 7/8__

Event Description A-Train SI, RH and AF pumps fail to automatically start (must manually start 1A SI pump)

Time Position Applicants Actions or Behavior EVALUATOR NOTE:

1BEP-0, Attachment B, SI VERIFICATION actions begin on this page.

CT BOP

[CT-7]

Attachment B action Verify ECCS pumps running CENT CHG pumps - BOTH RUNNING RH pumps Only 1B RH Pump RUNNING Starts 1A RH Pump SI pumps Neither SI Pump RUNNING, 1B SI Pump Out of Service Starts 1A SI Pump BOP Attachment B action Verify ECCS valve alignment Group 2 Cold Leg Injection monitor lights lit BOP Attachment B action Verify ECCS flow HHSI flow >100 gpm RCS pressure NOT <1700 psig If RCS pressure <1700 psig check SI pp flow > 200 gpm BOP Attachment B action Verify RCFCs running in Accident Mode - Group 2 RCFC Accident Mode status lights lit - LIT Verify CNMT isolation Phase A - Group 3 CNMT isolation monitor lights lit Verify CNMT Ventilation isolation - Group 6 CNMT Vent Isol monitor lights lit Verify CC Pumps both running Verify SX Pumps both running Check if Main Steamline Isolation is required o

Check SG pressure < 640 psig o

Check CNMT pressure > 8.2 psig If either condition is met, then verify MSIVs and MSIV Bypass valves closed Check if CS is required (NOT required)

BOP Attachment B action Verify FW isolated FW pumps tripped FW isolation monitor lights lit FW pumps discharge valves closed 1FW002A-C Trip all running HD pumps

28 Op-Test No.: 2019-302 _

Scenario No.: _N19-2_

Event No.: _ 7/8__

Event Description A-Train SI, RH and AF pumps fail to automatically start (must manually start 1A SI pump)

Time Position Applicants Actions or Behavior BOP Attachment B action Verify DGs running DGs - both running SX valves open 1SX169A and B Dispatch operator locally to check operation BOP Attachment B action Verify Generator Trip GCB 3-4 and OCB 4-5 open PMG output breaker open BOP Attachment B action Verify Control Room ventilation aligned for emergency operations:

Control Room Outside Air Intake radiation monitors < High Alarm setpoints Operating VC train equipment running Train A Supply fan 0A Return fan 0A M/U fan 0A Chilled water pump 0A MCR chiller 0A Operating VC train dampers M/U fan outlet damper NOT full closed 0VC24Y VC train M/U filter light LIT Operating VC train Charcoal Absorber aligned for train A 0VC43Y closed 0VC21Y open 0VC22Y open Operating VC train M/U filter alignment for train A (SI/Hi Rad) 0VC25Y - OPEN 0VC312Y-CLOSED Control Room pressure greater than +0.125 inches water on 0PDI-VC038

29 Op-Test No.: 2019-302 _

Scenario No.: _N19-2_

Event No.: _ 7/8__

Event Description A-Train SI, RH and AF pumps fail to automatically start (must manually start 1A SI pump)

Time Position Applicants Actions or Behavior BOP Attachment B action Verify Auxiliary Building ventilation aligned Two inaccessible filter plenums aligned Plenum A fan 0VA03CB running Damper 0VA023Y not fully closed Damper 0VA436Y closed Plenum C fan 0VA03CF running Damper 0VA072Y not fully closed Damper 0VA438Y closed Check Aux Building Supply and Exhaust fans One Exhaust Fan running for every Supply Fan running BOP Attachment B action Verify FHB ventilation aligned Train B fan 0VA04CB running 0VA055Y open 0VA062Y not fully closed 0VA435Y closed BOP9 Attachment B action Maintain UHS Basin level > 80%

Initiate periodic checking of Spent Fuel Cooling Dispatch operator to locally check SFP level and temperature Notify Unit Supervisor of Manual actions taken Failed equipment status Attachment B completed CREW Attachment B action Shutdown unnecessary plant equipment As time allows refer to 1BGP 100-4T4, REACTOR TRIP POST RESPONSE GUIDELINE As time allows refer to 1BGP 100-5, PLANT SHUTDOWN AND COOLDOWN EVALUATOR NOTE:

1BEP-0, REACTOR TRIP OR SAFETY INJECTION, main body actions continue on page 22.

1 Facility: Byron_____________ Scenario No.: N19-3________

Op-Test No.: 2019-302_

Examiners: ___________________________ Operators:

Initial Conditions: ~2% RTP, BOL Turnover: With Shift Manger concurrence, re-perform 1BGP 100-2 step 24 Turbine Oil checks from the Control Room.

An equipment operator is standing by locally for performance. Concurrently continue raising power IAW 1BGP 100-3 step 8. to greater than 5% RTP to enter Mode 1 operations. 2B SX pump is OOS, expected RTS in 14 hours1.62037e-4 days 0.00389 hours 2.314815e-5 weeks 5.327e-6 months . Tech Spec 3.7.8 Cond A has been entered and 2BOL 7.8 has been initiated. Severe weather is forecasted for the shift, currently no watches or warnings are in effect. PORC concurs with continuing the load ascension.

Event No.

Malf. No.

Event Type*

Event Description 1

None N - BOP N - US Perform step 24 Turbine Oil checks in 1BGP 100-2 2

None R - ATC R - US Raise Rx power past the POAH to 5% (Mode change) 3 CV16 100 60 I - ATC I - US VCT level channel 1LI-112 fails high 4

RX18H 650 30 I - ATC I - US TS - US RCS Thot RTD fails high (requires manual control of PZR level) 5 SW04 8500 120 SW01A C - BOP C - US TS - US Flooding in the AB from SX return header. Induces a loss of both A-train SX pumps (both 1A and 2A SX pumps trip).

1B SX pump requires a manual start. [CT-9] [TCA #4]

6 ED18A SUSTAINED ED07A ED07C ED18B SUSTAINED ED18C SUSTAINED ED18D SUSTAINED ED18E SUSTAINED RD01B M - ALL Lightning strike causes U1 and U2 LOOP, with Bus 242 fault. 1A DG experiences a lockout.

7 EG08B (preload)

C - BOP C - US 1B DG fails to start automatically or manually. A loss of all AC power on Unit 1 occurs. The crew will enter 1BCA 0.0, LOSS OF ALL AC POWER. When safety injection is actuated at step 5 of 1BCA 0.0 the 1B DG will automatically start energizing Bus 142.During this time, the site will experience a loss of all SX (loss of UHS).

[TCA #3]

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

2 SCENARIO N19-3 OVERVIEW The scenario will start at ~2% RTP, BOL, the crew is being directed to re-perform Turbine Oil Checks per 1BGP 100-2, step 24. The crew will concurrently raise power to enter Mode 1 operations per 1BGP 100-3. The 2B SX pump is OOS, expected RTS in 14 hours1.62037e-4 days 0.00389 hours 2.314815e-5 weeks 5.327e-6 months . 2BOL 7.8 has been initiated. Severe weather is forecasted for the shift.

Event 1:

The crew is directed to re-perform Turbine Oil Checks per 1BGP100-2, step 24.

Event 2:

The crew will be directed to proceed to raise power to greater than 5% to enter Mode 1. At the lead examiner discretion, continue to Event 3.

Event 3:

The crew will identify a failure of VCT level channel 1LI-112 (failing high) and respond to BAR 1-9-A2. The crew should place 1CV112A to VCT, per the BAR. At lead examiner discretion, continue to Event 4.

Event 4 The crew will identify a failure of RCS Thot RTD 1TE441 failing high. The crew will respond by taking manual control of pressurizer level to stabilize at program value. A false high program value will be observed due to the Auctioneered high Tave input to PZR level control. Rod control should remain in manual and no uncontrolled rod motion should occur during the transient. The crew should enter 1BOA INST-2 and take followup actions to select an operable controlling channel.

The crew should enter LCO 3.3.1 Cond A & E (function 6, 7). The crew may enter LCO 3.4.1 Cond A if PZR pressure drops below 2209 psig during the transient. At lead examiner discretion, continue to Event 5.

Event 5 The crew will experience flooding in the Aux Bldg, due to a leak in the SX return header. The leak will induce a loss of both A train SX Pumps, as the A-train SX pump room will flood. The running 1A and 2A SX pps will trip. The crew will start 1B SX pump and crosstie to Unit 2 per BHC 1-2-A1. The crew should enter 1BOA PRI-7, SX malfunction. The crew should enter the following for Unit 1: LCO 3.7.8 Cond A for Unit 1 (due to a loss of 1A SX pump) Cond B (for no opposite Unit SX). The crew may enter 0BOA PRI-8, Aux Bldg Flooding, to attempt to find the source of water (the crew may reference BOP SX-22 to determine the source of the leak and the impact of the leak). At lead examiner discretion, continue to Event 6.

Event 6 Severe weather in the area will impact the site via lightning strikes and high winds that induce a U1 and U2 LOOP, with a subsequent Bus 242 fault and a lockout of the 1A DG, ultimately a Loss of all AC power on Unit 1. On the 142 bus undervoltage, the 1B DG will fail to start, (Event 7). The source of power for Unit 2 at this point is the 2A DG. The crew will enter 1BCA-0.0 and take action to reenergize Bus 142.

Event 7 The 1B DG failing to start on the undervoltage signal (BAR 1-22-C8), resulting in a complete loss of SX flow, loss of UHS (0BOA PRI-7) until 1B DG is started when safety injection is actuated at step 5 of 1BCA 0.0, the 1B DG will automatically start energizing Bus 142. During this time, the site will experience a loss of all SX (loss of UHS). Actions per 0BOA PRI-7 will be ineffective, as the highest priority at this point is restoring Bus 142 so the 1B SX pump can be restarted.

The scenario can be terminated after the crew has restored Bus 142, started the 1B SX pump, and transitioned out of 1BCA 0.0.

3 Critical Tasks:

CT-9: Start 1B SX pump to restore SX flow prior to safeguards equipment failure or damage.

(K/A number - 076A2.01; importance 3.5/3.7)

TCA#4: Identify and isolate flood originating from the nonessential service water (WS) and essential service water (SX) within 30 minutes.

(UFSAR 9.3.3.2 pg. 9.3-21, R16) (K/A number - 076A2.01; importance 3.5/3.7)

TCA#3: Align alternate a-c power source within 10 minutes of onset of SBO.

(UFSAR 8.3.1.1.2.2 pg. 8.3-10, R14) (K/A number - 000055EA2.03 importance 3.9/4.7)

4 SIMULATOR SETUP GUIDE:

Verify/perform TQ-BY-201-0113, Appendix A, Simulator Ready for Training Checklist.

Establish the conditions of IC 11, BOL Startup, Mode 2, 2-3% power Place Simulator in RUN Initiate Smart Scenario:

o Open SMART SCENARIO (Extreme Ace icon) o Open file Scenario N192-3.ssf o

Load Initial values for instrument failures o

Event 3, VCT Level Channel 112 fails high o

Event 4, TH 1TD441X fails high o

Click on the MODE button (near top of screen) and pick EXECUTE o

Click on the PLAY button (bottom left of screen)

Verify the following are included in the Smart Scenario:

5

6 Place the following control switches in PTL:

none Place clearance order INFO tag on the following control switches:

none Place Protected Equipment placards on the following control switches:

1SX005 Set AB Pot to 5.25 for 1343 ppm boron Ensure REMA is available at the Unit Desk Provide marked-up copies of the following documents:

2BOL 7.8, LCOAR ESSENTIAL SERVICE WATER (SX) SYSTEM 1BOL 3.h, LCOAR POWER DISTRIBUTION MONITORING SYSTEM (PDMS)

Provide copies of the following documents:

1BGP100-2, PLANT STARTUP 1BGP100-3, POWER ASCENSION 1BGP100-3T1, POWER ASCENSION FLOWCHART BOP TG-15, TURNING GEAR STARTUP BOP TG-16, TURNING GEAR SHUTDOWN

7 Turnover Information Unit 1 is at ~2% BOL 0 MWe RCS boron concentration is 1343 ppm Control bank D @ 130 steps 2B SX pump is OOS; it is expected back in service in 14 hours1.62037e-4 days 0.00389 hours 2.314815e-5 weeks 5.327e-6 months .

2BOL 7.8, Essential Service Water (SX) System for Condition A has been initiated.

Crew is to re-perform 1BGP 100-2 step 24 Turbine Oil checks from the Control Room. An Equipment Operator is standing by locally.

Concurrently, continue raising power IAW 1BGP 100-3 step 8 to greater than 5% RTP to enter Mode 1 operations.

Mode 2 to Mode 1 Checklist is complete 1BOL 3.h has been entered for PDMS inoperability < 25% RTP.

Online Risk is Green Protected Equipment:

1SX005 Unit 2 FC Train

8 INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1 Perform step 24 Turbine Oil checks in 1BGP 100-2 As EO, if requested to verify that the Main Turbine Shaft is not rotating at 1BGP 100-2 step 24.n; report that the turbine is not rotating.

When requested as EO, respond to requests to perform local verifications/actions during performance of BOP TG-16, TURNING GEAR SHUTDOWN and BOP DG-15, TURNING GEAR STARTUP.

Event 2 Raise Rx power past the POAH to 5% (Mode change)

As SM, if requested; confirm permission to change modes.

As EO, if requested to VERIFY/OPEN 1MS003A-M and 1MS005A-M, Manual Isolation Valves for Steam Dump Valves; report 1MS003A-M and 1MS005A-M, Manual Isolation Valves for Steam Dump Valves are OPEN.

As SM, acknowledge entry into Mode 1..

Event 3 VCT level channel 1LI-112 fails high At Lead Evaluators cue, use Smart Scenario to fail VCT Level Channel 112 to 100% psig over a one minute period by right clicking on the box titled, VCT Level Channel 112 fails high, and select, Release As SM/WEC, acknowledge the failure, on line risk assessment, request for maintenance support, and IR requests Event 4 RCS Thot RTD fails high (requires manual control of PZR level)

At Lead Evaluators cue, use Smart Scenario to fail Primary RTD NR TH1TD441X to 650oF psig over a 30 second period by right clicking on the box titled, TH 1TD441X fails Hi, and select, Release As SM/WEC, acknowledge the failure, on line risk assessment, request for maintenance support, and IR requests

9 Event 5 Flooding in the AB from SX return header (1SX07HA-20), induces a loss of both A-train SX pumps (both 1A and 2A SX pumps trip). 1B SX pump requires a manual start.

At Lead Evaluators cue, use Smart Scenario to initiate a SX Header Leak leading to A Train Pump Trips by right clicking on the box titled, SX Header Leak leading to A Train Pump Trips, and select, Release When the 1B SX pump is started, the following announcement should be provided from Unit 2; Attention on Unit 1 for an update. When acknowledged; Perform prompt actions on Unit 1 for a Unit 2 SX Pump Trip, end of update.

If contacted as Rad Waste Operator, wait 5 minutes and report; Essential Service Water Sump Pumps are running and I have alarms on sump levels.

If dispatched as EO, to check for an SX leak, wait three minutes and report, there is a leak on a large SX line just in front of the watertight door.

If dispatched as EO to investigate 1A SX Pp trip and perform rotation checks, and you had NOT been previously dispatched, wait three minutes and report; unable to check rotation, there is a leak on a large SX line just in front of the watertight door, I cannot enter the room but the door was successfully relatched.

If dispatched as EO to investigate 1A SX Pp breaker, wait three minutes and report: 1A SX pump has an overcurrent relay target on Bus 141 Cubicle 2.

As EO dispatched to energize 1SX001A, wait three minutes then use Smart Scenario to energize 1SX001A by right clicking on the box titled, Energize 1SX001A, and select, Release, and report to control room that bkr 131X3:E4 is energized.

IF contacted as SM/WEC/EO on status of SX pump room floor plugs; report SX pump room floor plugs are installed.

If contacted as SM to determine if the SX System must be shutdown to mitigate the flooding concern, report; Do NOT shut down the SX system at this time, continue to investigate and isolate the flooding source.

Event 6 Lightning strike causes U1 and U2 LOOP, with Bus 242 fault. 1A DG experiences a lockout.

At Lead Evaluators cue, use Smart Scenario to initiate a LOOP and Bus 141 Lockout by right clicking on the box titled, LOOP and Bus 141 Lockout, and select, Release As Outsides/EO, if questioned, report; the weather has worsened and large lightning strikes are occurring nearby.

As SM acknowledge procedure entry and to evaluate for EMERGENCY PLAN conditions.

Event 7 1B DG fails to start automatically or manually. A loss of all AC power on Unit 1 occurs.

Note the time the malfunction ED19E inserts, approximately 93 seconds from the first electrical perturbation, this is the initiation time for Loss of All AC Power.

Record time loss of all AC power occurred. ______:______:______

As SM acknowledge procedure entry and to evaluate for EMERGENCY PLAN conditions.

As U2 NSO, acknowledge request to enter and perform actions of 2BCA 0.3.

As EO dispatched to depress 1A Diesel Generator Emergency Stop pushbutton, wait three minutes then use Smart Scenario to depress 1A Diesel Generator Emergency Stop pushbutton by right clicking on the box titled, Emergency Stop 1A Diesel, and select, Release.

10 Op-Test No.: 201-302 _

Scenario No.: _N19-3_

Event No.: _ 1__

Event

Description:

Perform step 24 Turbine Oil checks in 1BGP 100-2 Time Position Applicants Actions or Behavior CUE Directed at turnover to perform Turbine Oil checks EVALUATOR NOTE:

The following description is written for the Balance of Plant Operator to operate the Turning Gear from the Control Room.

BOP STOP 1TG06E, Main Turbine Turning Gear Motor, and ENSURE the ZERO SPEED light comes on per BOP TG-16.

PLACE HS-TG003, Turning Gear Control Switch for TG06E, to the REMOTE position at 1PM02J.

PLACE HS-TG002, Turning Gear Switch for TG06E, to the TRIP position at 1PM02J.

VERIFY the following at PM02J.

Turning Gear Disengaged light is lit.

Turbine Zero Speed alarm annunciates (1-18-E9).

PLACE 1TO08P, Turbine Brng Lift Pps, to the OFF position.

VERIFY/PLACE 1TO05P, Emergency Oil Pump, in AUTO AFTER TRIP).

PLACE 1TO07P, Turbine Seal Oil Backup Pump, in PULL OUT.

PLACE 1TO06P, Bearing Oil Pump, to PULL OUT. ENSURE that the Emergency Oil Pump starts at approximately 11 psig.

PLACE 1TO06P, Bearing Oil Pump, in AUTO (AFTER TRIP).

PLACE 1TO05P, Emergency Oil Pump, in PULL OUT. ENSURE that the Bearing Oil Pump starts at approximately 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).

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.

PLACE HS-1TG003, Turning Gear Control Switch for 1TG06E, to the REMOTE position at 1PM02J.

VERIFY/START the Turbine Bearing Oil Lift Pumps at 1PM02J.

VERIFY the Turbine Zero Speed alarm is lit at 1PM02J.

Dispatch the EO to MANUALLY ENGAGE the Turning Gear by lifting the Manual Engage Lever and to VERIFY Turning Gear is engaged (EO).

START the Turning Gear by PLACING HS-1TG002, Turning Gear C/S for 1TG06E, to the CLOSE position at 1PM02J.

VERIFY proper operation of the Turning Gear at PM02J by the following

11 Op-Test No.: 201-302 _

Scenario No.: _N19-3_

Event No.: _ 1__

Event

Description:

Perform step 24 Turbine Oil checks in 1BGP 100-2 indications:

Turning Gear Engaged Light lit.

Zero Speed Light NOT lit.

Turbine Zero Speed alarm clear.

25 to 35 amps indicated on 1IT-TG002 VERIFY 1TG06E, Turning Gear, GEAR ENGD light is ON and that the ZERO SPEED light goes OFF.

US Directs BOP to perform the o

Acknowledges the start of CD/CB pump EVALUATOR NOTE:

After the Turbine Oil checks are complete the crew should proceed with the next event.

12 Op-Test No.: 201-302 _

Scenario No.: _N19-3_

Event No.: _ 2__

Event

Description:

Raise Rx power past the POAH to 5% (Mode change)

Time Position Applicants Actions or Behavior CUE Directed at turnover to raise power IAW 1BGP 100-3step 8 to greater than 5% RTP to enter Mode 1 operations.

US Direct Power ascension per turnover.

Implement actions of 1BGP 100-3, POWER ASCENSION to raise power to greater than 5% RTP per step F.8.

o VERIFY/ENTER 1BOL 3.h for PDMS inoperability in Mode 1 < 25% RTP EVALUATOR NOTE:

Annunciator 1-14-D1 TAVE CONT DEV HIGH, is expected to be received while diluting to raise power to enter Mode 1.

ATC o

VERIFY Shift Manager's permission has been obtained and logged in the Unit log.

o VERIFY/OPEN 1MS003A-M and 1MS005A-M, Manual Isolation Valves for Steam Dump Valves.

INCREASE reactor power to > 5%.

Verify rod position and boron concentration.

Conducts reactivity brief Initiate dilution IAW ReMA and BOP CV-5 or BOP CV-5T1 Select STOP on RMCS Makeup Control Switch Select DIL or ALT DIL on RMCS Mode Select Switch o

Enter desired flowrate o

Verify Prescaler set to 1.0 o

Reset PW/ Total Flow counter Enter desired dilution amount in PW counter Place RMCS Makeup Control Switch to START Verify 1CV110B OPEN if in ALT DIL Verify 1CV111A and B OPEN Verify proper PW flow on flow recorder 1CD-CX4102 o

Monitors effects of dilution Turn on PZR backup heaters.

During dilution, monitor the following at 1PM05J and HMI:

VCT level.

RCS Tave rising/RCS boron concentration lowering.

PW/Total flow counter responding correctly.

Verify dilution auto stops at preset value.

Withdraw control rods per ReMA.

When Reactor Power is > 5%LOG Mode change in the Unit log book.

EVALUATOR NOTE:

After Rx power has been raised greater than 5% and with lead examiners concurrence, initiate the next event.

13 Op-Test No.: 201-302 _

Scenario No.: _N19-3_

Event No.: _ 3__

Event

Description:

VCT level channel 1LI-112 fails high Time Position Applicants Actions or Behavior CUE Annunciator VCT LEVEL HIGH-HIGH/LOW (1-9-A2) is LIT VCT Level 1LI-112 indicates 100% on recorder 1CV112A DIVERT to HUT CREW Refer to BAR 1-9-A2 Determine 1LT-112 is failed HIGH o

Determine Auto switchover at <5% is unavailable ATC Place 1CV112A to VCT position Monitor VCT level Control VCT level between 37 and 55%

US Notify SM of failure, request IR BOP Monitor primary and secondary panels Assist with BAR response EVALUATOR NOTE:

After the actions for the VCT level failure are complete and with lead examiners concurrence, insert the next event.

14 Op-Test No.: 201-302 _

Scenario No.: _N19-3_

Event No.: _ 4__

Event

Description:

RCS Thot RTD fails high (requires manual control of PZR level)

Time Position Applicants Actions or Behavior CUE Annunciators:

1-14-A5/B5/C5 LOOP 1A/1B/1C T DEV LOW - LIT 1-14-A3/B3/C3 LOOP 1A/1B/1C TAVE DEV LOW - LIT 1-12-B4 PZR LEVEL CONT DEV LOW 1-9-D3 CHG LINE FLOW HIGH LOW Loop 1D Tave indication rising and higher than the other loops Loop 1D T indication rising and higher than the other loops Programmed Pressurizer level rising ATC/US Identify/report failure of Loop 1D Tave/Thot ATC/US Implement 1BOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL, Attachment A, RCS NARROW RANGE RTD CHANNEL Notify SM to evaluate for E-plan o

Place Rod Bank Select switch in Manual Manually Defeat failed RTD channel Select Loop 1D Tave channel with TAVE DEFEAT switch Select Loop 1D T channel with T DEFEAT switch Check reactor power less than 100% RTP Select an operable RTD channel to the T recorder.

o Check if Rod Control can be placed in AUTO Check PZR level normal and stable - manually restore to program level if not.

o Cent Chg Pmps Flow Cont Vlv 1CV121 o

Master PZR Level Cont 1LK-459 Check P12 Interlock, Tave > 550º F - LO-2 TAVE STM DUMP INTLK P12 (1-BP-4.5) NOT LIT Remove 1D channel input to PDMS by placing T0462A (Loop D Tcold) in TEST Remove 1D channel input to SPDS by placing point T0460 in DELETE from SCAN o

Place channel in bypass/ trip as directed by SM

15 Op-Test No.: 201-302 _

Scenario No.: _N19-3_

Event No.: _ 4__

Event

Description:

RCS Thot RTD fails high (requires manual control of PZR level)

Time Position Applicants Actions or Behavior US (RF 6a) Recognize malfunction of TS Related Instrumentation (RF 6b) Locate/Determine Applicable LCOs LCO 3.3.1 Reactor Trip System (RTS) Instrumentation Function 6, Overtemperature T Function 7, Overpower T (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME CONDITION A - One or more Functions with one or more required channels or trains inoperable o

A.1 RA, Enter the Condition referenced in Table 3.3.1-1 [CONDITION E],

CT Immediately CONDITION E, One channel inoperable o

E.1 RA - Place channel in trip CT - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR o

E.2 RA - Be in MODE 3 CT - 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months EVALUATOR NOTE:

After the actions to respond to the failed RTD channel have been completed and with lead evaluators concurrence, insert the next event.

16 Op-Test No.: 201-302 _

Scenario No.: _N19-3_

Event No.: _ 5__

Event

Description:

Flooding in the AB from SX return header induces a loss of both A-train SX pumps (both 1A and 2A SX pumps trip). 1B SX pump requires a manual start Time Position Applicants Actions or Behavior CUE 1A SX pump - amps - rising 1A SX pump discharge pressure - LOWERING Rad Waste Operator calls stating; Essential Service Water Sump Pumps are running and I have alarms on sump levels.

Annunciators:

1-2-A2, SX PUMP DISCH HDR PRESS LOW 1-2-A1, SX PUMP TRIP EVALUATOR NOTE:

When the 1B SX pump is started, the following announcement should be provided from Unit 2; Attention on Unit 1 for an update. When acknowledged; Perform prompt actions on Unit 1 for a Unit 2 SX Pump Trip, end of update.

[CT]

BOP

[CT-9]

Implements BHC 1-2-A1, SX PUMP TRIP Starts the standby 1B SX pump Holds switch until oil pump starts and 1B SX pump starts OPEN 1SX005 (after update from U2)

ATC o

Performs support actions such as making a plant announcement, dispatching EO to pump and/or bus, and checking BARs US Direct/Ensure BOP attempts a manual start of 1B SX pump Inform SM of 1A SX pump trip.

EVALUATOR NOTE:

Due to the leakage in the SX Pump Room, the Equipment Operator will NOT be able to locally check the tripped SX pump(s) for rotation. The 1A pump suction valve should be energized and closed, in this instance, isolating the leak.

EVALUATOR NOTE:

Aux Building leakage is indicated, 0BOA PRI-8 AUX BUILDING FLOODING UNIT 0 should be referenced during implementation of 1BOA PRI-7.

[CT]

US/BOP

[TCA #4]

Implement 1BOA PRI-7, ESSENTIAL SERVICE WATER MALFUNCTION MONITOR RCP SEAL COOLING:

o Seal injection flow to all RCPs - AVAILABLE or RCP THERM BARR CC WTR FLOW alarms - NO LIT o

RCP seal outlet temperatures - LESS THAN 235°F o

RCP lower bearing temperatures - LESS THAN 225°F CHECK SX PUMPS:

o SX pump(s) - AT LEAST ONE RUNNING o

SX STRN DP HIGH (1-2-C2) - NOT LIT o

Locally check tripped SX pump(s) - NOT ROTATING Dispatch an operator to energize the affected pump's suction valve:

1SX001A at 131X3 cub E4 Close the affected pump's suction valve: 1SX001A (within 30 minutes of leak initiation).

CHECK SX PUMP DISCHARGE HEADER TEMPERATURE:

o Temperature - GREATER THAN 50°F and LESS THAN 80°F CHECK SX TOWER BASIN:

17 Op-Test No.: 201-302 _

Scenario No.: _N19-3_

Event No.: _ 5__

Event

Description:

Flooding in the AB from SX return header induces a loss of both A-train SX pumps (both 1A and 2A SX pumps trip). 1B SX pump requires a manual start Time Position Applicants Actions or Behavior o

Level - LESS THAN 100% and - GREATER THAN 80% AND STABLE CHECK CC OUTLET TEMPERATURE:

o CC heat exchanger outlet temperature(s) - LESS THAN 105°F:

CHECK SX SYSTEM INTACT o

Running CENT CHG pump oil temperature(s) - NORMAL o

Check running equipment temperature - LESS THAN MAXIMUM LIMITS:

o SX PUMP DSCH HDR PRESS LOW (1-2-A2) NOT LIT CNMT indications - NORMAL Aux Bldg indications - are NOT NORMAL Locate and isolate the leak Reference 0BOA PRI-8, AUXILIARY BUILDING FLOODING o

Dispatch operators to investigate and monitor leakage in affected areas Contact Radwaste operator to determine sump status o

Evacuate all unnecessary personnel from affected area o

Check SX pump room floor plugs - INSTALLED EVALUATOR NOTE:

0BOA PRI-8, AUX BUILDING FLOODING UNIT 0, may be referenced during performance of 1BOA PRI-7, ESSENTIAL SERVICE WATER MALFUNCTION.

[CT]

US/BOP

[TCA #4]

Determine source and severity of flooding:

Dispatch operators to investigate and monitor leakage in affected areas Contact Radwaste operator to determine sump status Evacuate all unnecessary personnel from affected area o

Consider securing and deenergizing equipment affected by flooding o

Evaluate need to shutdown OR trip reactor(s) due to secured equipment o

Trend level in following tanks Locate and isolate leakage while continuing with this procedure Check SX pump room floor plugs - INSTALLED Unit 1 initiate 1BOA PRI-7, ESSENTIAL SERVICE WATER MALFUNCTION CHECK IF SX SYSTEM SHUTDOWN REQUIRED:

Either of the following conditions - EXIST:

Leakage - CAN NOT BE ISOLATED WITHIN 30 MINUTES Shift Manager determines - SX SYSTEM MUST BE SHUTDOWN TO MITIGATE FLOODING CONDITION IDENTIFY LEAKING TRAIN:

Determines Only 1B SX pump is in operation supplying both Units Identifies Train A as leaking train (previous abnormal or low pressure)

ISOLATE LEAKING SX TRAIN:

Dispatch operators to energize pump suction valves for leaking train A:

1SX001A at MCC 131X3 E4 (383' P15)

Close pump suction valves for leaking train A:

1SX001A (SX pump 1A within 30 minutes of leak initiation).

18 Op-Test No.: 201-302 _

Scenario No.: _N19-3_

Event No.: _ 5__

Event

Description:

Flooding in the AB from SX return header induces a loss of both A-train SX pumps (both 1A and 2A SX pumps trip). 1B SX pump requires a manual start Time Position Applicants Actions or Behavior US RF 6a) Recognize malfunction of TS Related Component (RF 6b) Locate/Determine Applicable LCOs LCO 3.7.8 Essential Service Water (SX) System (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME CONDITION A, One unit-specific SX train inoperable o

A.1 RA - Restore unit-specific SX train to OPERABLE status CT - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months CONDITION B, Opposite-unit SX train inoperable o

B.1 RA - Restore opposite-unit SX train to OPERABLE status CT - 7 days EVALUATOR NOTE:

After the actions for the 1A SX Pump Trip and auxiliary building flooding are complete and with lead examiners concurrence, insert the next event.

19 Op-Test No.: 201-302 _

Scenario No.: _N19-3_

Event No.: _ 6__

Event

Description:

Lightning strike causes U1 and U2 LOOP, with Bus 242 fault. 1A DG experiences a lockout Time Position Applicants Actions or Behavior CUE Line 0621 Bus Alive - NOT LIT OCB 4 -5 and OCB 5 OPEN Bus 141 Lock Out 1-21-A7 Bus 141 FD BKR 1412 TRIP - LIT 1-21-C7 BUS 141 OVERLOAD OR VOLT LOW - LIT BUS 143 ACB 1432 - OPEN Control Rod Bottom Lights - LIT EVALUATOR NOTE:

The crew will enter 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, when Bus 143 de-energizes and it is identified that Control Rods have dropped.

US Implement 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, and directs operator actions.

Notifies SM of 1BEP-0 entry.

Requests Emergency Plan evaluation.

ATC Verify Reactor Trip Rod bottom lights - ALL LIT Reactor trip & Bypass breakers - OPEN Manually trip the Reactor:

1PM05J 1PM06J Neutron flux DROPPING BOP Verify Turbine Trip Turbine throttle valves - CLOSED Turbine governor valves - CLOSED BOP Verify power to 4KV busses Bus 142 - ENERGIZED Bus 141 - NOT ENERGIZED WHEN time permits, o

THEN try to restore power to deenergized ESF bus per 1BOA ELEC-3, LOSS OF 4KV ESF BUS.

20 Op-Test No.: 201-302 _

Scenario No.: _N19-3_

Event No.: _ 6__

Event

Description:

Lightning strike causes U1 and U2 LOOP, with Bus 242 fault. 1A DG experiences a lockout Time Position Applicants Actions or Behavior ATC Check SI status SI actuated SI First OUT annunciator lit (1-11-B1, 1-11-C1, 1-11-D1, 1-11-E1)

SI ACTUATED lit (1-BP-4.1)

SI Equipment running (SI pumps running, CV Cold leg injection SI8801A/B open)

Determine if SI required:

o Check PZR pressure < 1829 psig o

Check Steamline pressure < 640 psig o

Check CNMT pressure > 3.4 psig If SI is required:

Actuate SI from both SI switches (1PM05J and 1PM06J) and continue in 1BEP-0 EVALUATOR NOTE:

A LOSS OF ALL AC will occur at approximately the transition decision from 1BEP-0, dependent on timing initial decision will be either to 1BEP ES-0.1, REACTOR TRIP RESPONSE, or 1BCA 0.0, LOSS OF ALL AC POWER. Actions for 1BCA 0.0 begin on the following page.

21 Op-Test No.: 201-302 _

Scenario No.: _N19-3_

Event No.: _ 7__

Event

Description:

1B DG fails to start automatically or manually. A loss of all AC power on Unit 1 occurs Time Position Applicants Actions or Behavior EVALUATOR NOTE:

The LOSS OF ALL AC occurs approximately 90 seconds after the start of lightning strikes and subsequent electrical perturbations.

EVALUATOR NOTE:

Record time loss of all AC power occurred. ______:______:______

CUE 1-20-A1, LOSS OF OFFSITE POWER (1-20-A1) - LIT 1-21-C8, DG1A TROUBLE/FAIL TO START (1-21-C8) - LIT 1-22-C8, DG1B TROUBLE/FAIL TO START (1-22-C8) - LIT BOTH 4KV ESF bus alive lights NOT LIT.

US Implement 1BCA-0.0, LOSS OF ALL AC POWER, and directs operator actions Notifies SM of plant status and procedure entry.

Requests evaluation of Emergency Plan conditions Notify Unit 2 to enter and perform actions of 2BCA 0.3.

ATC Perform immediate operator actions of 1BCA-0.0:

Manually trip reactor at 1PM05J or 1PM06J.

Verify reactor trip at 1PM05J:

Reactor trip & Bypass breakers - OPEN Neutron flux - DROPPING BOP Perform immediate operator actions of 1BCA 0.0:

Manually Isolate Steamlines at 1PM05J or 1PM06J:

Actuate main steamline isolation.

Verify all MSIVs and MSIV Bypass valves - CLOSED.

BOP Verify AF flow at 1PM06J:

AF flow >500 gpm (1B AF train only)

ATC Verify RCS isolated Letdown isolation valves - CLOSED 1CV8149A 1CV8149B 1CV8149 Letdown isolation valves:

1CV459 1CV460 Excess letdown isol valves - CLOSED:

1CV8153A 1CV8153B RCPs - NOT RUNNING 1CV459 and 1CV460 closed.

1CV8153A & B closed RCPs not running

22 Op-Test No.: 201-302 _

Scenario No.: _N19-3_

Event No.: _ 7__

Event

Description:

1B DG fails to start automatically or manually. A loss of all AC power on Unit 1 occurs Time Position Applicants Actions or Behavior EVALUATOR NOTE:

Record time AC power restored: ______:______:______

Time power restored - time power lost = ______:______:______ (<10 minutes)

[CT]

BOP

[TCA #3]

Try to restore power to any/both Unit 1 4KV ESF buses at 1PM01J:

o Manually start DGs o 1A Diesel Generator running with Bus 141 Locked Out o 1B Diesel Generator will NOT start Check 4KV ESF buses - NEITHER ENERGIZED:

Manually actuate SI 1PM05J 1PM06J Verify 1B DG starts and energizes Bus 142 Dispatch EO to depress EMERGENCY STOP PUSHBUTTON for affected 1A Diesel Generator Check DG support loads AUTOMATICALLY STARTED Verify Bus 132X and Bus 132Z - ENERGIZED Verify 1B SX Pump running EVALUATOR NOTE:

When the crew has restored Bus 142, verified the 1B SX pump runnning, and transitioned out of 1BCA 0.0 terminate the scenario

1 Facility: Byron_____________ Scenario No.: N19-4________

Op-Test No.: 2019-302_

Examiners: ___________________________ Operators:

Initial Conditions: 90% RTP, MOL, steady state conditions Turnover: 1A FW Pump OOS for oil change. Power reduced to 90% for partial 1BOSR 3.G.4-1 TV/GV surveillance on GV1. The turbine is currently in Single-Valve Mode and an equipment operator is standing by for surveillance performance.

Event No.

Malf. No.

Event Type*

Event Description Preload ZDI1FW01PA PTL ZDI1FW002A CLS ZDI1FW002A1 OFF ZDI1FW012A1 OFF ZDI1FW01PAB PTL FW027 0 ZDI1FW002A2 OFF 1A Feedwater Pump Out of Service 1

None N - BOP N - US Perform partial TV/GV 1BOSR 3.G.4-1 for GV1 2

PB2260 OFF ZLO1RY4652 OFF TH11B 0.1 C - ATC C - US TS - US PZR PORV 456 leak, requires isolating with block valve 1RY8000B 3

FW35C C - BOP C - US 1C HD Pump trip (requires starting standby HD pump) 4 ZDI1HSD020 CLS SW03B (preload)

C - BOP C - US TS - US 1B DG inadvertent auto-start with a failure of 1SX169B to open

[CT]

5 FW35A R - ATC R - US 1A HD pump trips (requires HD runback to 780 MW) 6 CV03 C - ATC C - US U1 BAT pump trips during runback (requires swapping to U0 BAT pump) 7 ED12B M - ALL DC Bus 112 fault (manual Rx trip due to inability to maintain SG level, loss of all main FW) 8 TC03 (preload)

ZDI1HSTG010 NORM (preload)

C - BOP C - US Turbine automatic and manual trip failure.

2 9

ZDI1AF01PA TRIP (preload)

ZLO1AF01PA3 ON ZLO1AF01PA2 OFF ZLO1AF01PA1 OFF FW43 ZAO1PIAF053 40 20 ZAO1IIAF01PA 50 20 C - BOP C - US 1A AF pump fails to auto start. Once manually started, Pump experiences a shaft shear after initially developing flow (run indication, no flow). 1B AF pump will not start due to a low lube oil pressure lockout. 1BFR H.1 entry and crew will have to implement bleed and feed. [CT-44]

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

3 SCENARIO N19-4 OVERVIEW The scenario will start at approximately 90% RTP, MOL, steady state conditions, for an impending partial performance of 1BOSR 3.G.4-1, TV/GV surveillance on the GV1. The 1A FW pump is OOS for an oil change.

Event 1:

The crew will be directed to perform a partial surveillance of 1BOSR 3.G.4-1, TV/GV for only the GV1. When the crew has completed the surveillance, continue to Event 2.

Event 2:

The crew will receive annunciator 1-12-C6 for PZR PORV 456 discharge temperature high. The crew will respond using BAR 1-12-C6 and/or BHC 1-RY-P to determine leakoff line temperature is high and mitigate the leak by closing the block valve 1RY8000B. The crew should enter LCO 3.4.11 Cond B. The crew may enter LCO 3.4.13 Cond A for RCS leakage, depending on the RCS leak rate through the PORV. At lead examiners discretion, continue to Event 3.

Event 3:

The crew will identify the 1C HD Pump tripped. The crew will take action to start the standby 1A HD pump per BAR 1 D2, HD PUMP TRIP, and 1BOA SEC-1, SECONDARY PUMP TRIP. The crew may opt to place the tripped 1C HD pump in PTL. After the crew has stabilized the secondary and at lead examiners discretion, continue to Event 4.

Event 4:

The crew will identify the 1B DG inadvertently started and the 1SX169B valve failed to open. When the crew attempts to open 1SX169A, the valve will not open and the DG will be running without SX cooling water. The crew will be required to secure the 1A DG prior to overheating. The crew will enter LCO 3.8.1 Cond B. At lead examiners discretion, continue to Event 5.

Event 5:

The crew will identify a trip of the recently started 1A HD pump. With only 1 running HD pump and no standby pump, the crew will initiate a HD runback via DEHC to 780 MW, IAW 1BOA SEC-1. The crew should leave rod control in auto, while adding pre-determined batches of boron per the HD runback REMA.

Event 6:

During the HD runback, the crew will experience a trip of the U1 BAT pump. Auto rod control will allow control rods to insert negative reactivity and maintain RCS temperature deviation. Rods should remain above the Lo-2 insertion limit during the transient, however, the crew should respond to annunciator 1-9-A6, BA Flow Deviation and swap to the U0 BAT pump such that they can borate to restore AFD (withdrawing control rods). The crew will use BOP AB-17 to swap to the U0 BAT pump. At lead examiner discretion, continue to Event 7.

Event 7:

The crew will experience a DC Bus 112 fault. A fault of DC Bus 112 will result in FRVs failing closed and the crew will be required to insert a manual Rx trip prior to a loss of SG level and Lo-2 trip. The crew will implement 1BOA ELEC-1 and take followup actions, including tripping the running FW pumps. The crew will go to 1BEP-0.

Event 8:

During the immediate actions of 1BEP-0, the crew will identify that the turbine failed to automatically trip and will take action to trip the turbine, per 1BEP-0 Step 3. The turbine will fail to trip from either the pushbutton or DEHC turbine trip soft key, and will need to be run back by closing the governor valves or actuating a Main Steamline Isolation.

4 Event 9:

The crew will identify that 1A AF pump fails to auto start, if a Lo-2 SG level is reached. After manually starting the pump, the pump experiences a shaft shear after initially developing flow (run indication, no flow). The crew will be in a loss of all FW scenario and must enter 1BFR H.1. The crew will be required to dispatch an EO to locally start 1B AF pump due to DC 112 failure. The pump will not start due to a low lube oil pressure lockout after manual start is attempted. The crew will proceed to feed and bleed.

Terminate the scenario after the crew has initiated feed and bleed and is depressurizing the RCS.

Critical Tasks:

CT: Secure 1B DG due to a lack of SX cooling water prior to equipment damage.

(K/A number - 064A2.01; importance 3.1/3.3)

CT-44: Establish RCS bleed and feed before either PZR PORV opens automatically as a result of a loss of heat sink (K/A number - 010A4.03; importance - 4.0/3.8)

5 SIMULATOR SETUP GUIDE:

Verify/perform TQ-BY-201-0113, Appendix A, Simulator Ready for Training Checklist.

Establish the conditions of IC 184, 90% power, BOL, equilibrium xenon o

(IC-27, 90% for TV/GV with GVs in Single Mode; with 1A FW pump Out of Service)

Place Simulator in RUN Initiate Smart Scenario:

o Open SMART SCENARIO (Extreme Ace icon) o Open file Scenario N192-4.ssf o

Load Initial values for instrument failures o

None applicable o

Click on the MODE button (near top of screen) and pick EXECUTE o

Click on the PLAY button (bottom left of screen)

Verify the following are included in the Smart Scenario:

6

7 Ensure mini-trend for TV/GV surveillance is displayed on DEHC monitor on 1CX05J with the following points:

ZT-MS5006A-A GV No.1, LVDT A ZT-MS5006A-B GV No.1, LVDT B Ensure 1A Heater Drain Pump is OFF Place the following control switches in PTL:

1A FW Pump - PTL 1A FW Pump Aux Oil Pump - PTL Place clearance order INFO/CAUTION tags on the following COMPONENTS:

1A FW Pump - PTL 1A FW Pump Aux Oil Pump - PTL 1FW012A - CLS 1FW002A - power removed Place Protected Equipment placards on the following control switches:

1B FW Pump 1C FW Pump Set AB Pot to 3.42 for 877 ppm boron Verify the Online Risk Placard is Green Ensure REMA is available at the Unit Desk Provide marked-up copies of the following documents:

Partial 1BOSR 3.G.4-1 TV/GV surveillance

8 Turnover Information Unit 1 is at 90% MOL 1086 MWe RCS boron concentration is 877 ppm Control bank D @ 195 steps 1A FW pump is OOS for an oil change; it is expected back in service in six hours.

Crew is to perform partial 1BOSR 3.G.4-1 TV/GV surveillance on GV1.

Online Risk is Green Protected Equipment:

1B FW Pump 1C FW Pump Unit 2 FC Train

9 INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1, Perform partial TV/GV 1BOSR 3.G.4-1 for GV1 If asked, EO reports standing clear of all turbine valves and in position to observe valve movement.

When asked, EO reports he has noted GV1 position.

When asked, EO reports GV1 stroked smoothly in the closed direction.

When asked, EO reports GV1 stroked smoothly in the open direction and has returned to original position.

Acknowledge as SM commencement and completion of procedure.

Event 2, PZR PORV 456 leak, requires isolating block valve 1RY8000B At Lead Evaluators cue, use Smart Scenario to insert PZR PORV 1RY456 leak by right clicking on the box titled, PZR PORV 1RY456, and select, Release As EO, if asked to remove power from 1RY8000B, use Smart Scenario to open the breaker for 1RY8000B leak by right clicking on the box titled, (IF ASKED) to remove power from 1RY8000B, and select, Release As SM/WEC acknowledge the failure, on line risk assessment, request for maintenance support, and IR requests.

Event 3, 1C HD Pump trip (requires starting standby HD pump)

At Lead Evaluators cue, use Smart Scenario to cause a trip of 1C HD pump by right clicking on the box titled, 1C HD Pump trip, and select, Release.

As SM/WEC, acknowledge the 1C HD pump trip, 1BOA SEC-1 entry, request for E Plan evaluation, and requests for on line risk assessment, maintenance support, and IR initiation.

If dispatched as EO, report 1C Heater Drain pump has ground overcurrent flag at breaker cubicle (Bus 157 Cub 5)

If dispatched as EO, report 1A Heater Drain pump running normally and an abnormal smell at the 1C HD pump.

10 Event 4, 1B DG inadvertent auto-start with a failure of 1SX169B to open At Lead Evaluators cue, use Smart Scenario to auto start 1B DG by right clicking on the box titled, 1B DG Auto Start, and select, Release.

As SM/WEC acknowledge the auto start of the 1B DG, evaluation of on line risk assessment, request for maintenance support, and IR requests.

As SM/WEC/U2, Unit 2 NSOs will perform 1BOSR 8.1.1-1, Normal and Reserve Offsite AC Power Availability Weekly Surveillance.

If dispatched as EO to investigate 1B DG, wait three minutes and delay report by stating, that the card reader is not functioning and that you cannot access the 1B DG room.

After the 1B Diesel Generator is stopped from the Control Room, report that security is present and that you can now access the 1B DG room.

If directed as EO, place 1B DG in Maintenance Outage, use Smart Scenario to secure 1B DG by right clicking on the box titled, (IF ASKED) Place 1B DG in Maintenance/Outage, and select, Release.

Event 5, 1A HD pump trips (requires HD runback to 780 MW)

At Lead Evaluators cue, use Smart Scenario to trip 1A HD pump by right clicking on the box titled, 1A HD PUMP TRIP, and select, Release.

As SM/WEC, acknowledge the 1A HD pump trip, 1BOA SEC-1 entry, request for E Plan evaluation, and requests for on line risk assessment, maintenance support, and IR initiation. Acknowledge Turbine Runback for loss of second HD pump.

If contacted, as Generation Dispatch, acknowledge the load reduction and estimated duration of power derate.

If dispatched as EO, report 1A Heater Drain pump has ground overcurrent flag at breaker cubicle (Bus 157 Cub 3)

If dispatched as EO, report 1B Heater Drain pump running normally.

11 Event 6, U1 BAT pump trips during runback (requires swapping to U0 BAT pump)

The next event will occur approximately two minutes after initiating the boration. Use Smart Scenario to verify U1 BAT Pump trip automatically inserts by monitoring the box titled, U1 BAT Pump trip.

As SM acknowledge the failure, on line risk assessment, request for maintenance support, and IR requests. Accept US recommendation for reactivity changes / strategy during the turbine runback.

As EO, report U-1 Boric Acid Transfer Pump motor is very hot to the touch.

As EO, if directed to check the breaker, MCC 133X3 is tripped and does not appear to be damaged. If breaker re-closure is requested, report breaker is closed. DO NOT DELETE MALFUNCTION. If pump restart is attempted, report the breaker is open.

If contacted as Unit 2, report Unit 0 AB pump is NOT supplying Unit 2 demands and is NOT electrically aligned to Unit 2.

If dispatched as EO to align Unit-0 AB pump to Unit 1 per BOP AB-17:

Verify w/MCR AB pump 1 + 0 C/S is in PTL (BOP AB-17, step F.1.a)

Verify w/MCR makeup C/S is in STOP (BOP AB-17, step F.1.b)

Then use Smart Scenario to align U-0 BAT pump by right clicking on the box titled, Connect BAT Pump 0, and select Release Wait approximately two minutes (monitor the delay in Smart Scenario box titled Connect BAT Pump 0), then perform the following:

Notify MCR AB pump 1 + 0 C/S may be placed in AFTER TRIP (BOP AB-17, step F.1.j)

Notify MCR Makeup C/S may be placed in AFTER TRIP (BOP AB-17, step F.1.k)

Report Unit 0 AB pump aligned for Unit 1 demands (BOP AB-17 step F.1 is complete) and all verifications are complete.

If contacted as Chemistry, report samples have been taken for the Boric Acid Tank

12 Event 7 & 8, DC Bus 112 fault (manual Rx trip due to inability to maintain SG level, loss of all main FW) with failure of Main Turbine to Trip automatically or manually At Lead Evaluators cue, use Smart Scenario to cause a loss of DC Bus 112 by right clicking on the box titled, DC bus 112 fault, and select, Release.

As SM, acknowledge the failure and requests for on line risk assessment, maintenance support, and IR initiation.

1BEP-0 ATTACHMENT B:

As EO, acknowledge dispatch to locally check DG operation.

As EO, acknowledge dispatch to locally check SFP level and temperature.

Event 9, 1A AF pump fails to auto start. Pump experiences a shaft shear after initial developing of flow (run indication, no flow). 1B AF pump will not start due to a low lube oil pressure lockout. Crew will have to implement bleed and feed.

After the 1A AF Pump is started; use Smart Scenario to verify shaft shear of the 1A AF pump automatically inserts by monitoring the box titled Subsequent shaft shear.

If dispatched as EO to start the 1B AF Pump, report back after 5 minutes that the 1B AF Pump will not start due to a low lube oil pressure alarm that is locked in and will not clear.

If dispatched as EO to investigate the 1A AF Pump after the shaft shear, report; the 1A AF pump motor is running -

believe the pump is not rotating.

As SM/WEC, acknowledge procedure entry and request for Emergency Plan evaluations.

As SM, Crosstie Train A AF from Unit 2, respond that 10CFR 5054.X and implementation of 1BFSG-3 will not be done at this time.

13 Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 1__

Event

Description:

Perform partial TV/GV 1BOSR 3.G.4-1 for GV1 Time Position Applicants Actions or Behavior CUE:

Directed at turnover to perform a partial surveillance of 1BOSR 3.G.4-1, TV/GV for only the GV1.

BOP o

REVIEW Limitation and Action E.6 as necessary to verify familiarity with the operational considerations listed for performance of Governor Valve Testing at Power.

VERIFY operators are stationed as necessary to directly observe the movement of the valves to be tested through one complete cycle from the running position.

RECORD Megawatt Reference Value from Reference Window on graphic 5501.

o VERIFY/PLACE the U-1 NDCT Turbine Trip Interlock switch to the OVERRIDE position, at 0PM01J.

Create minitrends for the valves to be tested.

ZT-MS5006A-A GV NO. 1, LVDT A ZT-MS5006A-B GV NO. 1, LVDT B o

Contacts EO to locally OBSERVE Governor Valve 1 (GV1) position.

RECORD Governor Valve 1 (GV1) position as displayed on the Operator Workstation (OWS).

RECORD U1 Generator Output (MW).

SELECT VALVE TEST on graphic 5501.

SELECT GV1 MS5006A on graphic 7000.

SELECT EXECUTE on popup labeled GOVERNOR VALVE 1.

VERIFY the GV1 begins to CLOSE and the other GVs begin to OPEN.

o Contacts EO to locally OBSERVE GV1 (1MS5006A) as it travels in the CLOSED direction.

VERIFY TESTING GV1 displays in red.

VERIFY GV1 goes full CLOSED and starts to go back OPEN after a short time delay (~ 1 minute).

VERIFY GV1 restores to approximately its original position and the red TESTING GV1 message disappears.

o Contacts EO to locally VERIFY GV1 has re-opened to approximately its original position.

o VERIFY (TSLB-2) Trip Status Light 14.1, TV-1 1MS5005A Closed, is NOT lit at 1PM04J.

SELECT EXIT EVALUATOR NOTE:

When actions have been completed for the partial surveillance of 1BOSR 3.G.4-1 and prior to restoration per step F.4, with lead examiners concurrence, proceed with the next event.

14 Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 2__

Event

Description:

PZR PORV 456 leak, requires isolating block valve 1RY8000B Time Position Applicants Actions or Behavior CUE:

Annunciators:

1-12-B2 PZR PORV OR SAF VLV OPEN 1-12-C6 PZR PORV DSCH TEMP HIGH 1-12-D6 PZR SAF RLF DSCH TEMP HIGH PORV temp rising on 1TI-463 Dual indication on 1RY455B on 1PM05J PZR pressure dropping on 1PM05J ATC Identify/report 1RY456 open below PZR pressure setpoint.

Implement BHC 1-RY-P, PRESSURIZER PRESSURE MALFUNCTION Attempt closing 1RY456 When it does not close, close 1RY8000B, PORV Block valve to stop depressurization US Monitor NSO prompt actions using BHC 1-Summary Notify SM of plant status, request IR and maintenance notification and risk evaluation EVALUATOR NOTE:

In addition to declaring LCO 3.4.11, the US may identify LCO 3.4.13 RCS Operational LEAKAGE condition A, though due to actions taken, the condition of leaking PORV may not exist long enough to provide calculable data.

US (RF 6a) Recognize malfunction of TS Related Valve (RF 6b) Locate/Determine Applicable LCOs LCO 3.4.11 Pressurizer Power Operated Relief Valves (PORVs)

(RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME CONDITION B - One PORV inoperable and not capable of being manually cycled.

o B.1

RA - Close Block valve

CT - 1 hours1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND o

B.2

RA - Remove Power from Block valve

CT - 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND o

B.3

RA - Restore PORV to OPERABLE

CT - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

Dispatch an operator to de-energize 1RY8000B at 132X2 (Closed and de-energized within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months )

BOP Monitor plant for effects and take any action directed by the US

15 Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 2__

Event

Description:

PZR PORV 456 leak, requires isolating block valve 1RY8000B Time Position Applicants Actions or Behavior EVALUATOR NOTE:

When actions have been completed for the PORV failure, with lead examiners concurrence, proceed with the next event.

16 Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 3__

Event

Description:

1C HD Pump trip (requires starting standby HD pump)

Time Position Applicants Actions or Behavior CUE Annunciators:

1-17-D2 HD PUMP TRIP.

1-17-D3 HD PUMP DSCH FLOW HIGH.

HD Tank level rising.

HD Pump discharge valves opening.

1C HD pump amber trip light LIT BOP Recognizes 1C HD pump tripped.

Refer to BAR 1-17-D2.

Reports failure to US.

Recognizes one Heater Drain Pump running.

Perform actions of BAR 1-17-D2 Start Standby HD pump Inform US to enter 1BOA SEC-1 Direct EO to investigate cause of HD pump trip o Complete shutdown of tripped pump per BOP HD-2 US Acknowledge 1C HD pump trip.

Acknowledge start of standby HD pump per BAR Contact SM of procedure entry, EAL evaluation, perform risk assessment, initiate IR, and contact maintenance to investigate/correct failure Implement 1BOA SEC-1, SECONDARY PUMP TRIP, Attachment C HD PUMP TRIP and direct operator actions of 1BOA SEC-1 Notify Chemistry to monitor secondary chemistry.

BOP VERIFY/START standby HD pump Verify HD pumps running - TWO running Check HD tank level stable or dropping and <72%

Restore plant conditions HD tank overflow closed in AUTO Running HD pumps parameters acceptable ATC Check Delta I within limits Check PDMS OPERABLE Check PDMS LIMIT EXCEEDED alarm NOT LIT Control Delta I near target US Notify SM of plant status, request IR and maintenance notification and risk evaluation o

Considers recommencing ramp ATC Monitor plant response to Secondary transient and take actions directed by the US EVALUATOR NOTE:

After standby HD pump has been started and with lead examiners concurrence,

17 Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 3__

Event

Description:

1C HD Pump trip (requires starting standby HD pump)

Time Position Applicants Actions or Behavior continue with the next event.

Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 4__

Event

Description:

1B DG inadvertent auto-start with a failure of 1SX169B to open Time Position Applicants Actions or Behavior CUE Annunciators 1-22-C8 DG 1B TROUBLE / FAIL TO START 1-22-D9 DG 1B RUNNING UNLOADED 1B Diesel Generator running

[CT]

BOP

[CT]

Recognizes the 1B DG starts Refers to BAR 1-22-C8 Refers to BAR 1-22-D9 Directs EO to check on 1B DG operation Recognizes 1SX169B NOT open Reports valve failure to US Attempts to open 1SX169B o

Recommends securing 1B DG attempt to open 1SX169B fails Secure 1B DG from MCR VERIFY the Control Mode Selector switch is in REMOTE.

PLACE the Diesel Gen A/B Start switch in STOP position.

CHECK the STOP light illuminated.

Direct EO to complete local actions per BOP DG-12 o

Recommends placing in Maintenance Outage US Monitor NSO actions per the BAR Notify SM of plant status, request IR and maintenance notification and risk evaluation US Direct securing 1B DG o

Direct placing in Maintenance Outage

18 Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 4__

Event

Description:

1B DG inadvertent auto-start with a failure of 1SX169B to open Time Position Applicants Actions or Behavior US (RF 6a) Recognize malfunction of TS Related Component (RF 6b) Locate/Determine Applicable LCOs LCO 3.8.1 AC Sources-Operating (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME CONDITION B - One required DG inoperable o

B.1 RA - Verify both opposite-unit DGs OPERABLE CT - 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter AND o

B.2 RA - Perform SR 3.8.1.1 for the required qualified circuits CT - 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND o

B.3 RA - Declare required feature(s) supported by the inoperable DG inoperable when its required redundant feature(s) is inoperable CT - 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from discovery of Condition B concurrent with inoperability of redundant required feature(s)

AND o

B.4.1 RA - Determine OPERABLE DG is not inoperable due to common cause failure CT - 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR o

B.4.2 RA - Perform SR 3.8.1.2 for OPERABLE DG CT - 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AND o

B.5 RA - Restore DG to OPERABLE status CT 14 days AND 17 days from discovery of failure to meet LCO EVALUATOR NOTE:

After response to 1B DG Auto Start is complete and with lead examiners concurrence, continue with the next event.

19 Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 5__

Event

Description:

1A HD pump trips (requires HD runback to 780 MW)

Time Position Applicants Actions or Behavior CUE 1-17-D2 HD PUMP TRIP 1-17-D3 PUMP DISCH FLOW HIGH HD Tank level rising.

1HD046A/B discharge valves opening.

1A HD pump amber trip light LIT.

BOP Recognizes 1A HD pump tripped.

Refer to BAR 1-17-D2.

Reports failure to US.

Recognizes one Heater Drain Pump running.

Recognizes standby HD pump is unavailable.

CREW

Identify entry conditions for 1BOA SEC-1, SECONDARY PUMP TRIP.

US Acknowledge 1A HD pump trip.

Contact SM of procedure entry, EAL evaluation, perform risk assessment, initiate IR, and contact maintenance to investigate/correct failure.

Implement 1BOA SEC-1, SECONDARY PUMP TRIP Attachment C "HD PUMP TRIP" and direct operator actions of 1BOA SEC-1.

BOP Recognizes standby HD pump NOT AVAILABLE.

Check HD pump status at 1PM03J.

ONLY 1B HD pump running.

Initiate HD runback on OWS graphic 5512 at 1PM02J or OWS drop 210.

Verify turbine load lowering.

Check HD Tank level at 1PM03J:

Level > 72% and rising.

Maintain HD tank level.

o Verify 1HD046A &B in AUTO.

o Open 1CB113A-D as needed.

o Manually open 1HD117, HD tank overflow valve.

o Lower turbine load as necessary to maintain HD tank level <72%.

o Evaluate note. If level cannot be maintained < 80%, then should Trip the RX and enter 1BEP-0.

EVALUATOR NOTE:

IF HD tank level can NOT be maintained less than 80%, THEN the crew should manually trip the reactor and GO TO 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, Step1.

20 Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 5__

Event

Description:

1A HD pump trips (requires HD runback to 780 MW)

Time Position Applicants Actions or Behavior BOP Check 1HD117, HD tank overflow valve in auto and closed at 1PM03J.

o Lower turbine load as necessary to close 1HD117.

Check 1B HD pump parameters at 1PM03J.

1B HD pump amps < 168 amps.

1B HD pump flow < 2965 KLB/HR.

o Lower turbine load as necessary to restore 1B HD pump parameters.

When complete, deactivate turbine runback:

Depress STOP HD RUNBACK softkey at OWS graphic 5512 at 1PM02J or OWS drop 210.

US/ ATC Check PDMS operable.

Annunciator PDMS INOPERABLE not lit (1-10-E8).

1BOL 3.h not implemented.

Annunciator PDMS LIMIT EXCEEDED not lit (1-10-D7).

ATC

Control I near target.

Operate control rods in manual as necessary to restore I to desired value at 1PM05J.

Monitor RCS parameters.

o If RCS pressure lowers < 2209 psig, notify US to enter TS 3.4.1, RCS DNB Limits.

o If control rods < low - 2 rod insertion limit, notify US to enter TS 3.1.6, Control Bank Insertion Limits.

ATC Initiate RCS boration at 1PM05J:

Determine required boric acid volume.

o Determine from Rema.

Determine desired boric acid flow rate.

Set 1FK-110 BA Flow Control to desired boration rate.

Set 1FY-0110 BA Blender Predet Counter to desired volume.

Place MAKE-UP MODE CONT SWITCH to STOP position.

Place MODE SELECT SWITCH to BORATE position.

Place MAKE-UP MODE CONT SWITCH to START.

Verify proper operation of valves and BA transfer pump (1CV110B open, Boric Acid Transfer Pump running, 1CV110A throttles open, proper BA flow indicated on recorder).

o Turn on PZR backup heaters.

EVALUATOR NOTE:

The next event will occur approximately two minutes after initiating the boration.

21 Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 5__

Event

Description:

1A HD pump trips (requires HD runback to 780 MW)

Time Position Applicants Actions or Behavior BOP Verify running CB pump recirc valves in auto.

1CB113A-D on running pumps.

o Dispatch operators to perform BOP HD-2 for 1B HD pump.

o Shutdown CD/CB pump (if started during procedure performance).

US Notify chemistry to monitor secondary plant chemistry.

Notify SM to perform risk assessment.

Check reactor power change > 15% in one hour.

o Notify chemistry to perform TS 3.4.16 sampling.

o Notify rad protection to perform TS sampling.

Contact Generation Dispatch to inform of load reduction and estimated duration of power derate.

EVALUATOR NOTE:

Next event is time initiated from the start of the boration. Two minutes after the boration begins, U1 BAT pump will trip.

22 Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 6__

Event

Description:

U1 BAT pump trips during runback (requires swapping to U0 BAT pump)

Time Position Applicants Actions or Behavior CUE 1-9-A6 BA FLOW DEVIATION 1-9-A4 BA XFER PUMP TRIP o

1CV110B closed ATC Identify/report stop of Unit 1 Boric Acid Transfer pump.

Refer to BAR 1-9-A6.

Dispatch operator to Unit 1 Boric Acid Transfer pump and breaker.

US Notify SM of Unit 1 Boric Acid Transfer pump stop.

Direct operators to align the Unit 0 Boric Acid Transfer pump for Unit 1 demand.

EVALUATOR NOTE:

The following steps are per BOP AB-17.

ATC Determine Unit 1 Boric Acid Transfer pump is unavailable Align 0AB03P, Boric Acid Transfer pump 0 for Unit 1 demands per BOP AB-17 Verify 0AB03P NOT supplying Unit 2 boric acid demands Verify 0AB03P NOT connected to Unit 2 power supply Place Boric Acid Transfer pump 1 + 0 C/S in PULL OUT at 1PM05J.

MAKE-UP MODE CONT SWITCH to STOP at 1PM05J.

Dispatch operator to align 0AB03P to Unit 1 per BOP AB-17 Place Boric Acid Transfer pump 1 + 0 C/S in AFTER TRIP at 1PM05J.

Return Unit 1 RMCS to AFTER START at 1PM05J.

o Request EST for Boric Acid Transfer Pump alignment EVALUATOR NOTE:

After the actions for the boric acid transfer pump swap are complete and with lead examiners concurrence, continue with the next event.

23 Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 7/8__

Event

Description:

DC Bus 112 fault (manual Rx trip due to inability to maintain SG level, loss of all main FW) with failure of Main Turbine to Trip automatically or manually Time Position Applicants Actions or Behavior CUE:

Annunciators:

1-22-E6 125V DC BATT 112 MAIN BRKR TRIP

1-22-E10 125V DC PNL 112/114 VOLT LOW

1-15-E7 FWIV NOT FULL OPEN

1-15-A4/B4/C4/D4 S/G 1A/1B/1C/1D FLOW MISMATCH FW FLOW LOW

1-15-A9/B9/C9/D9 S/G 1A/1B/1C/1D LEVEL DEVIATION HIGH LOW

DC Bus 112 voltage indicates 0 Volts

All FW Reg Valves closed

All FW Isolation Monitor lights LIT

All SG levels dropping ALL/

US

Identify/report Loss of DC Bus 112

Direct a manual reactor trip and operators perform immediate actions of 1BEP-0, REACTOR TRIP OR SAFETY INJECTION ATC Manually trips reactor US Implement 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, and directs operator actions.

Notifies SM of 1BEP-0 entry Requests Emergency Plan evaluation ATC Verify Reactor Trip Rod bottom lights - ALL LIT Reactor trip & Bypass breakers - OPEN Neutron flux DROPPING BOP Verify Turbine Trip All Turbine throttle valves - CLOSED All Turbine governor valves - CLOSED Determines Turbine is Not Tripped Attempt to trip with push button / OWS Panel (does NOT work)

Determines throttle and governor valves remain OPEN CLOSE all throttle and governor valves using OWS:

Select turbine MANUAL Select RAPID Select and hold GV lower arrow BOP Verify power to 4KV busses Bus 141 - ENERGIZED Bus 142 - ENERGIZED

24 Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 7/8__

Event

Description:

DC Bus 112 fault (manual Rx trip due to inability to maintain SG level, loss of all main FW) with failure of Main Turbine to Trip automatically or manually Time Position Applicants Actions or Behavior ATC Check SI Status Check if SI is required:

Any SI first out annunciator-LIT SI ACTUATED permissive light - LIT SI equipment - AUTOMATICALLY ACTUATED Either SI pump - RUNNING Either CENT CHG pump to cold leg injection isol valve - OPEN:

1SI8801A 1SI8801B o

Check if SI required o

PZR pressure less than or equal to 1829 PSIG o

Steamline pressure less than or equal to 640 PSIG.

o CNMT pressure greater than or equal to 3.4 PSIG.

IF SI is required, THEN manually actuate SI.

Manually actuate SI from 1PM05J and 1PM06J US Verify SI Actuated Directs BOP to perform 1BEP 0, Attachment B, SI VERIFICATION EVALUATOR NOTE:

BOP actions of 1BEP-0, Attachment B continue on page 27.

EVALUATOR NOTE:

The next event automatically initiate approximately 63 seconds after actions are taken in 1BEP-0, Step 6, to start the 1A AF pump.

25 Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 7/8/9__

Event

Description:

1A AF pump fails to auto start. Pump experiences a shaft shear after initial developing of flow (run indication, no flow). 1B AF pump will not start due to a low lube oil pressure lockout. Crew will have to implement bleed and feed.

Time Position Applicants Actions or Behavior EVALUATOR NOTE:

Depending on the crews progress through events, there are two possible transition points for the crew to exit 1BEP-0. The crew is expected to transition to 1BFR H.1 atstep 6 when 500 gpm AF flow can NOT be established or at step 12 when it is identified that SGs pressures are dropping in an uncontrolled manner.

ATC/BOP Verify AF system (Step 6):

AF pumps - BOTH RUNNING Determine neither pump is running Manually start 1A AF pump o

Dispatch an EO to locally start 1B AF pump AF isolation valves 1AF13A-H - OPEN AF flow control valves 1AF005A-H - THROTTLED AF flow - GREATER THAN 500 GPM Identify NO AF pumps running If feed flow greater than 500 gpm can NOT be established, then go to 1BFR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK, Step 1.

o Check SG tubes intact:

o Secondary radiation level - NORMAL AND STABLE o

Narrow range levels - NOT RISING IN AN UNCONTROLLED MANNER US Directs transition to 1BFR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK, Step 1 IF feed flow is less than 500 gpm prior to completion of required actions of Step 6.

EVALUATOR NOTE:

Actions for 1BFR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK begin on page 27.

ATC/BOP Check PZR PORVs and Spray Valves:

o PORVs - closed o

1RY455A o

1RY456 o

PORV isol valves - At least one energized o

PORV relief path - At least one available o

PORV in Auto o

Associated isol valve open o

Normal PZR spray valves closed o

1RY455B o

1RY455C ATC/BOP Adjust AF Flow:

o Lower total Feed Flow to approximately 600 gpm

26 Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 7/8/9__

Event

Description:

1A AF pump fails to auto start. Pump experiences a shaft shear after initial developing of flow (run indication, no flow). 1B AF pump will not start due to a low lube oil pressure lockout. Crew will have to implement bleed and feed.

Time Position Applicants Actions or Behavior ATC/BOP Check Steam Dumps:

o Check Steam Dump Available o

C-9 Permissive light NOT lit o

Determines C-9 is LIT o

Actuate MS Isolation o

CW pump - At least one running ATC/BOP Adjust Feed Flow and Steam release to control RCS Temperature and maintain Heat Sink o

Control RCS Temperature per the table o

Below 557 and dropping o

Stop dropping steam o

If cooldown continues, Reduce feed flow (to minimum of 500 gpm to stop cooldown) o If cooldown continues close MSIVs ATC/BOP Check if RCPs should be stopped:

o RCPs - any running o

ECCS flow - either:

o High head SI flow greater than 100 gpm o

SI pump discharge flow greater than 200 gpm o

RCS pressure less than 1425 psig o

Stop all RCPs ATC/BOP Check if Secondary Pressure Boundaries are intact:

o Check pressure in all SGs o

No SG pressure dropping in an uncontrolled manner o

No SG completely depressurized o

Identify SG pressure dropping in an uncontrolled manner US o

Direct transition to 1BEP-2, FAULTED STEAM GENERATOR ISOLATION Step 1.

US Direct transition to 1BFR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK.

US Implement 1BFR-H.1, Loss of Secondary Heat Sink Notify SM of procedure transition and request EAL evaluation

27 Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 7/8/9__

Event

Description:

1A AF pump fails to auto start. Pump experiences a shaft shear after initial developing of flow (run indication, no flow). 1B AF pump will not start due to a low lube oil pressure lockout. Crew will have to implement bleed and feed.

Time Position Applicants Actions or Behavior EVALUATOR NOTE:

Actions for 1BFR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK begin here.

CREW Check RCS pressure > SG pressure Check RCS temperature > 350°F Check if Bleed and Feed is Required:

Wide range level in any three SGs less than 27%

Determine that Bleed and Feed conditions are required Stop All RCPs GO TO Step 15

[CT]

[CT-44]

CREW Establish RCS Feed Path Actuate SI Verify RCS Feed Path:

Centrifugal Charging pumps - Both running Verify at least on Centrifugal Charging pump or SI pump are in operation Manually align valves to establish an RCS feed path Group 2 Cold Leg injection lights LIT Establish RCS Bleed Path Verify PZR PORV isol valves ENERGIZED 1RY8000A Verify PZR PORV isol valves BOTH OPEN 1RY8000A Open BOTH PZR PORVs 1RY455A Verify adequate RCS Bleed path Both PZR PORVS OPEN Identify 1RY456 failed to open Both PZR PORV isol valves OPEN Identify only 1RY8000A can be opened Open Reactor Head Vent valves on 1PM11J (only equipment energized by Bus 141 will be available for use) 1RC014A 1RC014C EVALUATOR NOTE:

The scenario will be terminated after the crew has initiated feed and bleed and is depressurizing the RCS; Bleed path consists of PZR PORV 1RY8000A, and RX head vent valves 1RC014A and 1RC014C.

28 Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 7/8__

Event Description : DC Bus 112 fault (manual Rx trip due to inability to maintain SG level, loss of all main FW) with failure of Main Turbine to Trip automatically or manually Time Position Applicants Actions or Behavior EVALUATOR NOTE: 1BEP-0, Attachment B, SI VERIFICATION actions begin on this page.

BOP Attachment B action Verify ECCS pumps running (Train A)

CENT CHG pumps RH pumps SI pumps BOP Attachment B action Verify ECCS valve alignment Group 2 Cold Leg Injection monitor lights lit BOP Attachment B action Verify ECCS flow HHSI flow >100 gpm RCS pressure NOT <1700 psig If RCS pressure <1700 psig check SI pp flow > 200 gpm BOP Attachment B action Verify RCFCs running in Accident Mode - Group 2 RCFC Accident Mode status lights lit Verify CNMT isolation Phase A - Group 3 CNMT isolation monitor lights lit Verify CNMT Ventilation isolation - Group 6 CNMT Vent Isol monitor lights lit Verify CC Pumps running Verify SX Pump running Check if Main Steamline Isolation is required o

Check SG pressure < 640 psig o

Check CNMT pressure > 8.2 psig If either condition is met, then verify MSIVs and MSIV Bypass valves closed Check if CS is required (NOT required)

BOP Attachment B action Verify FW isolated FW pumps tripped FW isolation monitor lights lit FW pumps discharge valves closed 1FW002A-C Trip all running HD pumps

29 Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 7/8__

Event Description : DC Bus 112 fault (manual Rx trip due to inability to maintain SG level, loss of all main FW) with failure of Main Turbine to Trip automatically or manually Time Position Applicants Actions or Behavior BOP Attachment B action Verify both DGs running (Train A)

SX valve open 1SX169A Dispatch operator locally to check operation BOP Attachment B action Verify Generator Trip GCB 3-4 and OCB 4-5 open PMG output breaker open BOP Attachment B action Verify Control Room ventilation aligned for emergency operations:

Control Room Outside Air Intake radiation monitors < High Alarm setpoints Operating VC train equipment running Train A Supply fan 0A Return fan 0A M/U fan 0A Chilled water pump 0A MCR chiller 0A Operating VC train dampers M/U fan outlet damper NOT full closed 0VC24Y VC train M/U filter light LIT Operating VC train Charcoal Absorber aligned for train A 0VC43Y closed 0VC21Y open 0VC22Y open Operating VC train M/U filter alignment for train A (SI/Hi Rad) 0VC25Y - OPEN 0VC312Y-CLOSED Control Room pressure greater than +0.125 inches water on 0PDI-VC038

30 Op-Test No.: 2019-302 _

Scenario No.: _N19-4_

Event No.: _ 7/8__

Event Description : DC Bus 112 fault (manual Rx trip due to inability to maintain SG level, loss of all main FW) with failure of Main Turbine to Trip automatically or manually Time Position Applicants Actions or Behavior BOP Attachment B action Verify Auxiliary Building ventilation aligned Two inaccessible filter plenums aligned Plenum A fan 0VA03CA running Damper 0VA022Y not fully closed Damper 0VA020Y closed Plenum C fan 0VA03CF running Damper 0VA072Y not fully closed Damper 0VA438Y closed Check Aux Building Supply and Exhaust fans One Exhaust Fan running for every Supply Fan running BOP Attachment B action Verify FHB ventilation aligned Train B fan 0VA04CA running 0VA055Y open 0VA062Y not fully closed 0VA435Y closed BOP Attachment B action Maintain UHS Basin level > 80%

Initiate periodic checking of Spent Fuel Cooling Dispatch operator to locally check SFP level and temperature Notify Unit Supervisor of Manual actions taken Failed equipment status Attachment B completed CREW Attachment B action Shutdown unnecessary plant equipment As time allows refer to 1BGP 100-4T4, REACTOR TRIP POST RESPONSE GUIDELINE As time allows refer to 1BGP 100-5, PLANT SHUTDOWN AND COOLDOWN

ML20054A536

Text

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Navigation menu

Search