Text

Proposed_Dynamic_Simulator_Scenarios_Forms_3.3-1&2_DC-Cook_2022
	ML22250A704
Person / Time
Site:	Cook
Issue date:	06/30/2022
From:	Ted Wingfield; NRC/RGN-III/DRS/OLB
To:	; Indiana Michigan Power Co
	Wingfield T
Shared Package
ML21263A039	List: ML22250A690; ML22250A691; ML22250A692; ML22250A699; ML22250A703; ML22250A704; ML22250A707;
References
	Download: ML22250A704 (87)
	v • d • e

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-1 Page 1 of 1 Form 3.3-1 Scenario Outline Facility: DC COOK 1 & 2 Scenario #: NRC2022-1 Scenario Source: New Op. Test #: Cook 2022 Examiners:

Applicants/

Operators:

Initial Conditions: 100% Power Turnover: The plant is at 100% power and the crew is directed to maintain power at 100% and swap Stator Cooling Water Pumps for maintenance when clearance is ready.

Critical Tasks**: 1. Manually trip the reactor

2. Energize at least one AC emergency Bus Event No.

Malf. No.

Event Type*

Event Description**

1 U2_QLC451 I-RO QLC-451, VCT Level Transmitter, fails Low 2

U2_FFC210 I-BOP MC-BOP TS FFC-210, Feed Water Flow Instrument, SG #21 Channel 1, fails High 3

U2_NFP210 TS RCS Flow Instrument fails low 4

N-BOP Swap Stator Cooling Water Pumps 5

U2_TP03 C-BOP R-RO MC-RO Stator Water Cooling leak Perform 2%/min Rapid Power Reduction Control VCT level in manual 6

U2_NPP151 U2_RP16A I-RO Pressurizer pressure controlling channel fails high with mechanical failure of one spray valve open (EOP entry) 7 U2_RCO1A U2_101TD6 U2_101TA4 M-CREW C-CREW LBLOCA following Rx trip RHR Pumps Auto Start failure Transfer to Cold Leg Recirculation

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor, (TS)Tech Spec, (MC)Manual Control

- Details on subsequent pages

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 1 of 24 Form 3.3-2 Required Operator Actions Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Event No.: 1 Event

Description:

QLC-451 will fail low resulting in VCT makeup. The RO will take actions per 2-OHP-4022-IFR-001 to stop the auto makeup by placing the Reactor Coolant Blend Control switch in STOP and manually control VCT level. The Crew will transition to 2-OHP-4022-013-017, VCT Instrument Malfunction.

Event Termination: When actions of 2-OHP-4022-013-017 are complete up to energizing the RWS relay, and TRM has been referenced, or at Lead Evaluator discretion, the event is complete.

Symptoms/Cues:

VCT Level 2-QLC-451 fails to 0%

Annunciator 209-49, VCT LEVEL LOW Automatic VCT makeup starts Time Position Applicants Actions or Behavior RO Recognizes and reports instrument failure/annunciator on Panel #209 indicative of a VCT Level instrument failure (Drop 49).

US Direct RO and BOP to perform immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response RO Reports instrument malfunction and performs the immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response, from memory:

1. Determines a VCT Level Control issue exists

2. Determines both VCT level channels indicate <78%

3. Determines an automatic VCT makeup is in progress

4. Stops VCT makeup by placing the Reactor Coolant Makeup Blend Control Switch in STOP/NEUTRAL Crew Performs plant stability checks. (Order not important)

RO

1. Rx Power

2. RCS Temp

3. RCS Pressure

4. Pressurizer level

5. AFD BOP

1. Turbine Load

2. SG Level

3. MFP DP

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 2 of 24 Time Position Applicants Actions or Behavior US Enters and directs actions of 2-OHP-4022-IFR-001, Instrument Failure Response procedure:

1. Verifies RO immediate actions taken from memory

2. Assigns manual control bands for VCT level and pressure (nominal 15-78% Level and 15-35 psig Pressure)

3. Verifies no unexpected control rod motion occurred

4. Transitions to 2-OHP-4022-013-017, VCT Instrument Malfunction US Enters and directs actions of 2-OHP-4022-013-017, VCT Instrument Malfunction:

1. Determine 2-QLC-451 is failed

2. Direct RO to operate the Boric Acid Blender in Manual as required to maintain VCT level greater than 15%

3. Notify SM/MTI to initiate actions to energize associated RWS Relay in accordance with Attachment A.

4. Direct Work Control to prepare Caution tags as directed in 2-OHP-4022-013-017 NOTE: Action to energize the RWS relay requires access to the SSPS Engineering Work Station which is not physically modeled in the simulator and will not be performed during the scenario.

US Refers to TRM 8.1.1, Boration Systems - Operating:

Condition A Required Action A.1.

o Enters action statement to restore to operable status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 3 of 24 Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Event No.: 2 Event

Description:

Feed Flow Channel FFC-210 will fail high, resulting in lowering S/G levels in #21 SG. The BOP will take manual control of #21 FRV to stabilize levels per 2-OHP-4022-IFR-001. The crew will transition to 2-OHP-4022-013-015, Feed Water Flow Instrument Malfunction, for a Feed Flow channel failure to return level control to auto. The US should identify entry into the following Technical Specification conditions/actions: 3.3.1. Condition A Required Action A.1, 3.3.1.

Condition D Required Action D.1 (Based on Table 3.3.1-1 Function 15).

Event Termination: When actions of 2-OHP-4022-013-015 are complete up to bistable tripping and #21 SG FRV is in automatic or at Lead Evaluator discretion, the event is complete.

Symptoms/Cues:

2-FFC-210, 21 SG Channel 1 Feed Flow failed to 4E6 pph 2-FRV-210, 21 SG Feed Water Regulating Valve, throttles closed Feed Flow indication lowers on 2-FFC-211 21 SG level lowers Annunciator 213-3, SG1 WATER LEVEL LOW DEVIATION (possible based on timing of Crew actions)

Time Position Applicants Actions or Behavior BOP Recognizes and reports instrument or control system failure/annunciator on Panel #213 Drop 3, SG1 WATER LEVEL LOW DEVIATION US Direct RO and BOP to perform immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response BOP Reports instrument malfunction and performs the immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response, from memory:

Determines a SG Level Control condition exists Determines #21 SG NR level is not stable at or trending to 44%

and places FRV-210, SG #21 MFW Reg. Valve controller in manual Raises controller output to match the operable feed flow channel with steam flow.

Restores SG #21 level to program.

Determines SG PORVs all closed Determines MFP Differential Pressure is controlling at appropriate differential pressure for current actual steam flow.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 4 of 24 Time Position Applicants Actions or Behavior Crew Performs plant stability checks. (Order not important)

RO

1. Rx Power

2. RCS Temp

3. RCS Pressure

4. Pressurizer level

5. AFD BOP

1. Turbine Load

2. SG Level

3. MFP DP US Enters and directs actions of 2-OHP-4022-IFR-001, Instrument Failure Response procedure:

1. Verifies BOP immediate actions taken from memory

2. Assigns manual control band for #21 SG level (nominal 40-48%)

3. Verifies no unexpected control rod motion occurred

4. Transitions to 2-OHP-4022-013-015, Feed Water Flow Instrument Malfunction US Enters and direct actions of 2-OHP-4022-013-015, Feed Water Flow Instrument Malfunction BOP Performs the following actions as directed:

1. Determines 2-FFC-210 is failed

2. Places feed water flow selector switch 2-FS-510-C in CHAN 2 position

3. Manually adjusts #21 SG FRV to null the controller (control level at 44%)

4. Place #21SG FRV in automatic US Identify entry into Technical Specification/Technical Requirements Manual Conditions T.S 3.3.1 Condition A Required Action A.1 T.S 3.3.1 Condition D Required Action D.1 (Based on Table 3.3.1-1, Function 15).

TRO 8.3.6 Condition A Required Action A.1 TRO 8.7.14 Condition B Required Actions B.1 and B.2 US Initiates corrective action for failed channel

a. Notifies management and WCSRO

b. Directs RO/BOP to generate work request US Notifies SM/MTI to Initiate actions to trip Bi-stables associated with FFC-210 FW Flow Failure per Attachment A-1 of 2-OHP-4022-013-015.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 5 of 24 Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Event No.: 3 Event

Description:

The event is a low failure of an RCS flow detector. There will be no automatic plant response to the event. The crew should diagnose the failure and implement 2-OHP-4022-013-008, RCS Flow Instrument Malfunction. The US should identify entry into the following Technical Specification conditions: 3.3.1. Condition A Required Action A.1, 3.3.1. Condition D Required Action D.1 (Based on Table 3.3.1-1 Function 10).

Event Termination: When actions of 2-OHP-4022-013-008 are completed up to bistable tripping, the event is complete.

Symptoms/Cues:

Loop 1 Flow indication NFP-210 - fails low.

Annunciator 207-1, LOOP 1 RCP 1 TRIP OR FLOW LOW.

Time Position Applicants Actions or Behavior RO Acknowledge the alarm and determine 21 RCP is operating normally.

RO/BOP Perform actions of the annunciator response procedure for 207-1:

Determine that a RCP has not tripped and entry into E-0 is not required Determine the alarm is due to an instrument malfunction Inform the US to refer to Technical Specification LCOs 3.3.1, 3.3.2, 3.4.1, 3.4.4, 3.4.5, 3.4.6, and 3.4.7 US Determine no condition entries for Technical Specification LCOs 3.3.2, 3.4.1, 3.4.4, 3.4.5, 3.4.6, and 3.4.7 US Implement 2-OHP-4022-013-008, RCS Flow Instrument Malfunction:

Determine Loop 1 channel NFP-210 is the failed channel Identify entry into the following Technical Specification conditions:

o 3.3.1. Condition A Required Action A.1 o 3.3.1. Condition D Required Action D.1 (Based on Table 3.3.1-1 Function 10).

Contact SM/MTI to request MTI assistance for bistable tripping.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 6 of 24 Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Event No.: 4 Event

Description:

The crew will receive a phone call from Work Control that the clearance is ready for the running Stator Cooling Water Pump. The BOP will swap Stator Cooling Water Pumps per 2-OHP-4021-059-001, Generator Stator Cooling System Operation.

Event Termination: When actions of 2-OHP-4021-059-001 are completed, the event is complete.

Symptoms/Cues:

Time Position Applicants Actions or Behavior BOP Direct an AEO to be stationed at the Stator Cooling Water Pumps to monitor for equipment start BOP Verify the Stator Cooling Water System is in normal operation BOP Start the West Stator Cooling Water Pump 2-PP-113W BOP Verify system flow has stabilized and stop the East Stator Cooling Water Pump BOP Place the control switch for the East Stator Cooling Water Pump in AUTO BOP Verify stable system flow by checking Deionizer flow on 2-CFI-630 is 0-80 GPM and Stator Cooling Water flow on 2-CFC-610 is 845 GPM

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 7 of 24 Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Event No.: 5 Event

Description:

After several minutes, a small leak will occur on the Stator Cooling Water system, and a phone call will be received from the field reporting a crack on a Stator water system pipe that cannot be isolated. The BOP will respond to the Stator Cooling Water Tank low pressure alarm per the ARP.

The SM will direct a plant shut down at 2% / minute using the Rapid Power Reduction Response procedure, 2-OHP-4022-001-006. After initiation of normal boration, the RO will be required to take manual action to control VCT level to maintain VCT level and pressure within previously established manual control bands.

Event Termination: When power has been reduced sufficiently at Lead Evaluator discretion, the event is complete.

Symptoms/Cues:

2-GPI-263, Stator Cooling Water Tank Pressure lowers slowly Annunciator 221-39, STATOR CLG WATER TANK PRESS HI OR LO after 2-3 minutes Stator Cooling Water Tank makeup valve 2-CRV-630 opens and will restore level in the tank Time Position Applicants Actions or Behavior NOTE: Not all actions listed below may be performed based on the amount of load reduction required to evaluate Crew competency based on Lead Evaluator discretion.

BOP Recognizes and reports annunciator on Panel #221 Drop 39, STATOR CLG WATER TANK PRESS HI OR LO

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 8 of 24 Time Position Applicants Actions or Behavior BOP NOTE: The BOP should determine based on makeup valve operation that pressure reduction is caused by water leakage and that adding hydrogen is not required. If the BOP determines that pressure should be raised, actions listed below will be performed.

Adjust Stator Cooling Water Tank pressure to ~20.5 psia using 2-OHP-4021-059-001, Generator Stator Cooling Water System Operation using one or both of the following options:

1. Raise pressure in batches

a. Verify stator cooling water system is in service and a hydrogen atmosphere has been previously established

b. Direct AEO to open 2-H-159, Pressure Regulator GRV-256 inlet valve and to throttle open 2-SCS-171, Generator Hydrogen & Carbon Dioxide to Generator Stator Cooling Water Storage Tank Shutoff valve

c. May also direct AEO to adjust 2-GRV-256 regulator

d. When desired pressure is reached, direct AEO to close 2-SCS-171 and 2-H-159

2. Control pressure automatically:

a. Verify stator cooling water system is in service and a hydrogen atmosphere has been previously established

b. Direct AEO to open 2-H-159, Pressure Regulator GRV-256 inlet valve and to open 2-SCS-171, Generator Hydrogen &

Carbon Dioxide to Generator Stator Cooling Water Storage Tank Shutoff valve

c. Direct the AEO to adjust 2-GRV-256 to maintain the desired pressure.

US Enters 2-OHP-4022-001-006, Rapid Power Reduction US Conduct Control Room Brief for the Rapid Power Reduction utilizing Attachment C, Rapid Power Reduction Briefing Guide:

Direct power reduction at a rate of 2%/minute to a final power of 17% (or shut down)

Direct initial boration rate of 20 GPM Direct initial turbine unloading rate of 25.1 MW/minute Direct final turbine load target of 213 MW Direct total amount of boric acid of ~800 gallons Direct contingency actions US Direct RO to initiate boration using Attachment D, Borating the RCS using the Normal Boration flow path

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 9 of 24 Time Position Applicants Actions or Behavior RO Initiates boration using Attachment D:

Verify charging is > 75 gpm on 2-QFI-200 CLOSE 2-QMO-225, EAST CCP Mini-Flow (CCP ELO)

Verify Boric Acid Blender is aligned for Automatic Determine RC Makeup Blend control switch is in STOP (NOTE:

Switch placed in stop due to VCT level channel failure event).

Place RC Makeup Blend Control Mode switch in BORATE.

Adjust BA Controller/Totalizer to the desired flow rate and amount.

Place RC Makeup Blend control switch in START.

Divert letdown flow by performing one of the following:

o Manually adjust 2-RU-28, VCT Level Control to divert some or all letdown flow to the CVCS Holdup Tank (as required) to maintain VCT level and pressure.

o Place 2-QRV-303, VCT/Holdup Tank Inlet Selector, in the CVCS HU Tank position 2-OHP 4022-001-006 Attachment D Table (for evaluator reference):

BOP Check both Main Feed Pumps operating in D/P control RO/BOP Verify all Pressurizer Backup heaters energized NOTE: At a power reduction rate of 2%/minute, it is expected that AFD will remain within the acceptable region during the power reduction. The Crew should discuss prior to initiating the load decrease the US expectations for maintaining AFD in the target band during the load decrease. If AFD moves outside the target band with power >90%, the US should enter T.S. 3.2.3 Condition A Required Action A.1. If AFD is not within acceptable operation limits with power between 50% and 90%,

the US should enter T.S. 3.2.3 Condition C Required Action C.1.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 10 of 24 Time Position Applicants Actions or Behavior US Direct BOP to initiate power reduction using Attachment F, Adjusting Main Turbine Load BOP Performs Attachment F Adjusting Main Turbine Load Places MW feedback IN Enters TARGET Load into HMI (Selected value from Attachment C brief)

Enters RAMP RATE into HMI (Selected value from Attachment C brief)

Depresses GO to Lower Turbine load using HMI.

Adjust Tavg and Tref inhibit setpoints as desired, not to exceed

+/- 5 ºF Attachment F tables (for evaluator reference):

RO Check Control Rods in Automatic to maintain Tavg BOP Transfer MFPs steam supply to Main Steam:

Determine MFPs running on Reheat Steam Raise Main Steam Supply Pressure to running MFPs until pressure is 15 psig above Reheat Steam Pressure CREW May place a MFP in Speed Control and ramping down the speed as necessary to maintain DP as required (Procedurally allowed but not expected).

US Notify Load Dispatcher of final projected power level

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 11 of 24 Time Position Applicants Actions or Behavior BOP Remove Moisture Separator Reheaters from service using Attachment A:

Close MSR Bundle isolation valves Close MSR steam supply valves Open reheater startup drains Close Reheater Coil Drain Isolations to No. 6 heaters BOP Initiate actions of Attachment G, Operation of Secondary Plant Equipment, as Control Room staffing allows RO Monitor AFD during power reduction and report if AFD is outside the target band

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 12 of 24 Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Event No.: 6 Event

Description:

During the power reduction Pressurizer Pressure instrument NPP-151 fails upscale causing both spray valves to open. The crew should diagnose the instrument failure, perform immediate actions for 2-OHP-4022-IFR-001, Instrument Failure Response, and attempt to take manual control of pressurizer spray to stabilize the plant. One PZR spray valve will fail open and will not close when attempts are made via 2-OHP-4022-IFR-001 actions. The crew will take actions to trip the reactor and stop #22, 23 & 24 RCPs per IFR-001.

Event Termination:

When the Crew transitions to 2-OHP-4023-ES-0.1, Reactor Trip Response (if SI not actuated), or completes step 4 of E-0 (if SI actuated), the event is complete.

Symptoms/Cues:

Controlling Pressurizer Pressure channel 2-NPP-151 fails high Pressurizer heaters de-energize 2-NRV-163 & 2-NRV-164, Pressurizer Spray Valves, indicate full open (Red light on, Green light off) 2-NRV-163 will remain open regardless of operator actions Pressurizer pressure lowers CH 1 PRESSURE HIGH-HIGH status light ENERGIZED on 2-SML-14 Annunciators:

208-6, PRZ PRESS HIGH-HIGH 208-7, PRZ PRESS HIGH DEV After RCPs 22, 23, & 24 are stopped, 21 SG level will lower and steam flow will rise when steam dump valves open since it is the only active loop.

NOTE: If the Crew delays response to the failed open spray valve to trip the reactor and trip 22, 23, and 24 RCPs, an automatic SI may actuate on low pressurizer pressure.

Time Position Applicants Actions or Behavior RO Recognizes and reports instrument failure/Annunciator Panel 208 alarms and identifies that both spray valves are open US Direct RO and BOP to perform immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 13 of 24 Time Position Applicants Actions or Behavior RO Reports instrument malfunction and performs the immediate actions of OHP-4022-IFR-001, Instrument Failure Response from memory:

Determines pressurizer pressure is not stable at or trending to 2235 psig Places PRZ pressure master controller OR both spray valve controllers to manual and attempts to lower controller output to close spray valves.

Determine that one spray valve cannot be closed and inform the US that a reactor trip is required US Directs RO to trip the reactor and direct the RO and BOP to perform immediate actions of E-0, Reactor Trip or Safety Injection RO Performs a manual reactor trip, verifies reactor trip, and then trip #22,

23, and #24 RCPs RO/BOP Performs the immediate actions of E-0 from memory:

1. Checks reactor trip - Determines reactor Trip and Bypass breakers Open, all rods < 10 steps, neutron flux lowering

2. Checks turbine trip - Determines Turbine Stop Valve Closed Status Lights Lit

3. Checks power to AC emergency buses - Determines all emergency buses T21A, T21B, T21C, and T21D energized and both annunciators clear for Open Phase

4. Checks safety injection status - Determine SI Status Lights - SI Status Lights NOT Lit (QMO-225/226 white lights NOT Lit) and SI not required based on:

PZR Pressure > 1775#

CNTMNT Pressure < 1.0#

SG Pressure > 500#

STM Line DP < 100psid US Verify performance of immediate actions using procedure 2-OHP-4023-E-0 US Transition to 2-OHP-4023-ES-0.1, Reactor Trip Response, if SI did not actuate, or continues with E-0 step 5 if SI is actuated.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 14 of 24 Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Event No.: 7 Event

Description:

The major event will begin once OHP-4023-E-0 immediate actions are complete and transition is made to ES-0.1. A LBLOCA will occur requiring transition back to E-0. Auto RHR pump start will fail to occur requiring manual actuation. The Crew will complete E-0, transition to 2-OHP-4023-E-1, Loss of Reactor or Secondary Coolant, and transition to 2-OHP-4023-ES-1-3, Transfer to Cold Leg Recirculation.

Event Termination: When both RHR pumps and both CTS pumps have been transferred to recirculation mode, the event is complete.

Symptoms/Cues:

RCS pressure and pressurizer level lower rapidly Containment pressure rises rapidly to >2.8 psig Automatic SI/CI Phase A actuates Automatic CTS/CI Phase B actuates Automatic Steam Line isolation actuates Neither RHR pump auto starts All other equipment operates as expected Time Position Applicants Actions or Behavior US Direct transition back to 2-OHP-4023-E-0 Ensures immediate actions of 2-OHP-4023-E-0 are completed Directs subsequent actions of 2-OHP-4023-E-0.

RO/BOP Performs the immediate actions of E-0 from memory:

1. Checks reactor trip - Determines reactor Trip and Bypass breakers Open, all rods < 10 steps, neutron flux lowering

2. Checks turbine trip - Determines Turbine Stop Valve Closed Status Lights Lit

3. Checks power to AC emergency buses - Determines all emergency buses T21A, T21B, T21C, and T21D energized and both annunciators clear for Open Phase

4. Checks safety injection status - Determine SI Status Lights Lit (QMO-225/226 white lights Lit)

US/RO Foldout Page - RCP Trip Criteria:

Stop all running RCPs based on Containment Isolation Phase B actuated OR RCS is < 1300 psig and CCP/SI pump running

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 15 of 24 Time Position Applicants Actions or Behavior CT1: Manually start at least one RHR Pump Initiating Cue: Both of the following:

o Indication that RHR pumped injection is required (SI actuated status light lit and RCS pressure indicating below shutoff head of the RHR pumps) o Indication that no RHR pump flow is injecting into the core (Pump breaker indicating lights and RHR flow indication)

Performance Feedback: Indication that at least one RHR pump is injecting (Breaker indicating lights and RHR flow indication).

Success Path: Both RHR pumps are available for manual start. Pumps may be started as a backup action for a failed automatic action or as directed in E-0 Attachment A.

Measurable Performance Standard: Manually start at least one RHR pump before transition out of E-0 and completion of E-0 Attachment A.

RO/BOP Any time after completion of immediate actions from memory:

Determine both RHR Pumps should have automatically started and manually start both RHR pumps. (CT1 related action)

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 16 of 24 Time Position Applicants Actions or Behavior RO/BOP Complete actions of E-0 through steps 5-19 as directed:

5. Check if Main Steam line isolation is required-Determine isolation is required based on containment pressure >2.8 psig and determine all SG stop valves are closed.

6. Check if CTS is required-Determine containment pressure has not remained below 2.8 psig and perform the following:

a. Determine CTS is actuated, CTS Monitor Lights lit on 2-SML-9A and 2-SML-9B, and spray additive tank flow is indicated on 2-IFI-200

b. Determine CI Phase B is actuated

c. Stop all RCPs if not previously stopped

d. Place lower containment vent unit fans in OFF

e. Place control rod drive mech fans in STOP

7. Implement Attachment A while continuing with E-0 (actions listed below)

8. Check if ruptured SG is suspected-Determine no SG NR levels rising in an uncontrolled manner

9. Check AFW pumps running-Determine all three AFW pumps are running

10. Check total AFW flow >240 x103 PPH

11. Minimize unnecessary RCS cooldown-Determine SG NR levels are not >13% and reduce total AFW flow to between 240 x103 PPH and 450 x103 PPH and control NR level between 13% and 50%

12. Check AFW pump discharge valves-Determine valves are throttled

13. Check FW isolation-Determine both MFPs tripped, both MFP discharge valves closed, all four FRVs closed, and all four feed water isolation valves closed

14. Check RCS temperature-Determine RCS temperature is lowering, no dumping of steam is occurring, 2-DRV-407 is closed, AFW flow is >240 x103 PPH, and SG stop valves are already closed.

15. Check pressurizer PORVs and spray valves-Determine PORVs closed, one spray valve is open with all RCPs off, and PORV block valves are all energized.

16. Check if RCPs should be stopped-Determine criteria are satisfied to stop RCPs and stop RCPs is not previously secured.

17. Check if SG secondary pressure boundaries are intact-Determine no SG pressure is lowering in an uncontrolled manner nor completely depressurized

18. Check if SG tubes are intact-Determine no SG NR levels rising in an uncontrolled manner and no abnormal secondary radiation

19. Check if RCS is intact-Determine RCS is not intact based on abnormal containment radiation, pressure, and sump levels

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 17 of 24 Time Position Applicants Actions or Behavior CT1: Manually start at least one RHR Pump Initiating Cue: Both of the following:

o Indication that RHR pumped injection is required (SI actuated status light lit and RCS pressure indicating below shutoff head of the RHR pumps) o Indication that no RHR pump flow is injecting into the core (Pump breaker indicating lights and RHR flow indication)

Performance Feedback: Indication that at least one RHR pump is injecting (Breaker indicating lights and RHR flow indication).

Success Path: Both RHR pumps are available for manual start. Pumps may be started as a backup action for a failed automatic action or as directed in E-0 Attachment A.

Measurable Performance Standard: Manually start at least one RHR pump before transition out of E-0 and completion of E-0 Attachment A.

RO/BOP Perform actions of Attachment A as follows:

1. Check ECCS pumps all running-Determine CCPs and SI pumps are running, start RHR pumps if not previously started. (CT1 related action).

a. Determine East CCP emergency leak off valve 2-QMO-225 is open and cannot be closed (NOTE: This is due to the pressurizer pressure instrument failure in Event 6.)

2. Check ECCS flow-Determine flow is indicated for BIT flow, SI pump flow, and RHR HX flow.

3. Check ECCS valves in proper alignment-Determine ECCS alignment is correct using status lights on 2-SML-12A, 2-SML-12B, 2-SML-12C, 2-SML-11A, 2-SML-11B, and 2-SML-11C.

4. Check CCW status-Determine both CCW pumps running, CCW surge tank stable, and CCW monitor lights in proper status using 2-SML-8B.

5. Check ESW status-Determine both ESW pumps running, both discharge valves open, and proper status lights on 2-SML-7

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 18 of 24 Time Position Applicants Actions or Behavior RO/BOP Continue Attachment A actions:

6. Check if containment recirculation fans should be running-Determine containment pressure >1 psig, both CEQ fans running, both CEQ fan suction dampers open, all CEQ fan CCW valves open

7. Place DIS in service by directing local action to stop all ice condenser air handling units and turning on all hydrogen ignitors when local action is reported complete

8. Check containment vent and Phase A isolation-Determine Containment Vent Isolation and Phase A isolation are actuated and completed on both trains, and direct actions to periodically monitor SFP radiation, SFP cooling, and SFP level

9. Check ESF fans both running-Determine both fans are running

10. Align control room ventilation by checking both pressurization fans are running, stopping one pressurization fan, checking cable vault hatch closed, checking control room dampers aligned for SI, and checking at least one control room air handling unit is running

11. Align PACHMS for service by momentarily placing containment hydrogen sample bypass switches in BYPASS

12. Request Unit 1 perform actions

13. Check generator trip-Determine generator output breakers are both open and main generator excitation control is OPEN

14. Check Load Conservation status-Determine AC buses T21B and T21C are energized by offsite power

15. Check NESW pressure is >65 psig on 2-WPI-901

16. Check Containment Isolation Phase B status-Determine Containment Isolation Phase B is actuated and completed on both trains.

17. Report completion of Attachment A and report any unexpected conditions or actions taken US Announces transition to 2-OHP-4023-E-1, Loss of Reactor or Secondary Coolant and directs operator actions.

Checks Status Trees for Red Path NOTE:

Momentary entry into FR-P.1 will be required until crew verifies RHR flow (>400 gpm) sufficient to indicate a LB LOCA has occurred.

RO/BOP Reviews E-1 Foldout Page Criteria When RWST level lowers to < 30% then the crew must immediately transition to 2-OHP-4023-ES-1.3, Transfer To Cold Leg Recirculation.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 19 of 24 Time Position Applicants Actions or Behavior RO/BOP Completes steps of 2-OHP-4023-E-1, Loss of Reactor or Secondary Coolant, as directed until criteria satisfied to transition to ES-1.3:

1. Check if RCPs should be stopped-Determine criteria are satisfied to stop RCPs and verify RCPs are stopped.

2. Check if SG secondary pressure boundaries are intact-Determine no SG pressure is lowering in an uncontrolled manner nor completely depressurized.

3. Check intact SG levels-Maintain AFW flow >240 x103 PPH until NR level is >13%, then control intact SG levels 27-50%

4. Check secondary radiation-Reset containment isolation phase A, Direct Chemistry to sample SGs for activity, and determine secondary radiation is normal.

5. Check pressurizer PORVs and block valves-Determine all PORV block valves are energized, all PORVs are closed, and block valves are all energized.

6. Check if ECCS flow should be reduced-Determine RCS subcooling is not >40ºF and go to step 7

7. Check if containment spray should be stopped-Determine spray pumps need to run for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months based on RCS pressure <300 psig

8. Check if RHR pumps should be stopped-Determine RCS pressure is not >300 psig, leave RHR pumps running, and got to step 10

10. Check if DGs should be stopped-Determine AC buses energized from offsite power, reset SI, stop both EDGs, and direct local action to stop jacket water pumps and place in AUTO.

RO/BOP Report when RWST level is <30%

US Announces transition to 2-OHP-4023-ES-1.3, Transfer To Cold Leg Recirculation when RWST level < 30% per:

E-0, Foldout Page, Criteria 3 E-1, Foldout Page, Criteria 5 E-1, Step 13 RO/BOP Review 2-OHP-4023-ES-1.3 Fold Out Page US Direct actions of 2-OHP-4023-ES-1.3, Transfer To Cold Leg Recirculation US Monitors CSF Status Trees for information only

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 20 of 24 Time Position Applicants Actions or Behavior RO/BOP Reset SI if not previously performed RO/BOP Check CCW Return Flow for each in service RHR HX between 3000 and 3500 gpm-Throttle RHR HX outlet valves as necessary to establish required flow US Wait until RWST level is <20% before continuing RO/BOP Check containment water level greater than minimum recirc level-Determine status lights 2-NLI-330 and 2-NLI-331 are lit CT2: Transfer to cold leg recirculation Initiating Cue: All of the following:

o Indication/annunciation that SI is actuated (SI actuated status light lit) o Indication that RWST level is at or below 20% (Control Board level indication) o Indication that containment sump level is at or above the minimum level required for transfer to cold leg recirculation (Containment Water Level Minimum Recirculation Level status lights lit)

Performance Feedback: Flow indication of the recirculation of containment sump water through the RHR heat exchangers and into the RCS Success Path: Both trains of RHR and CTS pumps are available for transfer to recirculation as directed by ES-1.3. No additional malfunctions are included that would impact on the ability to accomplish the transfer within the stated time limits.

Measurable Performance Standard: Transfer at least one train of ECCS to cold leg recirculation prior to indications of cavitation/loss of flow from SI, CTS, or Charging Pumps AND without interruption of at least one train of RHR and CTS flow for more than 5 minutes AND while maintaining one available CCP and SI pump in service at all times.

Evaluator Note:

In the following step, record the time when the West CTS Pump is stopped and the time the West RHR pump is stopped. Record the time the East RHR pump is subsequently started and the time the East CTS pump is subsequently started. In order to satisfy the Critical Task, both of these times must be 5 minutes. In addition, at least one Charging Pump and at least one SI pump must remain in operation with no signs of pump cavitation during the time RHR and CTS pumps are off.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 21 of 24 Time Position Applicants Actions or Behavior RO/BOP Transfer RHR/CTS to Recirculation Mode per step 6 (CT2 related actions, steps 6a-6m):

a. Stop and lockout East CTS pump

b. Stop and lockout East RHR pump

c. Determine both pumps stopped

d. Initiate valve closure of 2-IMO-310, East RHR pump suction, and 2-IMO-215, East CTS pump suction from RWST

e. Stop and lockout West CTS pump TIME Stopped:_______

f.

Stop and lockout West RHR pump TIME Stopped:_______

g. Determine both pumps stopped

h. Initiate valve closure of 2-IMO-320, West RHR pump suction, and 2-IMO-225, West CTS pump suction from RWST

i.

Restore control power to ICM-305, recirc sump to East RHR/CTS pumps

j.

Check 2-ICM-305 open interlock met (2-IMO-215 and 2-IMO-310 both full closed

k. When 2-ICM-305 interlock is met, open 2-ICM-305

l.

Check 2-ICM-305 full open

m. Start East RHR Pump and East CTS pump Time RHR started:________ Time CTS Started:________

n. Restore control power to 2-ICM-306, recirc sump to West RHR/CTS pumps

o. Check 2-ICM-306 open interlock met (2-IMO-225 and 2-IMO-320 both full closed

p. Open 2-ICM-306

q. Check 2-ICM-306 full open

r. Start the West RHR and CTS pumps Time Completed:______

s. Reset CTS actuation

t.

Close spray additive tank valves 2-IMO-202 & 2-IMO-204 within 5 minutes of completion of Cold Leg Recirculation for RHR and CTS pumps Time Completed: ________

u. Check at least RHR pump running on recirculation sump-Determine both RHR pumps are operating properly on the recirculation sump The scenario will terminate when RHR and CTS pumps are transferred to recirculation lineup (ES-1.3 step 6 complete), or at Lead Evaluator discretion.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 22 of 24 Reset to a 100% IC, MOL, with East Stator Cooling Water Pump in service, Auxiliary Steam on Unit 1.

Verify deionizer flow =80 gpm.

Setup Items:

Set up failure of both RHR pumps to auto start:

Enter a failure of pressurizer pressure channel NPP-151 high and failure of pressurizer spray valve NRV-163 full open on ET3:

Event 1:

When the Crew has assumed responsibility for the Unit, and with Lead Evaluator concurrence, enter the low failure of QLC-451, VCT Level:

When contacted as MTI to energize the RWS relay, inform the Crew that two technicians will be briefed and sent to the Control Room within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

Event 2:

When the QLC-451 event is complete, and with Lead Evaluator concurrence, enter the high failure of 2-FFC-210, #21 Feed Water Flow:

When contacted as MTI to trip bistables, inform the Crew that two technicians will be briefed and sent to the Control Room within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

Event 3:

When the FFC-210 event is complete, and with Lead Evaluator concurrence, enter the RCS Flow Instrument failure:

When contacted as MTI to trip bistables, inform the Crew that two technicians will be briefed and sent to the Control Room within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

U2_NFP210 0 U2_RC15A 100 ET3 an06_u2(043) ALARM OFF trg= 1 "dor an06_u2(043)"

ET2 when WRHR pump in CLOSE trg= 2 "dmf u2_101ta4" U2_101TA4 U2_101TD6 trg= 2 "dor an06_u2(048)"

U2_QLC451 0 U2_NPP151 2500 ET3 AN06_U2(048) ALARM OFF U2_FFC210 4000000 ET1 when ERHR pump in CLOSE trg= 1 "dmf u2_101td6"

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 23 of 24 Event 4:

When the NFP-210 event is complete, and with Lead Evaluator concurrence, call as the Work Control SRO and inform the Crew that the clearance for the East Stator Cooling Water Pump is ready and request the Crew swap Stator Cooling Water pumps. Report that the Turbine AEO has been briefed.

Event 5:

5 minutes after the East Stator Cooling Water pump has been stopped, enter a leak on the Stator Cooling Water system:

When directed to locally investigate the Stator Cooling Water system, wait 3 minutes and report the following:

There is a leak on the Stator Cooling Water system supply line from a flange just upstream of the flow orifice for 2-CFS-610. The leak is approximately 5 GPM. The leakage is not affecting any other plant equipment.

If directed to check level in the Stator Cooling Water Tank, report that level is at the height of the lower viewing window.

When the Shift Manager is notified of the leak, direct the US to perform a unit shut down using the Rapid Power Reduction Response AOP at a rate of 2%/minute.

If directed to open 2-H-159, GRV-256 inlet shutoff valve, wait 1 minute and report completion.

If subsequently directed to throttle open 2-SCS-171, perform the following to open the valve to 15%

open, then adjust the remote from the Instructor Station as necessary based on direction from the Crew:

Event 6:

When directed by the Lead Evaluator, actuate ET3 to cause a failure of pressurizer pressure channel NPP-151 high and pressurizer spray valve 2-NRV-163 full open:

TRG! 3 U2_TP03 1 U2_TPR20 15

Op. Test No.: Cook 2022 Scenario No.: NRC2022-1 Form 3.3-2 Page 24 of 24 Event 7:

When the Crew has transitioned to ES-0.1 (SI not actuated) or completed E-0 step 4 (SI actuated),

insert the following to cause a LBLOCA:

Perform the following actions as directed during performance of E-0:

Stop ice condenser air handling units and report completion in ~5 minutes:

When directed to perform Unit 1 actions per E-0 Att. A:

1. Report chemistry has been directed to place Train A PACHMS in service, Unit 1 control room pressurization is aligned for a Unit 2 SI, 2-HV-AS-1 is in service

2. Place PACHMS Train A in service (30 minute delay):

U2_CHR02 ON After 30 Min Delay U2_CHR01 OFF After 5 Min Delay U2_RC01A 100

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-1 Page 1 of 1 Form 3.3-1 Scenario Outline Facility: DC COOK 1 & 2 Scenario #: NRC2022-2 Scenario Source: New Op. Test #: Cook 2022 Examiners:

Applicants/

Operators:

Initial Conditions: 100% Power, breaker T21C3 is OOS due to control power failure, T.S.

3.8.1.B in effect.

Turnover: As part of Post Maintenance testing for breaker T21C3, DG2CD output breaker to Bus T21C, start DG2CD per marked up copy of 2-OHP-4021-032-001CD, run loaded on Bus T21C at 900-1100 KW, then shut down the DG per the NOP.

Critical Tasks**: 1. Manually trip the reactor

2. Energize at least one AC emergency Bus Event No.

Malf. No.

Event Type*

Event Description**

1 N-BOP Perform DG2CD start per NOP 2

U2_EG14O ZGI101WMO726_

U2 ZGI101WMO728_

U2 C-BOP TS Failure of DG2CD ESW Supply 3

U2_RD07H C-US R-RO MC-RO Uncontrolled automatic Control Rod Insertion Restore control rod position 4

U2_NLP151 I-RO MC-RO TS Controlling Pressurizer Level Channel fails High 5

U2_SW09 C-BOP TS Loss of Containment Cooling 6

RP01A RP01B U2_RCP1 C-RO 21 RCP Trip with Automatic Reactor Trip Failure (EOP entry) 7 U2_ED05E U12_ED25B U12_ED25C M-CREW Loss of Bus T21A/Loss of Offsite Reserve Power

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor, (TS)Tech Spec, (MC)Manual Control

- Details on subsequent pages

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 1 of 20 Form 3.3-2 Required Operator Actions Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Event No.: 1 Event

Description:

As part of post maintenance testing for the DG2CD output breaker to bus T21C, the Crew will start the EDG and load the EDG on to bus T21C.

Event Termination: When DG2CD is started and loaded to 900-1100 KW, the event is complete.

Symptoms/Cues:

When the EDG is started, the following annunciators are expected:

212-14, OSCILLOGRAPH OPERATED 220-2, DG2CD COMPR AIR RECEIVER PRESSURE LOW 220-13, DG2CD FUEL OIL MANIFOLD PRESSURE LOW (in and clear) 220-23, DG2CD LUBE OIL PRESSURE LOW (in and clear)

When breaker T21C3 is closed, the following annunciator is expected:

220-76, 4KV BUS T21C PARALLEL OPERATION

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 2 of 20 Time Position Applicants Actions or Behavior BOP Perform actions of 2-OHP-4021-032-001CD section 4.3 to start DG2CD:

Start DG2CD by placing the DG2CD STOP-RUN control switch in RUN Determine DG2CD has started and reached 514 RPM on local tachometer and that generator output voltage on the control board meter is 119-124 volts Determine annunciators 220-13 and 220-23 are not lit Determine red light lit at DG2CD STOP-RUN control switch indicating DG2CD has reached 95% rated speed Direct local action to align a single Jacket Water pump for standby service Direct local verification of proper governor oil level and DG2CD room ventilation fans running Initiate data collection on appropriate data sheets

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 3 of 20 Time Position Applicants Actions or Behavior BOP Perform actions of Attachment 2 to parallel and load DG2CD on bus T21C:

Verify DG2CD START GEN & 69/4KV voltmeter selector switch is in a DG OUTPUT position Verify POTENTIAL DG2CD RUN & BUS T21C & T21D SELECTOR in a Bus T21C position Adjust DG2CD start voltage 2 to 3 volts higher than T21C run voltage Place DG2CD Start Voltmeter and DG2CD Run Voltmeter in OFF Place 2-T21C3 Synch Selector in MANUAL Adjust DG2CD speed using DG2CD GOVERNOR CONTROL so DG2CD synchro scope is rotating slowly in the fast direction When DG2CD synchro scope is between 5 minutes till 12 oclock and 12 oclock, then place DG2CD 4KV CB T21C3 control switch in CLOSE Check white light, Synch Permissives Met, illuminated for T21C3 When DG2CD synchro scope is between 5 minutes till 12 oclock and 12 oclock, then place DG2CD Synchronize Master Close switch to CLOSE When T21C3 closes, then without delay raise load with DG2CD GOVERNOR CONTROL to 900-1100 kw load Place T21C3 Synch Selector to OFF Minimize circulating current by slowly adjusting Auto Volt Adjust Place voltmeters in the desired position Maintain 900-1100 kw for ~10 minutes

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 4 of 20 Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Event No.: 2 Event

Description:

The event starts with failure of a DG run relay for DG2CD concurrent with the valve control circuit for 2-WMO-726, Normal Supply to DG2CD. This results in a loss of Essential Service Water cooling to DG2CD. High and High-High temperature alarms will be received. The Crew should respond per annunciator response procedures to trip DG2CD. The US should identify entry into the following Technical Specification condition/action: 3.7.8. Condition A, Required Action A.1. NOTE: T.S. 3.8.1 Condition B is already in effect as a scenario initial condition, so entry is not required based on Note 1 for 3.7.8.

Event Termination: When the EDG has been tripped and Tech Spec actions identified, the event is complete.

Symptoms/Cues:

Annunciator 212-14, OSCILLOGRAPH OPERATED, clears 2-WMO-726, Normal Supply to DG2CD, closes DG2CD Return Flow, 2-WFI-726, lowers to zero Annunciators:

220-32, DG2CD JACKET WATER TEMP HIGH (After time delay of ~45 seconds) 220-31, DG2CD JACKET WATER TEMP HI-HI (After time delay of ~90 seconds) 220-22, DG2CD LUBE OIL TEMP HIGH (After time delay of ~4 minutes if EDG is still running) 220-21, DG2CD LUBE OIL TEMP HI-HI (After time delay of ~6 minutes if EDG is still running)

DG2CD will trip after ~7 minutes if not manually tripped by the Crew Time Position Applicants Actions or Behavior BOP Diagnose loss of ESW cooling to DG2CD NOTE: If the BOP attempts to manually open 2-WMO-726 or 2-WMO-728 to restore ESW cooling, these actions will not be successful.

BOP Respond per ARP for 220-31:

Direct local check of jacket water temperature on CTI-305 Determine the EDG is not required for emergency situation and trip the EDG US Identify entry into T. S. 3.7.8 Condition A Required Action A.1, One ESW train inoperable, due to failure of required automatic valves to actuate properly (2-WMO-726).

NOTE: T.S. 3.8.1 Condition B is already in effect as a scenario initial condition, so entry is not required based on Note 1 for 3.7.8.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 5 of 20 Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Event No.: 3 Event

Description:

The event starts with an uncontrolled automatic control rod insertion on control bank D. The Crew should diagnose uncontrolled rod motion, perform immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response, place control rods in manual to stop rod movement, and then transition to 2-OHP-4022-012-003, Continuous Control Bank Movement. The RO should develop and implement a reactivity plan to withdraw control rods to match Tavg with Tref.

Event Termination: When actions of 2-OHP-4022-012-003 are complete, including restoration of control rods to match Tavg and Tref, the event is complete.

Symptoms/Cues:

Control Bank D control rods will insert at 72 steps per minute Reactor power lowers Tavg lowers NOTE: When control rods are placed in Manual, rod motion will stop and the switch will fail in the Manual position.

Time Position Applicants Actions or Behavior RO Recognizes and reports inward rod motion with no turbine runback in progress US Direct RO and BOP to perform immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response RO Reports uncontrolled rod motion and performs the immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response, from memory:

Determines load rejection or runback is not in progress Place rod control in MANUAL Verify rod motion is stopped Crew Performs plant stability checks. (Order not important)

RO

1. Rx Power

2. RCS Temp

3. RCS Pressure

4. Pressurizer level

5. AFD BOP

1. Turbine Load

2. SG Level

3. MFP DP

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 6 of 20 Time Position Applicants Actions or Behavior US Enters and directs actions of 2-OHP-4022-IFR-001, Instrument Failure Response procedure:

1. Verifies RO immediate actions taken from memory

2. Assigns manual control band for Tavg (nominal +/-2 ºF from Tref)

3. Verifies no unexpected control rod motion occurred

4. Transitions to 2-OHP-4022-012-003, Continuous Control Bank Movement US Enters and directs actions of 2-OHP-4022-012-003, Continuous Control Bank Movement NOTE: It is expected that action to place control rods in MANUAL will have been early enough to preclude either rod insertion below the low insertion limit or AFD out of band. If this did not occur, the Crew will perform actions per the RNO steps for step 1 of 2-OHP-4022-012-003.

RO/BOP RO RO RO BOP RO RO RO RO US/BOP Perform actions of 2-OHP-4022-012-003 as directed:

Determine rod position is above the low insertion limit and AFD is within the target band Determine Power Range Nuclear Instrumentation channels are operable Develop and implement a reactivity plan to minimize Tavg-Tref deviation by adjusting main turbine load, adjusting RCS boron concentration, or adjusting control rod position (expected)

Provide peer check for reactivity manipulation Determine no instrumentation malfunction occurred on Turbine First Stage Pressure, Tavg, or Power Range NI channels Determine inadvertent boration or dilution is not occurring Determine cause of rod motion has not been identified and perform the following:

o Verify Tavg and Tref matched o Verify Rod Control in MANUAL o Inform SM/duty staff supervisor of the situation NOTE: If the Crew completes actions of 2-OHP-4022-012-003 and has determined to not withdraw control rods to pre-malfunction height, with the concurrence of the Lead Evaluator, direct the US as Shift Manager to restore control rod position. This will enable evaluation of the reactivity manipulation by the RO.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 7 of 20 Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Event No.: 4 Event

Description:

Pressurizer Level Channel NLP-151 fails high. This results in automatic closure of 2-QRV-251, Charging Flow Control Valve. The RO should take manual control of charging flow per immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response, and stabilize pressurizer level. The Crew will complete IFR-001 actions and transition to 2-OHP-4022-013-010, Pressurizer Level Instrument Malfunction, complete AOP actions to restore pressurizer level to automatic, and identify required Technical Specification actions to trip bistables. The US should identify entry into the following Technical Specification conditions/actions: 3.3.1 Condition A Required Action A.1, 3.3.1 Condition D Required Action D.1 (Due to Table 3.3.1-1, Function 9), 3.3.4 Condition A Required Action A.1 (NLP-151 is the only channel that provides Remote Shutdown Monitoring).

Event Termination: When the Crew has completed actions of 2-OHP-4022-013-010 up to bistable tripping, pressurizer level control is in automatic, and Technical Specifications have been identified, the event is complete.

Symptoms/Cues:

Pressurizer level channel 2-NLP-151 fails to 100%

Charging flow and seal injection flow lowers as 2-QRV-251 throttles closed Pressurizer backup heaters energize Annunciators:

208-1, PRESSURIZER LEVEL HIGH HIGH 208-3, PRESSURIZER LEVEL HIGH DEV BACKUP HTRS ON 207-9, 29, 69, 89, RCP (1,2,3,4) THERM BARRIER DP LOW (Possible based on initial seal injection flow and timing of crew actions) 207-18, 38, 78, 98, RCP (12,3,4) SEAL WTR INJ FLOW LOW (Possible based on initial seal injection flow and timing of crew actions)

Time Position Applicants Actions or Behavior RO Recognizes and reports pressurizer level instrument failure based on control board indications and annunciators US Direct RO and BOP to perform immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response RO Reports instrument malfunction and performs the immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response, from memory:

Determines a pressurizer level instrument or control system issue exists Determines pressurizer level is not stable at or trending to program Places pressurizer level control in manual by taking manual control of 2-RU-23, PZR LEVEL CONTROL, or taking manual control of 2-QRV-251 using 2-RU-29, CCP DISCH FLOW CTRL and restore pressurizer level to program level

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 8 of 20 Time Position Applicants Actions or Behavior Crew Performs plant stability checks. (Order not important)

RO

1. Rx Power

2. RCS Temp

3. RCS Pressure

4. Pressurizer level

5. AFD BOP

1. Turbine Load

2. SG Level

3. MFP DP US Enters and directs actions of 2-OHP-4022-IFR-001, Instrument Failure Response procedure:

1. Verifies RO immediate actions taken from memory

2. Assigns manual control band for pressurizer level (nominal program level +/-5%)

3. Verifies no unexpected control rod motion occurred

4. Transitions to 2-OHP-4022-013-010, Pressurizer Level Instrument Malfunction US Enters and directs actions of 2-OHP-4022-013-010, Pressurizer Level Instrument Malfunction RO Performs the following actions as directed:

1. Determines 2-NLP-151 is failed

2. Determine 2-NLP-151 is the controlling channel and verify level control is in manual

3. Place Pressurizer Level Control Selector Switch 2-LS-459-D in CHANNELS 2&3 position

4. Place Pressurizer Level Recorder selector switch in CHAN 2 or CHAN 3 position

5. Determine 2-NPP-151 and 2-NLI-151 are not failed

6. Verify pressurizer level is >17%, letdown is in service, and pressurizer heaters are not tripped

7. If 2-QRV-251 is not in Auto (expected), verify pressurizer level master control 2-RU-23, PZR LEVEL CONTROL is in Manual, adjust 2-RU-23 to null 2-QRV-251 controller, and place 2-QRV-251 controller 2-RU-29 in Auto

8. Place 2-RU-23, PZR LEVEL CONTROL in Auto by verifying 2-QRV-251 in Auto, verify pressurizer level stable on program, and place 2-RU-23 in Auto

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 9 of 20 Time Position Applicants Actions or Behavior US Identify applicable Technical Specification /Technical Requirements Manual conditions 3.3.1, Condition A Required Action A.1 3.3.1 Condition D Required Action D.1 (Due to Table 3.3.1-1, Function 9)

T.S. 3.3.4 Condition A Required Action A.1 (NLP-151 is the only channel that provides Remote Shutdown Monitoring)

US Initiates corrective action for failed channel

a. Notifies management and WCSRO

b. Directs RO/BOP to generate work request US Notifies SM/MTI to Initiate actions to trip Bi-stables associated with 2-NLP-151 Pressurizer Level failure per Attachment A-1 of 2-OHP-4022-013-010.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 10 of 20 Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Event No.: 5 Event

Description:

The Unit 2 Containment Cooling system will fail due electrical fault on the supply bus.

Containment pressure will increase. The Crew will enter 2-OHP-4022-028-001, Loss of Containment Chilled Water, initiate a containment pressure relief, and restore containment cooling by local alignment for open loop cooling using Non-Essential Service Water. The US should identify entry into the following Technical Specification condition/action: 3.6.4. Condition A Required Action A.1.

Event Termination: When the Crew has shifted to open loop containment cooling and secured the containment pressure relief, the event is complete.

Symptoms/Cues:

2-WFI-901, NESW FROM CNTMT VT, lowers to zero On PPC screen from Containment Cooling:

Main Breaker 2-12CCB2-5C opens Tie breaker 2-12CCB2-5B opens Alarms:

o Tie Breaker overcurrent o Main breaker overcurrent o Bus 1 under voltage o 48V DC Bus trouble Containment pressure rises Containment temperature rises Annunciators:

204-5, CNTMT CHILLERS SYS TROUBLE 204-15, CNTMT CHILLERS SYS FAIL 204-41, CNTMT AIR TEMP REC HIGH OR ABNORMAL (After ~2 minutes) 205-31, UPPER CNTMT ORIENT 0 DEG PRESS HI OR LO (After ~1.5 minutes) 205-32, UPPER CNTMT ORIENT 180 DEG PRESS HI OR LO (After ~1.5 minutes)

NOTE: This malfunction will also cause a loss of containment chilled water on Unit 1, but these indications will not be available on Unit 2.

Time Position Applicants Actions or Behavior BOP Report annunciators on Panels 204 and 205 and indications of chiller failure BOP Respond to alarms 204-5 and 204-15:

Dispatch an operator to the Unit 2 Containment Chilled Water System skid to respond per 2-OHP-4024-CHW-WS (Local Annunciator Response Procedure)

US Determine that containment pressure is > than tech spec maximum with instrument inaccuracies (0.2 psig) and direct a containment pressure relief

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 11 of 20 Time Position Applicants Actions or Behavior US Direct performance of 2-OHP-4022-028-001, Loss of Containment Chilled Water BOP Perform the following actions of 2-OHP-4022-028-001 as directed:

Determine the containment chilled water system has failed based on eDNA displays of Electrical and Flow diagrams Determine containment air temperatures and pressures are rising NOTE: Calculation of average containment temperature requires access to an Excel spreadsheet which is maintained in a public directory which should not be accessed to maintain exam security. If desired by the Lead Evaluator, the US may be given the following values to determine if required conditions of T.S. 3.6.5 are satisfied. (These values were previously calculated for this event. These values would not require entry into T.S. 3.6.5 conditions):

Upper Containment Average: 94 ºF Lower Containment Average: 106 ºF US Identify entry into T.S. 3.6.4. Condition A Required Action A.1 NOTE: The Tech Spec limit with instrument uncertainties is 0.2 psig (Ref.

2-OHL-4030-SOM-042)

US Direct performance of 2-OHP-4021-028-004, Operation of the Containment Pressure Relief System BOP Initiates Containment Pressure Relief per 2-OHP-4021-028-004, Operation of the Containment Pressure Relief System:

Determine Radiation Monitoring System channels are all operable Complete required sections of Data Sheet 1 Verify the daily source checks have been performed or perform source checks Verify proper TRIP/BLOCK switch alignment Review contingencies as listed in the procedure Open Containment Isolation valves 2-VCR-107 and 2-VCR-207 Start 2-HV-CPR-1, Containment Pressure Relief Fan or open 2-HV-CDP-2, 2-HV-CPR-1 bypass volume damper

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 12 of 20 Time Position Applicants Actions or Behavior BOP Continue actions of 2-OHP-4022-028-001 as directed:

Determine power is not available to the Unit 2 Chilled Water System Go to Attachment E, Restore Electric Power Determine Unit 2 Bus is faulted Verify breaker 2-12CCB2-5C is open Verify both cross-tie breakers are open Direct AEO performance of Attachment C, Swapping Containment Chill Water to Open Loop BOP Secure containment pressure relief when containment pressure is restored:

Stop 2-HC-CPR-1 if running Close 2-HV-CDP-2 if open Close 2-VCR-107 and 2-VCR-207 Complete entries in Data sheet 1 Return the operable TRIP/BLOCK switches to BLOCK

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 13 of 20 Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Event No.: 6 Event

Description:

A locked rotor will occur on 21 RCP. Automatic reactor trip will fail. The Crew should recognize the failure of automatic trip and perform a manual reactor trip, perform immediate actions of 2-OHP-4023-E-0, Reactor Trip or Safety Injection, and transition to 2-OHP-4023-ES-0.1, Reactor Trip Response.

Event Termination: When the Crew has completed immediate actions of E-0 and transitioned to ES-0.1, the event is complete.

Symptoms/Cues:

21 RCP pump amps peg high 21 RCS Loop Flow lowers to zero 21 SG level and Steam Flow lower to zero 22, 23, & 24 SG steam flows increase Automatic turbine runback occurs due to OTT Multiple annunciators associated with RCS flow, RCS temperatures, and SG parameters 21 RCP breaker will trip in ~1 minute if not tripped by the RO Time Position Applicants Actions or Behavior CT1: Manually Trip the Reactor Initiating Cue: Indications and/or annunciators indicating an automatic reactor trip is required due to loss of reactor coolant loop 1 flow (Reactor Coolant Status Lights on 2-SML-13, Annunciator 207 Drop 1, 21 SG Level Lo-Lo status lights on 2-SML-19B, Annunciator 213 Drop 5), but the reactor does not automatically trip Performance Feedback: Reactor trip breaker indicates open, control rod position indicates rods inserted, neutron flux lowers Success Path: Either control room reactor trip switch will cause the associated breaker to open and insertion of all control rods Measurable Performance Standard: Manually open at least one reactor trip breaker using control board switches within one minute of the trip condition.

RO Report loss of 21 RCP with reactor trip failure and perform a manual reactor trip by opening at least on Reactor Trip breaker (CT1 related action)

US Direct RO to perform a manual reactor trip

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 14 of 20 Time Position Applicants Actions or Behavior RO/BOP Performs the immediate actions of E-0 from memory:

1. Checks reactor trip - Determines reactor Trip and Bypass breakers Open, all rods < 10 steps, neutron flux lowering

2. Checks turbine trip - Determines Turbine Stop Valve Closed Status Lights Lit

3. Checks power to AC emergency buses - Determines all emergency buses T21A, T21B, T21C, and T21D energized and both annunciators clear for Open Phase

4. Checks safety injection status - Determine SI Status Lights - SI Status Lights NOT Lit (QMO-225/226 white lights NOT Lit) and SI not required based on:

PZR Pressure > 1775#

CNTMNT Pressure < 1.0#

SG Pressure > 500#

STM Line DP < 100psid RO After completion of immediate actions from memory, trip 21 RCP breaker US Verify performance of immediate actions using procedure 2-OHP-4023-E-0 US Transition to 2-OHP-4023-ES-0.1, Reactor Trip Response

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 15 of 20 Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Event No.: 7 Event

Description:

After transition to ES-0.1, a fault will cause a loss of T21A, followed shortly by a loss of both Reserve Power transformers. DG2AB will start, load on to the faulted bus T21A, and trip. DG2CD is previously tripped. The Crew should enter ECA-0.0. Power restoration will be performed using the Emergency Power (EP) source. After power restoration, the Crew will complete ECA-0.0 actions and transition to ECA-0.1 or ECA-0.2, depending on pressurizer level.

Event Termination: The scenario terminates after the Crew has transitioned out of ECA-0.0.

Symptoms/Cues:

4.16 KV Bus T21A de-energizes 600V Bus 21A de-energizes Multiple annunciators associated with loss of power, including:

219-75, 4KV BUS T21A CB T21A9 TRIP DG2AB starts, output breaker closes to 4.16 KV Bus T21A, and then DG2AB trips and locks out Reserve Power transformers #5 and #9 de-energize Switchyard circuit breakers BE and BG open All 4.16 KV and 600V buses de-energize All 4.16 KV loads are lost, including but not limited to the following:

Both Motor Driven AFW pumps Charging Pumps Running Reactor Coolant Pumps CCW Pumps ESW pumps NOTE: If the Crew tripped the DG2CD in Event 2 using the STOP-RUN switch, the EDG will start and re-energize buses T21C and T21D. If this occurs, the Crew should follow the ARP for Hi-Hi Jacket Water temperature and attempt to establish ESW cooling by manually opening ESW supply valve. When this is unsuccessful, the Crew should trip the EDG and enter ECA-0.0 as described below.

Time Position Applicants Actions or Behavior CREW Diagnose a Loss of All AC Power US Direct RO and BOP to perform immediate actions of 2-OHP-4023-ECA-0.0, Loss of All AC Power RO/BOP Perform immediate actions of ECA-0.0 from memory

1. Checks reactor trip - Determines reactor Trip and Bypass breakers Open, neutron flux lowering

2. Checks turbine trip - Determines Turbine Stop Valve Closed Status Lights Lit US Direct actions of 2-OHP-4023-ECA-0.0, Loss of All AC Power

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 16 of 20 Time Position Applicants Actions or Behavior CREW Verify correct performance of immediate actions using the procedure RO Check if RCS is isolated:

Close letdown isolation valves 2-QRV-111 and 2-QRV-112 Determine pressurizer PORVs and excess letdown isolation valves closed BOP Determine TDAFP is running and AFW flow is >240x103 pph Control SG level based on previously established control bands RO/BOP Perform the following actions from 2-OHP-4023-ECA-0.0 as directed:

Determine no EDG is available Determine EP supply to AC emergency buses is energized from offsite EP and implement Attachment D Direct local action to close RCP seal injection filter isolation valves 2-CS-311N, 2-CS-311S, and 2-CS-307 Determine there is no running emergency DG Direct local action to close 2-QCM-350, RCP Seal Water Return Place equipment switches in PULL TO LOCKOUT: MDAFPs, CCPs, RHR pumps, SI pumps, CTS pumps, CCW pumps, ESW pumps, NESW pumps Open 4KV supply breakers to pressurizer heaters, T21A6 &

T21D9 Determine EP 4KV Bus 1 is properly energized from offsite EP power Select Train A bus for restoration based on lockout of Train B buses CT2: Energize at least one AC emergency bus Initiating Cue: Both of the following:

o Indication/annunciation that all AC emergency buses are de-energized (Bus Energized indicating lights, Bus Voltage meter indications) o Indication/annunciation/or other information that an AC source is available or can be made available (EP Red Status light lit, EP voltage meter indication, Standby Reserve Power Transformer #4 red indicating light)

Performance Feedback: Indication that at least one AC emergency bus (T21D) is energized.

Success Path: Emergency Power 69 KV (EP) transformer is unaffected by the loss of 345KV power that de-energizers Reserve Power transformers #5 and #9. EP is the first procedurally preferred offsite power source. Transformer #4 could also be made available, with action by the Switchyard Operator, to re-energize from Reserve Power.

Measurable Performance Standard: Energize at least one ac emergency bus (T21D) prior to direction to perform the Deep Load Shed by implementing 2-OHP-4027-FSG-4, ELAP Power Management.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 17 of 20 Time Position Applicants Actions or Behavior BOP Energize Train A buses from EP as directed (CT2 related actions):

Determine bus T21D is available based on trip annunciators clear Place breaker T21D8, DG2CD Supply to Bus T21D in PULL TO LOCKOUT Place Train A Load Conservation switch to LOAD CON Close breaker T21D1, 4KV EP Supply to Bus T21D and check the bus energized on all phases RO/BOP Perform the following actions from 2-OHP-4023-ECA-0.0 as directed:

Close 2-QCM-250, RCP Seal Water Return Isolation Valve Close 2-CCM-453, CCW from RCP thermal barrier valve Determine bus T21C is not energized but is available based on trip annunciators clear Place breaker T21C3, DG2CD Supply to Bus T21C in PULL TO LOCKOUT Close breaker T21C2, 4KV EP Supply to Bus T21C Check if RCS cold leg temperatures are stable at or trending to 547 ºF and take actions to minimize cool down as necessary:

o Verify 2-DRV-407 is closed o Control AFW flow o If cool down continues, trip closed all SG Stop valves Start the East ESW pump and verify discharge valve 2-WMO-703 is open.

RO/BOP Perform the following actions from 2-OHP-4023-ECA-0.0 as directed:

Return Train A Load Conservation switch to NORMAL Reset and start the North control room air handling unit 2-HV-ACRA-1 Verify non running equipment switches in PULL TO LOCKOUT:

MDAFPs, CCPs, RHR pumps, SI pumps, CTS pumps, CCW pumps, ESW pumps, NESW pumps Verify 4KV supply breakers to pressurizer heaters open with green target CREW Select recovery procedure:

If RCS subcooling based on core exit thermocouples is >40 ºF and pressurizer level is >20%, transition to 2-OHP-4023-ECA-0.1, Loss of All AC Power Recovery Without SI Required If RCS subcooling based on core exit thermocouples is 40 ºF or pressurizer level is 20%, transition to 2-OHP-4023-ECA-0.2, Loss of All AC Power Recovery With SI Required When the Crew has restored AC power and transitioned out of ECA-0.0, the event is complete.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 18 of 20 Time Position Applicants Actions or Behavior Simulator Instructions:

SETUP:

Reset to a MOL IC at 100% power Verify DG2CD start lineup complete per 2-OHP-4021-032-001CD is complete per steps 4.1 and 4.2.

Provide a marked of copy of 2-OHP-4021-032-001CD showing completion of sections 4.1 and 4.2, as well as marked up procedure steps to shut down the EDG after 10 minute run at 900-1100 KW.

Verify Containment Cooling supply for both units is on the Unit 2 source Set up a failure of the Normal and Alternate ESW supply valves to DG2CD on ET1:

Set up continuous inward rod motion at control rod speed of 72 steps per minutes on ET2:

Set up manual rod control to stop rod motion and failure of the bank selector switch in Manual on ET3:

Set up a loss of Bus T21A and a loss of Transformers 5 and 9 on ET4:

Set up failure of automatic reactor trip:

Event 2:

When DG2CD is loaded to 900-1100 KW, activate ET1 to cause loss of ESW to DG2CD:

If asked to report local jacket water temperature on CTI-305, report the value of simulator variable U2_EGTDGcdJW.

If asked to report local lube oil temperature on LTI-225, report the value of simulator variable U2_EGTDGCDLO.

If AT ANY TIME DURING THE SCENARIO, the AEO is directed to locally open either 2-WMO-726 or 2-WMO-728, wait 4 minutes and report the valve actuator will not move the valve shaft.

If directed as AEO, perform the following to stop jacket water pumps and return to automatic:

U2_RP01B U2_EGR04A STOP ZGI101WMO728_U2 CLOSE ET1 U12_ED25C ET4 5 sec delay U2_EGR04A AUTO U12_ED25B ET4 5 sec delay U2_ED05E ET4 U2_EGR04B STOP TRG= 3 "dmf u2_rd07h" U2_EGR04B AUTO ZGI101WMO726_U2 CLOSE ET1 U2_RP01A ET3 when rods not in auto trg= 2 "set u2_rdkrate2 72" U2_EG14O ET1 U2_RD07H ET2 TRG= 3 "set u2_rdkrate2 48" ZGI43CRDS12_U2 Manual ET3 TRG! 1

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 19 of 20 Event 3:

When the Crew has tripped DG2CD and identified Technical Specification actions, and with the concurrence of the Lead Evaluator, activate ET2 to cause continuous inward rod motion:

If the Crew completes actions of 2-OHP-4022-012-003 and has determined to not withdraw control rods to pre-malfunction height, with the concurrence of the Lead Evaluator, direct the US as Shift Manager to restore control rod position. This will enable evaluation of the reactivity manipulation by the RO.

Event 4: When the Crew has restored control rod position and completed actions of 2-OHP-4022-012-003, and with the concurrence of the Lead Evaluator, enter a failure of the controlling pressurizer level channel high:

When contacted as MTI to trip bistables, inform the Crew that two technicians will be briefed and sent to the Control Room within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

Event 5:

When the Crew has completed actions of 2-OHP-4022-013-010 up to bistable tripping, pressurizer level control is in automatic, and Technical Specifications have been identified, and with the concurrence of the Lead Evaluator, enter a loss of the Unit 2 Containment Cooling bus:

Role play as AEO: Three minutes after being dispatched to the Unit 2 Containment Chilled Water skid, call the Control Room and report the following:

Unit 2 containment chillers are not running The following alarms are actuated:

Drop 6, CHILLER FAILURE Drop 13, 480V COOLING CONTAINMENT BUS 2 UV Drop 14, 48 VDC TROUBLE ALARM ARP, 4024-CHW-WS for Drop 13 directs performance of 2-OHP-4022-028-001, Loss of Containment Chilled Water If directed to report status of the Chilled Water system based on local HMI, use the PPC display for Containment Chilled Water to report status as requested.

If asked as Unit 1, report that the Unit 1 cross-tie breaker is open.

When directed to swap to open loop cooling per Attachment C, perform the following:

When the file is complete (after ~8 minutes), report completion.

U2_NLP151 100 U2_SW09 TRG! 2 APP! U2_CHW_NESW_OPEN_LOOP.app

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-2 Page 20 of 20 Event 6:

When the Crew has shifted to open loop containment cooling and secured the containment pressure relief, and with the concurrence of the Lead Evaluator, enter a locked rotor of 21 RCP:

Event 7:

When the Crew has tripped the reactor, completed immediate actions of E-0, and transitioned to ES-0.1, and with the concurrence of the Lead Evaluator, activate ET4 to cause a loss of bus T21A and both Reserve Power transformers:

If DG2CD starts and re-energizes the buses, wait 15 minutes, or as directed by the Lead Evaluator, and trip DG2CD due to simulated bearing failure:

When directed to locally isolate RCP seal injection, wait 6 minutes and perform the following:

When directed to locally close 2-QCM-350, wait 5 minutes and perform the following:

If asked as Unit 1, report annunciator 121-65 is clear.

ZGI5DGCDET_U2 TRIP TRG! 4 U2_CVR20 0 set U2_CVVQCM350 0 U2_CVR21 0 U2_RCP1 Shaft Seizure

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-1 Page 1 of 1 Form 3.3-1 Scenario Outline Facility: DC COOK 1 & 2 Scenario #: NRC2022-3 Scenario Source: New Op. Test #: Cook 2022 Examiners:

Applicants/

Operators:

Initial Conditions: 100% Power Turnover: After crew turnover, swap NESW pumps and place the currently running pump in standby mode. After NESW pumps are swapped, reduce load to 95% in preparation for turbine valve testing.

Critical Tasks**: 1. Isolate ruptured SG

2. Control initial RCS cool down

3. Depressurize RCS to E-3 SI Termination criteria

4. Terminate ECCS flow Event No.

Malf. No.

Event Type*

Event Description**

1 N-BOP Start South NESW Pump and Stop the North NESW pump.

2 R-RO Commence power reduction to 95%

3 U1_NPP151 I-RO MC-RO TS Pressurizer Pressure Channel Fails Low 4

U2_101GLC2 C-BOP M-BOP Bus Duct Cooling Fan Failure with failure of the standby fan to auto start 5

U2_SW07A C-BOP MC-BOP Main Turbine Oil Temperature Controller Failure 6

U2_RC23B

@1%

C-RO TS MC-RO SG Tube Leak 7

U2_RC23B ZGI43SDI_U2 U2_RC15A M-CREW C-CREW C-CREW Steam Generator Tube Rupture (EOP entry)

Steam Dump System failure Pressurizer spray valve NRV-163 fails open during RCS depressurization

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor, (TS)Tech Spec, (MC)Manual Control

- Details on subsequent pages

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 1 of 20 Form 3.3-2 Required Operator Actions Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Event No.: 1 Event

Description:

The crew is directed to start the South NESW Pump and shutdown the North NESW pump per 12-OHP-4021-020-002. An AEO has been briefed and is ready for the pump start.

Event Termination: When NESW pumps have been swapped to the South pump in service and the North pump off, the event is complete.

Symptoms/Cues:

N/A Time Position Applicants Actions or Behavior BOP Direct AEO to verify South NESW pump is ready for start BOP Start the Unit 2 South NESW pump per 12-OHP-4021-020-002 :

Verify that 2-WMO-902, Unit 2 South NESW Pump discharge valve is open using valve position indicating lights Start the South NESW pump using the control board switch Direct AEO to verify the Backwash Selector switch in AUTO BOP Stop the Unit 2 North NESW pump per 12-OHP-4021-020-002 :

Close 2-WMO-901, North NESW Pump Discharge valve using control board switch Stop the Unit 2 North NESW pump using the control board switch Open 2-WMO-901, North NESW Pump Discharge valve using control board switch Place 2-PP-8N, North NESW Pump, control switch in AUTO

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 2 of 20 Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Event No.: 2 Event

Description:

The Crew will perform a power reduction to 95% using the normal operating procedure 2-OHP-4021-011-001, At Power Operation Including Load Swings.

Event Termination: When the Crew has completed the power reduction and restored systems to Automatic, the event is complete.

Symptoms/Cues:

N/A Time Position Applicants Actions or Behavior RO Prepare a reactivity plan for the 5% power reduction NOTE: This may have been performed during the scenario pre-brief)

US Direct actions of 2-OHP-4021-011-001, Attachment 2, Power Reductions Between 89% and 100%.

US Confirm load reduction is approved by the Shift Manager RO If the Crew determines that MANUAL rod control is required:

Place Full Length Bank Selector Switch in MANUAL Perform rod motion to adjust AFD or RCS temperature Place rod control in AUTO when desired RO/BOP Reduce turbine load per 2-OHP-4021-050-001, Attachment 5, Turbine Control Operation, using the Main Turbine HMI:

Adjust Tavf and Tref inhibit setpoints as desired, not to exceed +/-5

ºF Place Megawatt Control in IN Select desired MW Target Select desired MW Ramp Rate Select GO When evolution is complete, place Megawatt Control in OUT

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 3 of 20 Time Position Applicants Actions or Behavior RO NOTE: Boration may be performed using Attachment 2, Boric Acid Blender Operation in Manual Mode, Attachment 3, Boric Acid Blender Operation in the Borate Mode, Attachment 14 Blender Operation Short Form-Borate Mode, or Attachment 17, Blender Operation Short Form-Manual Mode. Actions listed below are from Attachment 3, which is the expected response.

Maintain Tavg by boration as necessary per 2-OHP-4021-005-002, Operation of the Unit 2 Boric Acid Blender:

If desired, verify charging header flow is >75 gpm and close the East CCP Emergency Leak Off valve 2-QMO-225 Verify the Boric Acid Blender is aligned for automatic Determine desired boration batch (may have been performed as part of scenario debrief)

Place Reactor Control Makeup Blend Control Switch in STOP Place RC Makeup Blend Control Mode Selector Switch in BORATE Set desired batch on BA flow totalizer:

o Depress PRE A and verify display reads PRE A o Depress PRE A again to display last requested batch amount preset o Depress an arrow to change value of associated decimal place o When new batch amount is preset, depress ENTER button twice Adjust 2-RU-33, Blender BA Flow Control to desired flow Place Reactor Coolant Makeup Blend Control switch in START and verify automatic actions:

o BA Pump(s) selected to RUN shift to FAST o 2-QRV-400, BLENDER TO CHG PUMPS SUCT, opens o 2-QRV-421, BORIC ACID TO BLENDER, throttles open to selected flow Divert letdown flow if desired using 2-RU-28 in manual or place 2-QRV-303 in the CVCS HU Tank position

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 4 of 20 Time Position Applicants Actions or Behavior RO If desired to clear the Boric Acid Blender Line when the boration is complete per 2-OHP-4021-005-002 Attachment 5, Boric Acid Blender Operation in Alternate Dilute Mode (expected and listed below) or 6, Blender Operation Short Form-Alternate Mode.:

Determine 27 gallons is required Place Reactor Control Makeup Blend Control Switch in STOP Place RC Makeup Blend Control Mode Selector Switch in ALT DILUTE Set desired batch on PW flow totalizer:

o Depress PRE A and verify display reads PRE A o Depress PRE A again to display last requested batch amount preset o Depress an arrow to change value of associated decimal place o When new batch amount is preset, depress ENTER button twice Adjust 2-RU-34, Blender PW Flow Control to desired flow If desired to make up only to CCP suction, place control switch for 2-QRV-451 in CLOSE Place Reactor Coolant Makeup Blend Control switch in START and verify automatic actions:

o 2-QRV-400, BLENDER TO CHG PUMPS SUCT, opens o 2-QRV-422, PRIM WATER TO BLENDER, throttle open o Primary Water flow indication on 2-QFC-422, PRI WATER FLOW, and 2-QRV-422 HMI RO When desired to align the boric acid blender for Automatic per 2-OHP-4021-005-002 Attachment 1, Boric Acid Blender Operation in Automatic Mode:

Verify Reactor Coolant Makeup Blend control switch in STOP Align boric acid blender control valves to Auto and Verify 2-RU-33 flow control is set for required flow rate Place RC Makeup Blend Control Mode Select Switch in AUTO Place Reactor Coolant Makeup Blend Control switch in START

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 5 of 20 Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Event No.: 3 Event

Description:

Controlling Pressurizer Pressure channel 2-NPP-151 fails downscale causing both spray valves to close. The crew should implement 2-OHP-4022-IFR-001, Instrument Failure Response, perform immediate actions from memory, take manual control of pressurizer pressure, and then implement 2-OHP 4022-013-009, Pressurizer Pressure Instrument Malfunction. The Crew will disable the failed channel and return pressurizer pressure control to automatic. The US should identify entry into the following Technical Specification conditions/actions:

3.3.1 Condition A Required Action A.1 3.3.1 Condition D Required Action D.1 3.3.2 Condition A Required Action A.1 3.3.2 Condition D Required Action D.1 3.3.2 Condition G Required Action G.1 3.3.4 Condition A Required Action A.1 3.5.2 Condition A Required Action A.1 Event Termination: When the Crew has completed 2-OHP 4022-013-009 actions to defeat the failed channel and return pressurizer pressure control to Automatic, the event is complete.

Symptoms/Cues:

2-NPP-151 fails low to 1700 psig Both spray valves close Actual RCS pressure begins to rise Panel SML-14 Status Lights energize:

CH I PRESS LOW-LOW CH I PRESS EXT LOW CH I PRESS LOW PERM P-11 Panel SML-17 Status Lights:

LP 1 CH 1 OTT RX TRIP LP 1 CH 1 OTT BLK ROD WDR ANN Panel 208 alarms:

Drop 8, PRZ PRESS LOW DEV BACKUP HTRS ON Drop 9, PRZ PRESS LOW-LOW Drop 10, PRZ PRESS EXT LOW ANN Panel 211 alarms:

Drop 5, LOOPS 1,2,3,4 OVERTEMP T AT TRIP SP Drop 10, LOOPS 1,2,3,4 OVERTEMP T AT C3 Time Position Applicants Actions or Behavior RO Recognizes and reports pressurizer pressure instrument failure based on control board indications and annunciators US Direct RO and BOP to perform immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 6 of 20 Time Position Applicants Actions or Behavior RO Reports instrument malfunction and performs the immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response, from memory:

Determines a pressurizer pressure instrument or control system issue exists Determines pressurizer pressure is not stable at or trending to program Places pressurizer pressure control in manual by taking manual control of 2-RU-27, PRZ PRESS CONTROL, 2-RU-24 AND 2-RU-25, PZR SPRAY CONTROL, or Pressurizer Heaters as desired and restore pressurizer pressure to program pressure Determine pressurizer PORVs are closed Crew Performs plant stability checks. (Order not important)

RO

1. Rx Power

2. RCS Temp

3. RCS Pressure

4. Pressurizer level

5. AFD BOP

1. Turbine Load

2. SG Level

3. MFP DP US Enters and directs actions of 2-OHP-4022-IFR-001, Instrument Failure Response procedure:

1. Verifies RO immediate actions taken from memory

2. Assigns manual control band for pressurizer pressure

3. Verifies no unexpected control rod motion occurred

4. Transitions to 2-OHP-4022-013-009, Pressurizer Pressure Instrument Malfunction US Enters and directs actions of 2-OHP-4022-013-009, Pressurizer Pressure Instrument Malfunction CREW RO RO RO RO/BOP US RO RO/BOP Performs the following actions as directed:

1. Determine 2-NPP-151 is the failed channel and is also the controlling channel

2. Verify pressure control is in Manual

3. Place PRESS CTRL SLECTOR switch 2-PS-455-F in Channels 2&3 position

4. Verify recorder selector switches 2-PS-455-G, 2-43-DT, 2 OPDT, and 2-43-OTDT are selected to channel 2, 3, or 4

5. Declare East CCP inoperable

6. Verify 2-QMO-225, East CCP Leak Off valve is open

7. Direct local action to open 2-QMO-225 breaker, 2-ABV-D-5C

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 7 of 20 Time Position Applicants Actions or Behavior RO Performs the following actions as directed to restore pressure control to automatic:

Verify 2-RU-27, PRZ PRESS CONTROL, in MANUAL If either spray valve controller is in manual, null the controller and return to auto Adjust pressurizer pressure to 2235 psig to null 2-RU-27 Place 2-RU-27 in AUTO RO Verify P-11 interlock is in the correct status (Status light on 2-SML-14 not lit)

US Identify entry into the following Technical Specification & /Technical Requirements Manual conditions/actions:

3.3.1 Condition A Required Action A.1 3.3.1 Condition D Required Action D.1 (Due to Table 3.3.1-1, Functions 6, 8a, 8b) 3.3.2 Condition A Required Action A.1 3.3.2 Condition D Required Action D.1 (Due to Table 3.3.2-1, Function 1d) 3.3.2 Condition G Required Action G.1 (Due to Table 3.3.2-1, Function 8b) 3.3.4 Condition A Required Action A.1 3.5.2 Condition A Required Action A.1 TRM 8.1.1 Condition A Required Action A.1 TRM 8.7.14 Condition B Required Actions B.1 & B.2 US Initiates corrective action for failed channel

a. Notifies management and WCSRO

b. Directs RO/BOP to generate work request US Notifies SM/MTI to Initiate actions to trip Bi-stables associated with 2-NPP-151 Pressurizer Pressure failure per 2-OHP-4022-013-009.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 8 of 20 Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Event No.: 4 Event

Description:

The running Generator Bus Duct Cooling fan will trip, and the standby fan will fail to automatically start. The Crew should manually start the standby Bus Duct Cooling Fan as a backup to a failed automatic action or per the Annunciator Response Procedure.

Event Termination: When the standby Bus Duct Cooling fan has been started and Bus Duct temperature returned to normal, the event is complete.

Symptoms/Cues:

East Bus Duct fan stops Pump Control Switch green light and red light de-energized Alarms:

221-19, GEN DUCT COOLING FAN FAILURE 221-18, GEN DUCT COOLING AIR TEMP HIGH (possible after short delay based on timing of crew response)

Time Position Applicants Actions or Behavior BOP Identify and report annunciators on Panel 221 BOP Perform applicable annunciator response procedures:

Place standby fan switch (West fan) in RUN Place failed fan switch (East fan) in OFF Dispatch AEO to investigate reason for loss of the East fan Determine power reduction for inoperable bus duct cooling is not required NOTE: The BOP may start the West Bus Duct fan prior to referring to the ARP as a backup manual action for a failed automatic action

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 9 of 20 Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Event No.: 5 Event

Description:

The event is a failure of the controller for 2-WRV-970, Main Turbine Lube Oil Temperature Control full closed in automatic. Main Turbine lube oil and bearing temperatures will rise and several alarms will actuate. The crew should respond per 2-OHP-4022-IFR-001 and take manual control of 2-WRV-970 to return oil temperatures to normal.

Event Termination:

When the crew has taken manual control of 2-WRV-970 and returned oil temperatures to normal, the event is complete.

Symptoms/Cues:

2-WRV-970, Main Turbine Lube Oil Temperature Control Valve, closes fully MT lube oil temperatures and bearing temperatures rise on recorder SG4 Alarms (Possible based on timing of Crew actions):

218-8, MAIN TURBINE THRUST BRG REC TEMP HIGH 218-9, MAIN TURBINE OIL CLR DISCH REC TEMP HIGH 218-30, MAIN TURB BRG 9 LUBE OIL TEMP HIGH Time Position Applicants Actions or Behavior BOP Recognizes and reports automatic failure of 2-WRV-970, Main Turbine Lube Oil Temperature Control Valve based on control board indications and annunciators US Direct RO and BOP to perform immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response BOP Reports instrument malfunction and performs the immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response, from memory:

Determines a lube oil temperature control system issue exists Determines Main Turbine Lube Oil controller is not controlling properly in AUTOMATIC Places controller for 2-WRV-970 in HAND and open the valve as necessary to stabilize temperature in desired band Establish manual control band for Main Turbine Lube Oil temperature (110-120 ºF nominal)

Determine that Main Turbine Lube Oil Temperature is under control

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 10 of 20 Time Position Applicants Actions or Behavior Crew Performs plant stability checks. (Order not important)

RO

1. Rx Power

2. RCS Temp

3. RCS Pressure

4. Pressurizer level

5. AFD BOP

1. Turbine Load

2. SG Level

3. MFP DP US Enters and directs actions of 2-OHP-4022-IFR-001, Instrument Failure Response procedure:

1. Verifies BOP immediate actions taken from memory

2. Assigns manual control band for main turbine lube oil

3. Verifies no unexpected control rod motion occurred

4. Initiate repair for failed controller

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 11 of 20 Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Event No.: 6 Event

Description:

A ~8 gpm SG tube leak is initiated on 22 SG. The crew should diagnose SG tube leakage based on pressurizer level changes and radiation monitor indications and enter AOP 2-OHP-4022-002-021, Steam Generator Tube Leak. The Crew should stabilize pressurizer level with manual control, determine leak rate, and determine a reactor shutdown is required. The US should identify entry into the following Technical Specification condition/actions: 3.4.13 Condition B Required Action B.1 & B.2.

Event Termination: When the Crew has stabilized pressurizer level, quantified the leak rate, and identified the Tech Spec required shut down, the event is complete.

Symptoms/Cues:

Pressurizer level lowers Charging flow rises VCT Level lowers The following Rad Monitor readings will rise:

SRA-2805, Gland Steam Condenser Vent SRA-2905, Steam Jet Air Ejector The following ANN Panel 211 alarms actuate:

Drop 48, PPC-RMS U1 CT ALARM OR ABNORMAL Drop 49, PPC-RMS U2 CT ALARM OR ABNORMAL Time Position Applicants Actions or Behavior CREW Diagnose SG Tube Leakage based on lowering pressurizer level with stable Tavg and secondary radiation monitor alarms US Enter and direct actions of 2-OHP-4022-002-021, Steam Generator Tube Leak NOTE: If the Crew fails to diagnose SG Tube Leakage, they may enter 2-OHP-4022-002-020, Excessive Reactor Coolant Leakage, and perform actions of this procedure until SG Tube Leakage is identified US Inform the Shift Manager of event in progress to determine if Emergency Classification is required NOTE: Leak rate of ~8 gpm will not exceed the 25 gpm limit for identified leakage required to declare an Unusual Event

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 12 of 20 Time Position Applicants Actions or Behavior RO/BOP Perform actions of 2-OHP-4022-002-021 as directed:

Identify the Unit is in Mode 1 Determine pressurizer level is not stable or trending to program level Raise charging flow to maintain pressurizer level by manual control of 2-QRV-251 and 2-QRV-200 while maintaining seal injection flow at 6-12 gpm per RCP Determine further steps to stabilize pressurizer level are not required Determine VCT makeup not initially required and monitor automatic makeup when it occurs Perform Attachment B:

o Determine Auxiliary Steam is on Unit 1 o Direct local action to place 12-DRV-710, Turbine Room Sump Pumps Discharge control valve control switch in RECIRC o Direct Chemistry to sample SGs for activity o Direct Chemistry to monitor Turbine Room Sump compositor samples more frequently o Notify RP to monitor turbine building leaks for contamination o Notify RP to survey main steam lines for activity Determine leak rate is ~8 gpm Determine primary to secondary leak rate exceeds 75 gallons per day and contact Duty Staff Supervisor to determine if shutdown is prudent Continue to monitor leak rate for possible implementation of continuous actions steps for reactor trip/SI if leakage increases above limits US Determine entry into T.S. 3.4.13 Condition B Required Actions B.1 & B.2

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 13 of 20 Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Event No.: 7 Event

Description:

The SG Tube leak will increase to a tube rupture of ~400 gpm. The Crew should determine that leak rate has increased to >100 gpm and perform a manual reactor trip and actuate safety injection. The Crew will complete actions of 2-OHP-4023-E-0, Reactor Trip or Safety Injection and transition to 2-OHP-4023-E-3, Steam Generator Tube Rupture. Failure of the Steam Dump system will require RCS Cooldown using SG PORVs. RCS depressurization will be performed using pressurizer spray. One pressurizer spray valve will stick open, requiring the Crew to stop 23 and 24 RCPs when depressurization is complete. ECCS flow will be terminated.

Event Termination: The scenario may be terminated any time after ECCS flow is stopped.

Symptoms/Cues:

Pressurizer level lowers rapidly Pressurizer pressure lowers 22 SG NR level rises slightly, 22 SG FRV throttles closed When Steam Dump is transferred to Steam Pressure Mode in E-3:

Steam Dump valves close Condenser Vacuum Permissive C9 status light on 2-SML-18 de-energizes When pressurizer spray valves are manually opened in E-3 2-NRV-164 fails full open Red Open position light remains on when control signal is reduced RCS depressurization continues Time Position Applicants Actions or Behavior RO Identify increase in leak rate to >100 gpm US Direct performance of a manual reactor rector trip and safety injection per 2-OHP-4022-002-021 continuous action step Ensures immediate actions of 2-OHP-4023-E-0 are completed Directs subsequent actions of 2-OHP-4023-E-0.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 14 of 20 Time Position Applicants Actions or Behavior RO/BOP Performs the immediate actions of E-0 from memory:

Perform a manual reactor trip using control board switches

1. Checks reactor trip - Determines reactor Trip and Bypass breakers Open, all rods < 10 steps, neutron flux lowering

2. Checks turbine trip - Determines Turbine Stop Valve Closed Status Lights Lit

3. Checks power to AC emergency buses - Determines all emergency buses T21A, T21B, T21C, and T21D energized and both annunciators clear for Open Phase Manually initiates SI using control board switches

4. Checks safety injection status - Determines 2-QMO-225 white light is not lit and actuates SI using both sets of switches RO/BOP Complete actions of E-0 through steps 5-18 as directed:

5. Check if Main Steam line isolation is required-Determine isolation is not required based on containment pressure <2.8 psig SG pressures and steam flows at normal post trip value.

6. Check if CTS is required-Determine containment pressure has remained below 2.8 psig:

7. Implement Attachment A while continuing with E-0 (actions listed below)

8. Check if ruptured SG is suspected-Isolate AFW flow to 22 SG when narrow range level exceeds 13%

9. Check AFW pumps running-Determine all three AFW pumps are running

10. Check total AFW flow >240 x103 PPH

11. Minimize unnecessary RCS cooldown-Reduce total AFW flow to between 240 x103 PPH and 450 x103 PPH and control NR level between 13% and 50%

12. Check AFW pump discharge valves-Determine valves are throttled

13. Check FW isolation-Determine both MFPs tripped, both MFP discharge valves closed, all four FRVs closed, and all four feed water isolation valves closed

14. Check RCS temperature-Determine RCS temperature is stable, or if lowering, no dumping of steam is occurring, 2-DRV-407 is closed, AFW flow is >240 x103 PPH, and SG stop valves should remain open.

15. Check pressurizer PORVs and spray valves-Determine PORVs closed, spray valves are closed, and PORV block valves are all energized.

16. Check if RCPs should be stopped-Determine criteria are not satisfied to stop RCPs.

17. Check if SG secondary pressure boundaries are intact-Determine no SG pressure is lowering in an uncontrolled manner nor completely depressurized

18. Check if SG tubes are intact-Determine 22 SG NR level rising in an uncontrolled manner and transition to 2-OHP-4023-E-3, Steam Generator Tube Rupture

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 15 of 20 Time Position Applicants Actions or Behavior RO/BOP Perform actions of Attachment A as follows:

1. Check ECCS pumps all running-Determine CCPs, SI pumps, and RHR pumps are all running.

2. Check ECCS flow-Determine flow is indicated for BIT flow; Determine no SI pump flow or RHR HX flow.

3. Check ECCS valves in proper alignment-Determine ECCS alignment is correct using status lights on 2-SML-12A, 2-SML-12B, 2-SML-12C, 2-SML-11A, 2-SML-11B, and 2-SML-11C.

4. Check CCW status-Determine both CCW pumps running, CCW surge tank stable, and CCW monitor lights in proper status using 2-SML-8B.

5. Check ESW status-Determine both ESW pumps running, both discharge valves open, and proper status lights on 2-SML-7

6. Check if containment recirculation fans should be running-Determine containment pressure <1 psig

7. Place DIS in service by directing local action to stop all ice condenser air handling units and turning on all hydrogen ignitors when local action is reported complete

8. Check containment vent and Phase A isolation-Determine Containment Vent Isolation and Phase A isolation are actuated and completed on both trains, and direct actions to periodically monitor SFP radiation, SFP cooling, and SFP level

9. Check ESF fans both running-Determine both fans are running

10. Align control room ventilation by checking both pressurization fans are running, stopping one pressurization fan, checking cable vault hatch closed, checking control room dampers aligned for SI, and checking at least one control room air handling unit is running

11. Align PACHMS for service by momentarily placing containment hydrogen sample bypass switches in BYPASS

12. Request Unit 1 perform actions

13. Check generator trip-Determine generator output breakers are both open and main generator excitation control is OPEN

14. Check Load Conservation status-Determine all AC buses T21B and T21C are energized by offsite power

15. Check NESW pressure is >65 psig on 2-WPI-901

16. Check Containment Isolation Phase B status-Determine Containment Isolation Phase B is not actuated.

17. Report completion of Attachment A and report any unexpected conditions or actions taken US Announces transition to OHP-4023-E-3, Steam Generator Tube Rupture and directs operator actions.

Checks Status Trees for Red Path

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 16 of 20 Time Position Applicants Actions or Behavior RO/BOP Reviews E-3 Foldout Page Criteria and perform steps of E-3 as directed RO Determine RCPs should not be stopped based on RCS pressure RO/BOP Direct Chemistry to sample all SGs for activity using 12-THP-4030-002-208, Primary to Secondary Leak Rate BOP Identify 22 SG as ruptured based on unexpected rise in narrow range SG level CT1: Isolate ruptured SG:

Initiating Cue: Indication/annunciation of a SGTR in one SG (Increasing SG water level, increased secondary radiation) with indications of a reactor trip and safety injection Performance Feedback: Indication of stable or increasing pressure in the ruptured SG (SG Stop Valves closed) and indication of zero feed water flow rate and lowered SG level rise in the ruptured SG (Auxiliary Feed Flow isolated).

Success Path: No malfunctions are part of the scenario which would complicate procedurally directed action to isolate the ruptured SG.

Measurable Performance Standard: Isolate feed water flow into and steam flow from the ruptured SG before a transition to ECA-3.1 occurs by:

o Isolating feed water flow into the ruptured SG by closing AFW supply valves o Isolating flow from the ruptured SG by completing applicable actions listed in E-3 step 3.

BOP Isolate flow from ruptured SG:

Adjust 22 SG PORV controller to 1040 psig and check PORV closed Close 2-MCM-221, SG2 MAIN STEAM TO AUX FP TURB (CT1 related action)

Determine blowdown isolation and blowdown sample valves for 22 SG are closed Place 2-DRV-407 in CLOSE and check closed Determine steam line warming valves are closed Trip closed 22 SG stop valve 2-MRV-220 (CT1 related action)

Verify ruptured SG stop valve dump valves 2-MRV-221 and 2-MRV-222 closed BOP Verify feed flow isolated to 22 SG when NR level is >13% if not previously performed BOP Determine 22 SG is isolated from intact SGs based on differential pressure BOP Determine 22 SG pressure is >450 psig CREW Determine required core exit temperature (488.2 expected)

RO Determine RCPs are running and condenser steam dump is available RO/BOP Attempt to transfer steam dump to steam pressure mode:

Place steam pressure controller in MANUAL Match controller output to valve demand signal meter Place steam dump mode control in STEAM PRESSURE Determine steam dump valves are failed closed

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 17 of 20 Time Position Applicants Actions or Behavior CT2: Control initial RCS cool down Initiating Cue: Indication/annunciation of a SGTR in one SG (Increasing SG water level, increased secondary radiation) with indications of a reactor trip and safety injection AND indication of ruptured SG pressure >450 psig Performance Feedback: Indication of intact SG PORV position, steam flow rate greater than zero, indication of RCS temperature decreasing.

Success Path: RCS cool down will be performed by the second priority action in E-3 to use intact SG PORVs due to malfunction of the Steam Dump system.

Measurable Performance Standard: Establish/maintain RCS temperature so that transition from E-3 does not occur because the RCS temperature is in either of the following conditions:

o Too high to maintain minimum required sub-cooling (requiring transition to ECA-3.1); OR o Too low as to cause a challenge to sub-criticality or integrity CSF (red or orange path requiring transition to the applicable CSF recovery procedure.)

BOP Manually dump steam from 21, 23, & 24 SGs at the maximum rate by fully opening the PORVs (CT2 related action)

RO/BOP When Tavg Lo-Lo Perm P12 status light 2-SML-17 Drop 30 is lit, block steam line break SI and bypass steam dump low-low Tavg interlock RO/BOP WHEN core exit thermocouples are less than target temperature, stop the RCS cool down (CT2 related action)

RO/BOP After stopping cool down, maintain core exit thermocouples 10-20 ºF less than target temperature BOP Control NR level in 21, 23, & 24 SGs between 27% and 50%

RO Determine pressurizer PORVs closed and PORV block valves are energized and open RO/BOP Reset SI and CI Phase A BOP Determine control air pressure >85 psig and open control air valves to containment 2-XCR-100, 2-XCR-101, 2-XCR-102, and 2-XCR-103 RO/BOP Stop both RHR pumps US Do not proceed with E-3 actions until RCS cool down is complete CREW Determine ruptured SG pressure is stable or rising and RCS subcooling is >60 ºF CT3: Depressurize RCS to E-3 SI termination criteria Initiating Cue: Indication/annunciation of a SGTR in one SG (Increasing SG water level, increased secondary radiation) with indications of a reactor trip and safety injection AND indication that the RCS is cooled down to target temperature.

Performance Feedback: Indication of Spray Valve open position, RCS pressure decreasing, and pressurizer level rising.

Success Path: Procedurally directed RCS depressurization will be performed using manual control of both pressurizer spray valves which are not affected by selected simulator malfunctions.

Measurable Performance Standard: Depressurize RCS to meet SI termination criteria before water release from the ruptured SG PORV or safety valve as indicated by SG NR level indicating 100% with SG WR level stable and a SG PORV or Safety Valve not fully closed.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 18 of 20 Time Position Applicants Actions or Behavior RO Depressurize RCS to minimize break flow and refill pressurizer (CT3 related actions):

Determine normal pressurizer spray is available Open both spray valves using manual control of master controller 2-RU-27 or both spray valve controllers 2-RU-24 and 2-RU-25 When depressurization criteria are satisfied, attempt to close both spray valves Determine pressurizer spray valve failed to close and stop RCP 23 and 24 CREW Check if ECCS flow should be terminated:

Determine RCS subcooling is > 40 ºF Determine secondary heat sink exists based on minimum AFW flow or intact NR SG level Determine RCS pressure stable or rising Determine pressurizer level >20%

CT4: Terminate ECCS Flow Initiating Cue: Indication/annunciation of a SGTR in one SG (Increasing SG water level, increased secondary radiation) with indications of a reactor trip and safety injection, indication that the RCS is cooled down to target temperature, indication that RCS depressurization is complete, AND indications that SI termination criteria are met.

Performance Feedback: Indication of decreasing SI pump flow, decreasing BIT flow Success Path: The delay in completing RCS depressurization steps is not significant due to clear procedural actions to stop RCPs to stop depressurization. Thus, procedurally directed actions to terminate SI flow can be performed in a timely manner from the Control Room.

Measurable Performance Standard: Terminate ECCS flow before water release from the ruptured SG PORV or safety valve as indicated by SG NR level indicating 100% with SG WR level stable and a SG PORV or Safety Valve not fully closed by:

o Stopping both SI pumps AND o Stopping all but one running CCP AND o Isolating BIT flow RO/BOP Stop both SI pumps and one CCP (CT4 related actions)

RO/BOP Isolate BIT flow:

Determine CCP suction aligned to RWST Reset and open CCP leak-off valve 2-QMO-226 and determine 2-QMO-225 is open with breaker OFF from previous event Close BIT inlet valves (CT4 related actions)

Close BIT outlet valves (CT4 related actions)

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 19 of 20 Simulator Instructions:

SETUP:

Reset the simulator to a MOL 100% IC with the North NESW Pump in service.

Place all backup heaters on and allow pressure to stabilize.

Mark up 2-OHP-4021-011-001 Attachment 2 to show completion of prerequisites.

Verify the East Bus Duct Fan is running and the West Bus Duct Fan is in Auto Enter the following items to simulate failure of the West Bus Duct Fan to auto start:

Set up failure of the steam dump system when control is transferred to steam pressure:

Event 1:

If asked, report the South NESW pump is ready for start and personnel are clear of the area.

When directed, report the Backwash Selector switch in AUTO Event 2:

If asked as Shift Manager, inform the Crew that load reduction is approved.

Event 3:

When the Crew has completed the power reduction, or at the direction of the Lead Evaluator, enter the pressurizer pressure instrument low failure:

5 minutes after being directed to open the breaker for 2-QMO-225 (East CCP ELO, ABV-D-5C), insert the following global malfunction and report completion:

Event 4:

When the Crew has completed 2-OHP 4022-013-009 actions to defeat the failed channel and return pressurizer pressure control to Automatic, and with the concurrence of the Lead Evaluator, enter a loss of the East Bus Duct Cooling Fan:

If asked to report bus duct temperatures, wait three minutes and report the following, based on status of the standby fan:

If West Bus Duct fan is running and Panel 121 Drop 19 is clear, report bus duct temperature is 77 degrees C and lowering If West Bus Duct fan is running and Panel 121 Drop 19 is NOT clear, report bus duct temperature is 85 degrees C and lowering If the West Bus Duct fan has not yet been started and Panel 121 Drop 19 is lit, report bus duct temperature is 95 C degrees and rising If asked to report cooling water flow, report cooling water flow is normal If asked to check the breaker for the East Bus Duct fan, wait three minutes and report the breaker is tripped.

Event 5: When the standby Bus Duct Cooling fan has been started and Bus Duct temperature returned to normal, enter a failure of the Main Turbine Lube Oil temperature controller:

U2_SD_StmPress ET10 ZGI43SD2A_U2 OFFRST ET10 U2_101QMO225 U2_NPP151 1700 TRG= 5 "dlo ZLO101GLC1_U2[GRN]"

U2_101GLC1 ZLO101GLC1_U2[GRN]

U2_101GLC2 TRG= 5 "dmf u2_101glc1" TRG 5 on West Bus Duct Fan in RUN ZLOSTMC2_U2[15] OFF ET10

Op. Test No.: Cook 2022 Scenario No.: NRC2022-3 Form 3.3-2 Page 20 of 20 Event 6:

When the crew has taken manual control of 2-WMO-970 and returned oil temperatures to normal, enter a tube leak in 22 SG:

If asked as Unit 1 to assume the Auxiliary Steam loads, reply that 50# and 150# auxiliary steam headers are already on Unit 1 When directed to place 12-DRV-710 in RECIRC, wait one minute and report completion.

Event 7:

When pressurizer spray valves are opened in E-3, insert a failure of pressurizer spray valve 2-NRV-163 full open:

Perform the following actions as directed during performance of E-0:

Stop ice condenser air handling units and report completion in ~5 minutes:

When directed to perform Unit 1 actions per E-0 Att. A:

1. Report chemistry has been directed to place Train A PACHMS in service, Unit 1 control room pressurization is aligned for a Unit 2 SI, 2-HV-AS-1 is in service

2. Place PACHMS Train A in service (30 minute delay):

When requested, run the following file to sample SGs, 22 last:

U2_CHR02 ON After 30 Min Delay U2_RCR44 3 app! SAMPLSG3142_U2.app U2_RC15A 100 U2_SW07A 0 Modify U2_RC23B 40 U2_RC23B 1 U2_CHR01 OFF After 5 Min Delay

Op. Test No.: Cook 2022 Scenario No.: NRC2022-2 Form 3.3-1 Page 1 of 1 Form 3.3-1 Scenario Outline Facility: DC COOK 1 & 2 Scenario #: NRC2022-4 Scenario Source: New Op. Test #: Cook 2022 Examiners:

Applicants/

Operators:

Initial Conditions: 80% power. The South Condensate Booster Pump is running with slightly elevated temperatures.

Turnover: After turnover, shift the Condensate Booster Pumps to the Middle Pump in service and the South Pump in standby. Then, continue power increase to 100% power.

Critical Tasks**: 1. Isolate Main Turbine from SGs during ATWS.

2. Start AFW Pumps during ATWS.

Event No.

Malf. No.

Event Type*

Event Description**

1 N-BOP Shift Condensate Booster Pumps 2

R-RO Raise reactor power 3

U2_QFI200 I-RO MC-RO Charging Flow Instrument QFI-200 fails low 4

U2_ECC short U2_CC02B C-BOP M-BOP TS Running CCW pump failure, CCW pump Auto start fails 5

U2_QLC452 I-RO VCT Level channel 2-QLC-452 Fails High 6

U2_BLP141 I-BOP MC-BOP TS Controlling SG Level Channel fails high 7

U2_RP12A U2_RP12B U2_RP03A U2_RP03B U2_TC02 U2_RP07A U2_RP07B U2_FW48A U2_FW48B U2_FW48C M-CREW C-CREW C-CREW Inadvertent SI/Loss of Feed ATWS (EOP entry)

Auto & Manual turbine trip failure Auto Main Steam Isolation failure AFWP auto start failures 8

SI Termination

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor, (TS)Tech Spec, (MC)Manual Control

- Details on subsequent pages

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 1 of 19 Form 3.3-2 Required Operator Actions Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Event No.: 1 Event

Description:

The Crew will start the Middle Condensate Booster Pump and then stop the South Condensate Booster pump per 2-OHP-4021-054-001 Attachment 2, Operation of the Hotwell and Condensate Booster Pumps Event Termination: When the Middle Condensate Booster Pump is in service and the South Condensate Booster Pump is stopped, the event is complete.

Symptoms/Cues:

N/A Time Position Applicants Actions or Behavior BOP Determine that reactor power is low enough to compensate for a power transient during pump swap BOP Shift Condensate Booster Pumps per 2-OHP-4021-054-001 Attachment 2 step 4.7:

Determine maintenance has not been performed on the Condensate Booster Pump oil system Place the standby North Hotwell Pump control switch in NEUT Place the standby Middle Condensate Booster Pump control switch in NEUT Place the standby West TACW Pump control switch in NEUT Determine the Middle Condensate Booster Pump ELO is not failed open Determine Bus 2A voltage is >117.6V Start the Middle Condensate Booster Pump o Report annunciator 216 drop 73 if not previously identified as an expected alarm Direct AEO to report local Condensate Booster Pump oil pressure and determine it is 2 psig Determine total condensate flow is >2.0E6 pph and that the Middle Condensate Booster Pump recirc valve should be closed Stop the South Condensate Booster Pump and place the control switch in AUTO Determine ELO was not previously failed open Direct AEO to locally verify 2-CRV-224, Low Pressure Heaters Condensate Bypass control valve is closed Notify Chemistry of Condensate Booster Pump configuration change Place standby Hotwell Pump, Condensate Booster Pump, and TACW Pump control switches in AUTO

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 2 of 19 Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Event No.: 2 Event

Description:

The Crew will initiate a load increase from 80% using the normal operating procedure 2-OHP-4021-001-006, Power Escalation.

Event Termination: When the Crew has raised turbine load sufficiently as determined by the Lead Evaluator, the event is complete.

Symptoms/Cues: N/A Time Position Applicants Actions or Behavior CREW Develop a reactivity plan for power increase to 100% (May have been performed prior to entry into the simulator)

NOTE: It is expected the RO will place rod control in Manual per 2-OHP-4021-001-006, Power Escalation.

NOTE: It is expected the RO will choose to perform dilution using the Alternate Dilute mode with makeup to the CCP suction only. It is procedurally allowed to use either normal or alternate dilute modes. The expected actions for alternate dilute are listed below.

RO NOTE: Dilution may be performed using Attachment 5, Boric Acid Blender Operation in Alternate Dilute Mode, or Attachment 16 Blender Operation Short Form-Alternate Mode. Actions listed below are from.

Initiate boron dilution per reactivity plan per 2-OHP-4021-005-002, Operation of the Unit 2 Boric Acid Blender:

If desired, verify charging header flow is >75 gpm and close the East CCP Emergency Leak Off valve 2-QMO-225 Verify Boric Acid Blender is aligned for Automatic Verify Reactor Coolant Makeup Blend Control Switch in STOP Verify RC Makeup Blend Control Switch in ALT DILUTE Set desired batch on the PW Flow Integrator o Depress PRE A and verify display reads PRE A o Depress PRE A again to display last requested batch amount preset o Depress an arrow to change value of associated decimal place o When new batch amount is preset, depress ENTER button twice Adjust 2-RU-34, Blender PW Flow Control to desired flow rate If desired to makeup to the CCP suction only, then close 2-QRV-451, Blender to VCT

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 3 of 19 Time Position Applicants Actions or Behavior RO Continue actions to initiate dilution::

Place Reactor Coolant Makeup Blend Control Switch in START and verify automatic actions:

o PW pump(s) selected to AUTO start o 2-QRV-422, Primary Water to Blender, throttles open to selected flow o 2-QRV-400, Blender to Charging Pump Suction, opens o If in AUTO, 2-QRV-451, Blender to VCT, opens If desired to divert letdown flow, perform one of the following:

o Manually adjust 2-RU-28, VCT Level Control o Place 2-QRV-303, VCT/Holdup Tank Inlet Selector in the CVCS HU Tank position When desired to restore VCT level control to AUTO, then perform the following:

o Verify 2-RU-28, VCT Level Control in AUTO o Verify 2-QRV-303, VCT/Holdup Tank Inlet Selector in AUTO When the selected batch is complete or when desired, place the Reactor Coolant Makeup Blend Control Switch in STOP Verify the PW Flow Totalizer is set to 0 Verify 2-QRV-451, Blender to VCT in AUTO Align the Boric Acid Blender to Automatic RO/BOP Raise turbine load per 2-OHP-4021-050-001, Attachment 5, Turbine Control Operation, using the Main Turbine HMI:

Adjust Tave and Tref inhibit setpoints as desired, not to exceed

+/-5 ºF Place Megawatt Control in IN Select desired MW Target Select desired MW Ramp Rate Select GO When evolution is complete, place Megawatt Control in OUT

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 4 of 19 Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Event No.: 3 Event

Description:

The event is a failure of QFI-200, Charging Flow detector. The low flow signal results in the output of 2-QRV-251, Charging Flow controller, to fail to 100%. This results in a high charging flow and rising pressurizer level. The Crew should perform immediate actions for 2-OHP-4022-IFR-001, Instrument Failure Response, diagnose unexpected charging flow reduction from an instrument failure, and restore charging flow using 2-QRV-251 in manual to maintain pressurizer level.

Event Termination: When actions of 2-OHP-4022-IFR-001 have been completed, the event is complete. Note that 2-QRV-251 will remain in Manual for the duration of the scenario Symptoms/Cues:

Indicated charging flow 2-QFI-200 fails low Charging flow control valve 2-QRV-251 fails to 100% open Indicated Seal Injection flow rises Pressurizer level rises slowly Annunciator 208-20, CHARGING FLOW LESS THAN MIN SET POINT NOTE: It is likely the Crew will stop the power ascension to respond to the instrument failure.

Time Position Applicants Actions or Behavior RO Recognizes and reports charging flow instrument failure based on control board indications and annunciators US Direct RO and BOP to perform immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response RO Reports instrument malfunction and performs the immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response, from memory:

Determines a pressurizer level control system issue exists Determines pressurizer level is not stable at or trending to program Places pressurizer level control in manual by taking manual control of 2-QRV-251 using 2-RU-29, CCP DISCH FLOW CTRL and restore pressurizer level to program level Crew Performs plant stability checks. (Order not important)

RO

1. Rx Power

2. RCS Temp

3. RCS Pressure

4. Pressurizer level

5. AFD BOP

1. Turbine Load

2. SG Level

3. MFP DP

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 5 of 19 Time Position Applicants Actions or Behavior US Enters and directs actions of 2-OHP-4022-IFR-001, Instrument Failure Response procedure:

1. Verifies RO immediate actions taken from memory

2. Assigns manual control band for pressurizer level (nominal program level +/-5%)

3. Verifies no unexpected control rod motion occurred

4. Initiates corrective action for instrument failure US Determine entry is required for Technical Requirements Manual TRO 8.7.14 Condition B Required Actions B.1 & B.2

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 6 of 19 Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Event No.: 4 Event

Description:

The event is a loss of the East CCW pump, with an auto start failure of the West CCW pump. The Crew should diagnose a loss of CCW and manually start the West CCW pump as a backup to a failed automatic action or per the Annunciator Response Procedure. The US should identify required Technical Specification actions for one inoperable CCW train.

Event Termination: When the crew has started the West CCW pump and identified applicable Tech Spec actions, the event is complete.

Symptoms/Cues:

East CCW pump breaker trips The West CCW pump does not auto start Annunciators:

204-83, CCW PUMP MOTOR INSTANT TRIP 204-84, EAST CCW PUMP DISCHARGE PRESSURE LOW Multiple additional annunciators due to loss of CCW flow which clear on start of the West CCW pump Time Position Applicants Actions or Behavior CREW Diagnose a Loss of ALL Component Cooling Water due to trip of the East CCW pump.

BOP Determine the West CCW failed to auto start and manually start the West CCW pump as a backup to a failed automatic action.

NOTE: This action should be taken without referencing a procedure.

The ARP for 204-84 and the AOP for CCW Malfunction also direct this action.

BOP Respond per ARP for 204-83:

Place East CCW pump in LOCKOUT US Identify entry into the following Technical Specification condition/action:

3.7.7 Condition A Required Action A.1.

Identify that entry into support system conditions and required actions is not required per T.S. LCO 3.0.6

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 7 of 19 Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Event No.: 5 Event

Description:

The event is a high failure (in range) of VCT Level channel 2-QLC-452. The Letdown Divert valve will reposition to the CVCS Holdup Tank, resulting in lowering VCT level. This will be a silent failure, with the only initial indications being the level meter and the divert valve position. After several minutes, VCT level on the operable VCT level channel 2-QLC-451 will lower to the point where an automatic makeup will start. The crew should perform immediate actions for 2-OHP-4022-IFR-001, Instrument Failure Response, diagnose VCT Level Instrument failure and take divert valve QRV-303 to VCT position to stabilize the plant. The Crew should then perform actions of 2-OHP-4022-013-017, VCT Instrument Malfunction.

Event Termination: When actions of 2-OHP-4022-013-017 are complete up to energizing the RWS relay, and TRM has been referenced, or at Lead Evaluator discretion, the event is complete.

Symptoms/Cues:

QLC-452 VCT level indication rises to 100%.

QRV-303, Letdown diversion, will fully open.

Actual VCT level will lower due to diversion of QRV-303, causing QLC-451 to lower, and VCT pressure, (QPI-451), to lower.

Annunciator 209-49, VOLUME CONTROL TANK LEVEL LOW (possible based on timing of crew actions)

Time Position Applicants Actions or Behavior RO Recognizes and reports instrument failure/annunciator on Panel #209 indicative of a VCT Level instrument failure (Drop 49, if actuated).

US Direct RO and BOP to perform immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response RO Reports instrument malfunction and performs the immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response, from memory:

1. Determines a VCT Level Control issue exists

2. Determines one VCT level channels indicate <78% and lowering with the other channel failed high

3. Stop letdown diversion by placing VCT/HOLDUP TK INLET SELECTOR 2-QRV-303 in VCT Crew Performs plant stability checks. (Order not important)

RO

1. Rx Power

2. RCS Temp

3. RCS Pressure

4. Pressurizer level

5. AFD BOP

1. Turbine Load

2. SG Level

3. MFP DP

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 8 of 19 Time Position Applicants Actions or Behavior US Enters and directs actions of 2-OHP-4022-IFR-001, Instrument Failure Response procedure:

1. Verifies RO immediate actions taken from memory

2. Assigns manual control bands for VCT level and pressure (nominal 15-78% Level and 15-35 psig Pressure)

3. Verifies no unexpected control rod motion occurred

4. Transitions to 2-OHP-4022-013-017, VCT Instrument Malfunction US Enters and directs actions of 2-OHP-4022-013-017, VCT Instrument Malfunction:

1. Determine 2-QLC-452 is failed

2. Direct RO to operate the Boric Acid Blender in Manual as required to maintain VCT level greater than 15%

3. Notify SM/MTI to initiate actions to energize associated RWS Relay in accordance with Attachment B.

4. Direct Work Control to prepare Caution tags as directed in 2-OHP-4022-013-017 NOTE: Action to energize the RWS relay requires access to the SSPS Engineering Work Station which is not physically modeled in the simulator and will not be performed during the scenario.

US Refers to TRM 8.1.1, Boration Systems - Operating:

Condition A Required Action A.1.

o Enters action statement to restore to operable status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 9 of 19 Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Event No.: 6 Event

Description:

SG 24 level channel will slowly fail high. SG 24 feed water regulating valve 2-FRV-240 will slowly close, causing reduction in actual level indicated on the two operable channels. The crew should diagnose the instrument failure, implement 2-OHP-4022-IFR-001, Instrument Failure Response, perform immediate actions, take manual control of the feed regulating valve for SG 24 to stabilize level, and then perform actions of 2-OHP-4022-013-013, Steam Generator Level Instrument Malfunction. The US should identify entry into the following Technical Specification conditions/actions:

3.3.1 Condition A Required Action A.1 3.3.1 Condition D Required Action D.1 3.3.2 Condition A Required Action A.1 3.3.2 Condition D Required Action D.1 Event termination: When actions of 2-OHP-4022-013-013 are complete up to bistable tripping, the event is complete.

Symptoms/Cues:

SG 24 Channel 2 level indicator (2-BLP-141) fails full scale high over 2 minutes.

Feed flow to SG 24 lowers, causing actual level as indicated on SG 24 channels 3 & 4 to lower.

Controller output for SG 24 Feed Water Regulating valve lowers.

Reactor will trip on low SG level without operator action.

Annunciators:

214-31, STEAM GEN 4 WATER LEVEL HIGH-HIGH 214-32, STEAM GEN 4 WATER LVL HIGH DEVIATION Time Position Applicants Actions or Behavior BOP Recognizes and reports annunciators on Panel #214 US Direct RO and BOP to perform immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response BOP Reports instrument malfunction and performs the immediate actions of 2-OHP-4022-IFR-001, Instrument Failure Response, from memory:

Determines a SG Level Control condition exists Determines #24 SG NR level is not stable at or trending to 44%

and places FRV-240, SG #24 MFW Reg. Valve controller in manual Raises controller output to match the operable feed flow channel with steam flow.

Restores SG #24 level to program.

Determines SG PORVs all closed Determines MFP Differential Pressure is controlling at appropriate differential pressure for current actual steam flow.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 10 of 19 Time Position Applicants Actions or Behavior Crew Performs plant stability checks. (Order not important)

RO

1. Rx Power

2. RCS Temp

3. RCS Pressure

4. Pressurizer level

5. AFD BOP

1. Turbine Load

2. SG Level

3. MFP DP US Enters and directs actions of 2-OHP-4022-IFR-001, Instrument Failure Response procedure:

1. Verifies BOP immediate actions taken from memory

2. Assigns manual control band for #24 SG level (nominal 40-48%)

3. Verifies no unexpected control rod motion occurred

4. Transitions to 2-OHP-4022-013-013, Steam Generator Level Instrument Malfunction US Enters and direct actions of 2-OHP-4022-013-013, Steam Generator Level Instrument Malfunction US Identify entry into the following Technical Specification conditions/actions:

3.3.1 Condition A Required Action A.1 3.3.1 Condition D Required Action D.1 (Due to Table 3.3.1-1, Function 14).

3.3.2 Condition A Required Action A.1 3.3.2 Condition D Required Action D.1 (Due to Table 3.3.2-1, Functions 5b and 6c).

US Initiates corrective action for failed channel

a. Notifies management and WCSRO

b. Directs RO/BOP to generate work request US Notifies SM/MTI to Initiate actions to trip Bi-stables associated with per Attachment D-2 of 2-OHP-4022-013-013.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 11 of 19 Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Event No.: 7 Event

Description:

The event starts with a trip of both Main Feed Water Pumps due to a failed SSPS relay. The crew should respond by attempting a manual reactor trip and then entering 2-OHP-4023-FR-S.1, Response to Nuclear Generation/ATWS. The crew will perform actions in FR-S.1 including manual AMSAC initiation, manual turbine trip, and initiation of emergency boration.

The crew will transition out of FR-S.1 when conditions are satisfied. After completion of FR-S.1, the crew will transition to 2-OHP-4023-E-0, Reactor Trip or Safety Injection.

Event Termination: When the Crew transitions to E-0, the event is complete.

Symptoms/Cues:

Both Main Feed Pumps trip SG level lowers on all Steam Generators Reactor fails to tip automatically or manually Automatic Turbine trip does not occur Automatic AFW pump start does not occur Automatic SI actuation is likely when local reactor trip actions are completed Time Position Applicants Actions or Behavior NOTE: It is expected that control rods will have been placed in automatic after stopping the power escalation earlier in the scenario. Actions listed below assume rod control is in automatic.

CREW Diagnose a loss of all feed water flow US Direct the RO to perform a manual reactor trip RO Attempt to manually trip the reactor using control board switches to open reactor trip breakers (unsuccessful)

US Direct RO and BOP to perform immediate actions of 2-OHP-4023-FR-S.1, Response to Nuclear Power Generation/ATWS RO From memory, determine reactor is not tripped based on reactor trip breakers CLOSED and attempt manual reactor trip using both reactor trip switches.

NOTE: Plant Specific Background Document 12-OHP-4023-FR-S.1 states that If RCS temperature is above the current reference temperature, then the rods should automatically be driven in by the Rod Control system. This actions satisfies the intent of the contingency requirement to manually insert control rods as long as rod speed is 48 steps per minute.

RO From memory, manually insert control rods or verify automatic control rod insertion is >48 steps per minute.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 12 of 19 Time Position Applicants Actions or Behavior CT2: Start AFW pumps during ATWS Initiating Cue: Both of the following:

o Indication of a condition requiring reactor trip and automatic/manual reactor trip have failed o Indication and/or annunciation that <3 AFW pumps are running Performance Feedback: Pump indicating lights indicate pumps running and AFW flow rate increases Success Path: AFW pumps can be started by manual AMSAC initiation or by manually starting each individual AFW pump using the control switch Measurable Performance Standard: Start all available AFW pumps prior to all SG WR levels lowering below 17% by performing one of the following:

o Manual AMSAC initiation o Manual start of AFW pumps BOP From memory, manually actuate AMSAC by placing control switch 2-101-AM-1 in TRIP (CT2 related action)

CT1: Isolate main turbine from SGs during ATWS Initiating Cue: Indication of loss of main feed water (MFP status on Main Feed Pump HMI, feed water flow indication), indication that automatic and manual reactor trip are ineffective (Reactor tip breaker position), and indication that the main turbine is not tripped (Main Turbine stop valve status light, Main Turbine valve position on Main Turbine HMI).

Performance Feedback:

o Valve status lights that isolate main turbine from SGs indicate closed o Main Turbine speed and MW load lowering Success Path: The expected and procedurally preferred success path will be by closing Main Turbine Control Valves using the ATWS runback on the Main Turbine HMI or manually closing SG Stop Valves. These actions are all designated as immediate action steps (performed from memory prior to referencing the procedure.)

Measurable Performance Standard: Isolate the main turbine from the SGs prior to dry out conditions in all steam generators as indicated by SG WR levels <17% by performing one or more of the following:

o Initiation of ATWS turbine runback o Manual steam line isolation BOP From memory, determine turbine stop valve status lights are not lit and perform the following:

Attempt a manual turbine trip by placing the SOLENOID TRIP switch in SOL TRIP (unsuccessful)

Actuate the ATWS TURBINE RUNBACK button on the HMI (CT1 related action)

US Direct actions of 2-OHP-4023-FR-S.1 using procedure Verify proper performance of RO and BOP immediate action steps 1-3 RO/BOP Perform actions of 2-OHP-4023-FR-S.1 as directed.

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 13 of 19 Time Position Applicants Actions or Behavior BOP Check AFW pumps running If AMSAC was not manually initiated, the BOP should perform the following:

o Manually start both Motor Driven AFW pumps (CT2 related action) o Verify TDAFP steam supply valves are open o Manually start the TDAFP (CT2 related action)

RO Initiate Emergency Boration of the RCS:

Determine at least one CCP is running Start both Boric Acid Transfer pumps in FAST speed Open 2-QMO-420 emergency boration to CCP suction valve Determine emergency boration flow is >44 gpm on 2-QFI-420 Determine pressurizer <2335 psig BOP Check containment ventilation isolation valves closed:

Containment pressure relief system valves 2-VCR-107 & 2-VCR-207 Containment instrument room purge system valves 2-VCR-101, 2-VCR-102, 2-VCR-201, & 2-VCR-202 Containment Purge System valves 2-VCR-103, 2-VCR-203, 2-VCR-104, 2-VCR-204, 2-VCR-105, 2-VCR-205, 2-VCR-106, 2-VCR-206 RO US Check if Safety Injection Actuated status light is lit If SI actuated, direct performance of steps 5-13 of E-0 as time permits.

US Direct local action to open reactor trip breakers CREW Determine WR log power <5% with negative SUR US Transition back to procedure and step in effect (2-OHP-4023-E-0)

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 14 of 19 Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Event No.: 8 Event

Description:

The Crew will perform actions of E-0 and ES-1.1 to terminate SI.

Event Termination: When the Crew has stopped all but one Charging Pump, isolated BIT flow, stopped SI pumps, and stopped RHR pumps, the event is complete.

Symptoms/Cues:

N/A Time Position Applicants Actions or Behavior US Direct transition back to 2-OHP-4023-E-0 Ensures immediate actions of 2-OHP-4023-E-0 are completed Directs subsequent actions of 2-OHP-4023-E-0.

RO/BOP Performs the immediate actions of E-0 from memory:

1. Checks reactor trip - Determines reactor Trip and Bypass breakers Open, all rods < 10 steps, neutron flux lowering

2. Checks turbine trip - Determines Turbine Stop Valve Closed Status Lights Lit

3. Checks power to AC emergency buses - Determines all emergency buses T21A, T21B, T21C, and T21D energized and both annunciators clear for Open Phase

4. Checks safety injection status - Determine SI Status Lights Lit (QMO-225/226 white lights Lit)

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 15 of 19 Time Position Applicants Actions or Behavior RO/BOP Complete actions of E-0 through steps 5-20 as directed:

5. Check if Main Steam line isolation is required-Close all SG stop valves if SG pressures did not remain above 500 psig.

a. NOTE: SG Stop Valves may have been previously isolated due to low-low SG pressure with failure of automatic isolation

6. Check if CTS is required-Determine containment pressure has remained below 2.8 psig

7. Implement Attachment A while continuing with E-0 (actions listed below)

8. Check if ruptured SG is suspected-Determine no SG NR levels rising in an uncontrolled manner

9. Check AFW pumps running-Determine all three AFW pumps are running

10. Check total AFW flow >240 x103 PPH

11. Minimize unnecessary RCS cooldown-Determine SG NR levels are not >13% and reduce total AFW flow to between 240 x103 PPH and 450 x103 PPH and control NR level between 13% and 50%

12. Check AFW pump discharge valves-Determine valves are throttled

13. Check FW isolation-Determine both MFPs tripped, both MFP discharge valves closed, all four FRVs closed, and all four feed water isolation valves closed

14. Check RCS temperature-Determine RCS temperature is lowering, no dumping of steam is occurring, 2-DRV-407 is closed, AFW flow is >240 x103 PPH, and SG stop valves should not be closed.

15. Check pressurizer PORVs and spray valves-Determine PORVs and spray valves are operating properly to control pressure and PORV block valves are all energized.

16. Check if RCPs should be stopped-Determine criteria are not satisfied to stop RCPs.

17. Check if SG secondary pressure boundaries are intact-Determine no SG pressure is lowering in an uncontrolled manner nor completely depressurized

18. Check if SG tubes are intact-Determine no SG NR levels rising in an uncontrolled manner and no abnormal secondary radiation

19. Check if RCS is intact-Determine RCS is intact based on normal containment radiation, pressure, and sump levels

20. Check if ECCS flow should be reduced: Determine RCS subcooling >40 ºF, Feed Flow >240E3 pph, RCS pressure stable or rising. Pressurizer level >20%

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 16 of 19 Time Position Applicants Actions or Behavior RO/BOP Perform actions of Attachment A as follows:

1. Check ECCS pumps all running-Determine CCPs, SI pumps, and RHR pumps running.

2. Check ECCS flow-Determine flow is indicated for BIT flow.

3. Check ECCS valves in proper alignment-Determine ECCS alignment is correct using status lights on 2-SML-12A, 2-SML-12B, 2-SML-12C, 2-SML-11A, 2-SML-11B, and 2-SML-11C.

4. Check CCW status-Determine one CCW pump running, CCW surge tank stable, and CCW monitor lights in proper status using 2-SML-8B.

5. Check ESW status-Determine both ESW pumps running, both discharge valves open, and proper status lights on 2-SML-7

6. Check if containment recirculation fans should be running-Determine containment pressure <1 psig.

7. Place DIS in service by directing local action to stop all ice condenser air handling units and turning on all hydrogen ignitors when local action is reported complete

8. Check containment vent and Phase A isolation-Determine Containment Vent Isolation and Phase A isolation are actuated and completed on both trains, and direct actions to periodically monitor SFP radiation, SFP cooling, and SFP level

9. Check ESF fans both running-Determine both fans are running

10. Align control room ventilation by checking both pressurization fans are running, stopping one pressurization fan, checking cable vault hatch closed, checking control room dampers aligned for SI, and checking at least one control room air handling unit is running

11. Align PACHMS for service by momentarily placing containment hydrogen sample bypass switches in BYPASS

12. Request Unit 1 perform actions

13. Check generator trip-Determine generator output breakers are both open and main generator excitation control is OPEN

14. Check Load Conservation status-Determine AC buses T21B and T21C are energized by offsite power

15. Check NESW pressure is >65 psig on 2-WPI-901

16. Check Containment Isolation Phase B status-Determine Containment Isolation Phase B is actuated and completed on both trains.

17. Report completion of Attachment A US Announces transition to 2-OHP-4023-ES-1.1, SI Termination, and directs operator actions.

Checks Status Trees for Red Path

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 17 of 19 Time Position Applicants Actions or Behavior RO/BOP Performs actions of 2-OHP-4023-ES-1.1, SI Termination as directed:

Reset SI Stop all but one CCP Reset Containment Isolation Establish Control Air to containment:

o Place pressurizer spray valve controllers in MANUAL at zero demand o Determine control air pressure is >85 psig o Open control air to containment valves 2-XCR-100, 2-XCR-101, 2-XCR-102, & 2-XCR-103.

o Determine annunciator 204-33 clear Determine RCS pressure is stable or rising Isolate BIT:

o Determine CCP suction is aligned to the RWST o Reset and open both CCP leak off valves 2-QMO-225 and 2-QMO-226 o Close BIT inlet valves 2-IMO-255 and 2-IMO-256 o Close BIT outlet valves 2-ICM-250 and 2-ICM-251 Establish Charging flow:

o Close 2-QRV-200, charging header pressure control valve o Open charging flow to regen heat exchanger valves o Establish minimum charging flow using 2-QRV-200 and 2-QRV-251 to maintain 6 to 12 gpm seal injection flow to each RCP NOTE: 2-QFI-200, Charging Flow instrument, is failed from a previous event.

Control charging flow to maintain pressurizer level stable or rising Determine RCS pressure is >1650 psig and stable or rising and stop SI pumps Stop both RHR pumps

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 18 of 19 Simulator Instructions:

SETUP:

Reset to an 80% IC with the North Hotwell Pump and Middle Condensate Booster Pump in standby, MSRs in service, and all pressurizer backup heaters are energized with pressure stabilized.

Provide a marked up copy of 2-OHP-4021-001-006, Power Escalation, completed through step 4.87 (When approximately 80% power, then compare power indications and record on Data Sheet 9).

Enter a failure of the West CCW pump to auto start:

Enter the following to disable automatic and manual reactor trip:

Enter the following to disable automatic AMSAC actuation:

Enter the following to disable automatic start of AFW pumps:

Enter the following to enable AFW pump start when AMSAC is manually initiated:

Enter the following to disable all automatic and manual turbine trips:

Enter the following to disable automatic steam line isolation:

Enter the following to set up inadvertent SI actuation of SI on ET2:

Event 1:

AEO Role Play:

If requested, report the Middle Condensate Booster Pump is ready for start and personnel are clear of the area.

After pump start, report that Condensate Booster Pump oil pressure is 4 psig.

When requested, report 2-CRV-224 is verified closed by local indication.

Event 2:

No action required Event 3:

When directed by the Lead Evaluator, insert the following malfunction:

Event 4:

NOTE: The following event is required for the BOP. It should be inserted when the RO is engaged with manual control of 2-QRV-251 to ensure the BOP is the person who responds to the event.

U2_RP07B U2_TC02 U2_RP07A trg= 1 "dmf u2_fw48c" U2_FW48C U2_CC02B U2_PB505E1 Not Tripped trg= 1 "dmf u2_fw48a" U2_AMSAC ET1 U2_RP03B U2_FW48A U2_FW48B trg= 1 "dmf u2_fw48b" U2_RP12A ET2 U2_RP03A U2_PB506E1 Not Tripped U2_QFI200 0 U2_RP12B ET2

Op. Test No.: Cook 2022 Scenario No.: NRC2022-4 Form 3.3-2 Page 19 of 19 When the Crew has completed actions of IFR-001, and with the concurrence of the Lead Evaluator, insert the following malfunction to fail the East CCW pump:

Event 5:

When the crew has started the West CCW pump and identified applicable Tech Spec actions, and with the concurrence of the Lead Evaluator, enter the following to cause a failure of VCT level channel QLC-452:

Event 6:

When the Crew has completed actions of IFR-001, actions of 2-OHP-4022-013-017 are complete up to energizing the RWS relay, and with the concurrence of the Lead Evaluator, enter the following to cause a failure of 24 SG level to 100%:

Event 7:

When actions of 2-OHP-4022-013-013 are complete up to bistable tripping, and with the concurrence of the Lead Evaluator, enter the following to cause an inadvertert SI on both trains:

When directed, wait 2 minutes and open reactor trip breakers locally:

When directed, wait 2 minutes and locally trip the turbine:

Event 8:

Perform the following actions as directed during performance of E-0:

Stop ice condenser air handling units and report completion in ~5 minutes:

When directed to perform Unit 1 actions per E-0 Att. A:

1. Report chemistry has been directed to place Train A PACHMS in service, Unit 1 control room pressurization is aligned for a Unit 2 SI, 2-HV-AS-1 is in service

2. Place PACHMS Train A in service (30 minute delay):

U2_CHR02 ON After 30 Min Delay TRG! 2 U2_ECC Stator Short Circuit U2_BLP141 45-100%, 2 Min Ramp U2_QLC452 100 Delete RP03A U2_CHR01 OFF After 5 Min Delay Delete RP03B U2_TCR01 TRIP

ML22250A704

Contents

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:

Navigation menu

ML22250A704

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:

Navigation menu

Search