NRC INITIAL LICENSE EXAM SCENARIO # 1for PMs. 1A CA Pump has been inoperable for 2 hours and is expected to be returned to service in 8 hours. Direction for the crew is to continue

Catawba Nuclear Station NRC Exam May 2016

Appendix D Catawba NRC Exam May 2016 Scenario 1 NUREG 1021 Revision 10 Page 1 of 67

NRC INITIAL LICENSE EXAM SCENARIO # 1

Catawba Nuclear Station NRC Exam May 2016 Appendix D Scenario Outline Form ES-D-1


Facility: Catawba NRC Exam 2016 Scenario No.: 1 Op Test No.: 2016301 Examiners: Operators: SRO RO BOP

Initial Conditions: Unit 1 is at 75% power at the MOL. Unit 2 is at 100% power. Turnover: Unit 1 is at 75% power at the MOL. Unit 2 is at 100% power. 1A CA Pump has been removed from

service for PMs. 1A CA Pump has been inoperable for 2 hours and is expected to be returned to service in 8 hours. Direction for the crew is to continue a power decrease to 13% (at 10% / hour) for turbine offline work. The Unit 1 RMWST is NOT aligned to supply Unit 2 per OP/2/A/6200/012 (Reactor Makeup Water).

Event No.

Malf. No. Event Type*

Event Description

1 R – RO N - BOP N – SRO

Decrease power to ~13%

2 AD19F04 NC009F

C – RO C - SRO TS – SRO

PZR PORV fails open (Isolated by block valve)

3 RN002B C – BOP C - SRO TS - SRO

RN (Nuclear Service Water) Strainer Hi D/P

4 WL018D C – BOP C – SRO 1B NCDT Pump Trip

5 CF012F C – RO C – SRO 1CF-51 (S/G 1C CF CONT ISOL) fails closed / Auto Reactor Trip Failure

6 SM009 M – ALL Rupture on equalization header upon Rx trip

7 ISE006A ISE006B C – RO Failure of Automatic Main Steam Isolation

8 VE001A C - BOP Failure of Automatic 1A VE Fan start

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



Scenario 1 – Summary Initial Condition Unit 1 is at 75% power at the MOL. Unit 2 is at 100% power. Turnover: Unit 1 is at 75% power at the MOL. Unit 2 is at 100% power. 1A CA Pump has been removed from service for PMs. 1A CA Pump has been inoperable for 2 hours and is expected to be returned to service in 8 hours. Direction for the crew is to continue a power decrease to 13% (at 10% / hour) for turbine offline work. The Unit 1 RMWST is NOT aligned to supply Unit 2 per OP/2/A/6200/012 (Reactor Makeup Water). Event 1 Crew will use the provided reactivity plan to begin a power decrease to ~13%. BOP will perform a boration per the reactivity plan. RO will input a target and load rate into the turbine control panel and place the turbine in GO to commence power decrease. RO will also insert control rods as required to maintain RCS temperature. Event 2 1NC-36B (PZR PORV) fails open while BOP is responding to a rear board annunciator. Manual closure of the associated block valve will be successful. AP/11 (Pressurizer Pressure Anomalies) entry. TS evaluation required. Verifiable Action – RO will isolate PZR PORV by manually closing the associated PORV Isolation valve. Event 3 1B RN (Nuclear Service Water) strainer Hi D/P. AP/20 (Loss of Nuclear Service Water) entry. TS evaluation required. Verifiable Action – BOP will start an alternate RN Pump and secure 1B RN Pump. Event 4 1B NCDT (Reactor Coolant Drain Tank) Pump trips. Required actions contained in Annunciator Response Procedure. Verifiable Action – The BOP will start the 1A NCDT Pump per the ARP. Event 5 1CF-51 (S/G 1C CF CONT ISOL) valve fails closed. Both CFPTs will trip on Hi Discharge Pressure resulting in an AMSAC Turbine Trip. The Automatic Reactor Trip on Turbine Trip greater than 69% (P9) will fail. AP/06 (Loss of S/G Feedwater) Immediate Actions, and the failed Automatic Trip, will require the RO to manually trip the reactor. Verifiable Action – RO will manually trip the reactor. Event 6 Following unit trip, a rupture at the steam equalization header occurs. Verifiable Action – Crew will terminate Safety Injection following manual initiation of Main Steam Isolation. Event 7 Automatic Main Steam Isolation trains ‘A’ and ‘B’ fail to actuate on low S/G pressure. Manual initiation will be required. Verifiable Action – RO will manually initiate Main Steam Isolation on both trains.



Scenario 1 – Summary Event 8 1A VE (Annulus Ventilation) Fan fails to start on Safety Injection signal. Manual start will be required. Verifiable Action – BOP will manually start the fan. Critical Task 1 – Manually isolate failed open Pressurizer PORV prior to reactor trip or ESF actuation. Critical Task 2 – Manually trip the reactor from the control room before 1C S/G dryout occurs (W/R S/G level < 12%). Critical Task 3 – Manually actuate Main Steam Isolation before a severe (orange path) challenge develops to either the subcriticality or the integrity CSF or before transition to ECA-2.1, whichever happens first.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (5–8) 8

2. Malfunctions after EOP entry (1–2) 2

3. Abnormal events (2–4) 4

4. Major transients (1–2) 1 5. EOPs entered/requiring substantive actions (1–2) 1 6. EOP contingencies requiring substantive actions (0–2) 0

7. EOP based Critical tasks (2–3) 2



EXERCISE GUIDE WORKSHEET

1. INITIAL CONDITIONS:

1.1 Reset to IC # 170

START TIME:__________ Trigger Instructor Action Final Delay Ramp Delete In Event

2 ANN-AD19-F04 (YN CRITICAL TROUBLE) ON 2

11 VLV-NC009F (NC36B PZR PORV FAIL TO POSITION) 1 2

3 MAL-RN002B (RN STRAINER 1B HI D/P) 100 3

4 OVR-WL018D (NCDT PMP 1B OFF PB) ON 4

4 OVR-WL-018A (NCDT PMP 1B OFF LT) OFF 4

5 VLV-CF012F (CF51 CF CONT ISOL VLV 1CF051 FAIL TO POSITION)

0 4SEC 5

6 MAL-SM009 (SM HEADER BREAK) 1.27 e7 6

N/A MAL-ISE006B (AUTO SM ISOL SIGNAL TRN B) BLOCK 7

N/A MAL-ISE006A (AUTO SM ISOL SIGNAL TRNA) BLOCK 7

N/A

MAL-VE001A (FAN VE-1A DISABLE AUTOSTART RELAY)

ACTIVE 8

10

LOA-VC039 (MNL RST LATCH FOR CHILLER B HI COND PRESS TRP DUE TO LOSS RN)

RESET 10:00

N/A LOA-CA017 (RACKOUT CA PUMP 1A) RACK-OUT

N/A

MAL-IPX001A (AUTO REACTOR TRIP FAILURE TRN A)

ACTIVE

N/A

MAL-IPX001B (AUTO REACTOR TRIP FAILURE TRN B)

ACTIVE



12 VLV-NC008C (NC35B PORV ISOL VLV FAIL PWR) ACTIVE

Ensure TRIGGER 11 = x5ri017a (1AD-19 Acknowledge) Ensure TRIGGER 6 = ipplp4(1) ipplp4(2) (Reactor Trip either train) Ensure 1B RN Pump is in service Ensure 1B NCDT Pump is in service Ensure Control Rods in manual



2. SIMULATOR BRIEFING

2.1 Control Room Assignments:

Position Name CRS RO

BOP

2.2 Give a copy of Attachment 2 (Shift Turnover Information) to the CRS.

3. EXERCISE PRESENTATION

3.1 Familiarization Period

A. Allow examinees time to familiarize themselves with the Control Board alignments.

3.2 Scenario EVENT 1, Power decrease to 13%

BOOTH INSTRUCTOR ACTION IF contacted as SOC by the crew to inform of commencing power decrease, REPEAT the

information.

3.3 Scenario EVENT 2, 1NC-36B (PZR PORV) fails open.

BOOTH INSTRUCTOR ACTION WHEN directed by the lead examiner, THEN INSERT SIMULATOR Trigger 2 to cause

1AD-13, F/5 (HVAC PANEL TROUBLE) to alarm.

BOOTH INSTRUCTOR ACTION IF the SWM is contacted to initiate an NCR for 1NC-36B, REPEAT back the information.

BOOTH INSTRUCTOR ACTION

IF the Unit Supervisor is contacted to remove power from 1NC-35B, THEN INSERT SIMULATOR Trigger 12.


IF Station Management is contacted for power decrease guidance, ask for CRS recommendation and agree.


IF an AO is contacted to investigate YN Critical Trouble, REPEAT back the information.



3.4 Scenario EVENT 3, 1B RN Strainer Hi D/P


1B RN Strainer Hi D/P.

BOOTH INSTRUCTOR ACTION IF the SWM is contacted to investigate the problem with 1B RN Strainer and/or breaker,

REPEAT back the information.

BOOTH INSTRUCTOR ACTION IF an Operator and/or Maintenance are dispatched to investigate the 1B RN Strainer

and/or breaker, REPEAT back the information.

BOOTH INSTRUCTOR ACTION IF an Operator is dispatched to reset VC/YC, THEN INSERT SIMULATOR Trigger 10. After 10 minutes has elapsed, REPORT VC/YC has been reset.


WHEN contacted concerning Unit 2 RN valve position, REPORT 2RN-67A and 69B are Open.


IF an Operator is dispatched to perform post start check of RN Pump, REPEAT back the information.

After 5 minutes has elapsed, REPORT RN Pump ____ is good for continued operation.

BOOTH INSTRUCTOR ACTION IF Environmental Chemistry is contacted, REPEAT back the information.


IF indication of 2AD-12 C/2 and C/5 are requested, REPORT that both annunciators are dark.

3.5 Scenario EVENT 4, 1B NCDT Pump Trip

BOOTH INSTRUCTOR ACTION WHEN directed by the lead examiner, THEN INSERT SIMULATOR Trigger 4 to trip 1B

NCDT pump.

BOOTH INSTRUCTOR ACTION IF Operator and/or Maintenance are dispatched to investigate the 1B NCDT Pump and/or

breaker, REPEAT back the information.



BOOTH INSTRUCTOR ACTION IF SWM is called to initiate an NCR on the 1B NCDT pump, REPEAT back the

information. 3.6 Scenario EVENT 5, 1CF-51 (S/G 1C CF CONT ISOL) fails closed.

BOOTH INSTRUCTOR ACTION WHEN directed by the lead examiner, THEN INSERT SIMULATOR Trigger 5 to fail 1CF-

51 (S/G 1C CF CONT ISOL) closed.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 301 Scenario # 1 Event # 1 Page 10 of 67 Event Description: Power Reduction

Time Position Applicant’s Actions or Behavior


EVENT 1

NOTE TO EVALUATOR: Crew will begin by performing a boration per the reactivity plan provided by reactor engineering. They will also set up the turbine controls for proper load rate and target load. Crew may also decide to insert control rods to provide a temperature error prior to placing the turbine in ‘GO’. These steps may be performed in any order that the crew chooses.

NOTE TO EVALUATOR: All needed materials have been provided to the crew to perform any needed pre job briefs prior to being brought into the simulator for their control board walk down prior to assuming the watch.

NOTE TO EVALUATOR: The following steps are taken from OP/1/A/6150/009 (Boron Concentration Control) Enclosure 4.2 (Boration).

NOTE TO EVALUATOR: The Turbine Load Changing procedure begins on page 13.

ALL

NOTE: This enclosure will affect reactivity of the core and is therefore designated important to Reactivity Management per the guidelines of AD-OP-ALL-0203 (Reactivity Management). (R.M.)

BOP 3.1 Ensure valves are aligned per Enclosure 4.8 (Valve Checklist).

BOP

3.2 Ensure the following valve control switches in “AUTO”: • 1NV-238A (B/A To Blender Ctrl Vlv) • 1NV-186A (B/A Blender Otlt To VCT Otlt)

BOP 3.3 Ensure 1NV-238A (B/A To Blender Ctrl Vlv) controller in auto.

BOP 3.4 Ensure at least one boric acid transfer pump is in “AUTO” or “ON”.

NOTE TO EVALUATOR: The supplied Reactivity Management plan will specify an initial boric acid addition of 130 gallons.

BOP 3.5 Record the desired volume of boric acid to be added. ______ gallons

BOP 3.6 Adjust the boric acid counter to the desired volume of boric acid to be added. (R.M.)

BOP

3.7 IF the blender is set up for automatic makeup per Enclosure 4.1 (Automatic Makeup), record the setpoint of the controller for 1NV-238A (B/A To Blender Ctrl Vlv). __________ gpm




BOP 3.8 Place the “NC MAKEUP MODE SELECT” switch in “BORATE”.

BOP NOTE: Boric Acid flow rates > 32 gpm may result in a boric acid flow deviation annunciator.

BOP 3.9 IF required, adjust the controller for 1NV-238A (B/A To Blender Ctrl Vlv) to the desired flow.

BOP

3.10 IF NC System boron concentration will be changed by > 50 ppm, initiate PZR spray to equalize the boron concentration throughout the system by operating backup heaters per OP/0/A/6200/005 (Miscellaneous Component Operation).

NOTE TO EVALUATOR: Step 3.11, 3.12, and 3.13 are conditional steps and should not need to be performed during this scenario.

BOP

3.11 IF AT ANY TIME it is desired to divert letdown to the RHT manually operate 1NV-172A (3-Way Divert to VCT-RHT) as follows:

3.11.1 Place the control switch for 1NV-172A (3-Way Divert to VCT-RHT) to the “RHT” position.

3.11.2 Ensure VCT level is monitored continuously while diverting to the RHT.

NOTE: Procedure may continue while performing the next step. 3.11.3 WHEN desired VCT level is reached return 1NV-172A (3-Way

Divert to VCT-RHT) to auto as follows: 3.11.3.1 Place the control switch for 1NV-172A (3-Way Divert to

VCT-RHT) in the “VCT” position. 3.11.3.2 Place the control switch for 1NV-172A (3-Way Divert to

VCT-RHT) in the “AUTO” position.

BOP

3.12 IF AT ANY TIME during the makeup it becomes necessary to change the makeup flow rate, adjust the setpoint for 1NV-238A (B/A Xfer Pmp To Blender Ctrl) as necessary to achieve the desired flow.




BOP

3.13 IF AT ANY TIME while boration is in progress it becomes necessary OR it is desired to stop the boration, perform the following:

3.13.1 Place the “NC MAKEUP CONTROL” switch to the “STOP” position.

3.13.2 Ensure the following valves close: (R.M.) • 1NV-238A (B/A To Blender Ctrl Vlv) • 1NV-186A (B/A To Blender Otlt To VCT Otlt)

3.13.3 Record boric acid volume added as indicated on the Boric Acid counter. __________ gallons

3.13.4 WHEN conditions allow resuming the boration, perform the following: 3.13.4.1 Determine remaining volume to be added by subtracting

the amount previously added (Step 3.13.3) from the desired volume to be added (Step 3.5) __________ - __________ = __________ gallons (Step 3.5) (Step 3.13.3)

3.13.4.2 Adjust boric acid counter to the volume of boric acid determined in Step 3.13.4.1. (R.M.)

3.13.4.3 Place “NC MAKEUP CONTROL” switch in the “START” position. (R.M.)

3.13.4.4 Verify the following: • 1NV-238A (B/A To Blender Ctrl Vlv) modulates to establish

desired flow • 1NV-186A (B/A To Blender Otlt To VCT Otlt) opens

3.13.4.5 IF in “AUTO”, verify the boric acid pump starts.

RO

3.14 WHILE makeup is in progress, monitor the following for expected results:

• Control rod motion • NC System Tavg • Reactor Power

BOP NOTE: If a small makeup is being performed, placekeeping for Steps 3.15 through 3.18 may be performed after Step 3.19 is performed.

BOP 3.15 Place the “NC MAKEUP CONTROL” switch to the “START” position. (R.M.)




BOP

3.16 Verify the following: • 1NV-238A (B/A To Blender Ctrl Vlv) modulates to establish desired

flow • 1NV-186A (B/A Blender Otlt To VCT Otlt) opens

BOP 3.17 IF in “AUTO”, verify the boric acid transfer pump starts.

BOP 3.18 Verify proper flow by observing the Boric Acid Counter. {PIP 96-0137}

BOP NOTE: The boric acid counter may count up 1 – 5 gallons after termination.

BOP

3.19 WHEN the desired volume of boric acid is reached on the boric acid counter, ensure the following valves close: (R.M.)

• 1NV-238A (B/A To Blender Ctrl Vlv) • 1NV-186A (B/A Blender Otlt To VCT Otlt)

NOTE TO EVALUATOR: Step 3.20 may not be performed. See note below.

BOP NOTE: If additional borations will be performed over the course of the shift, flushing the makeup line is NOT recommended.

BOP

3.20 IF desired, flush the makeup line as follows: 3.20.1 Record the setpoint on 1NV-242A (RMWST To B/A Blender Ctrl):

________ gpm 3.20.2 Place controller for 1NV-242A (RMWST To B/A Blender Ctrl) in

manual. 3.20.3 Increase demand on controller for 1NV-242A (RMWST To B/A

Blender Ctrl) to full open. 3.20.4 Open the following valves:

• 1NV-242A (RMWST To B/A Blender Ctrl) • 1NV-186A (B/A Blender Otlt To VCT Otlt)

3.20.5 Ensure one reactor makeup water pump is in “ON”. 3.20.5.1 IF Unit 1 RMWST is NOT aligned to supply Unit 2

per OP/2/A/6200/012 (Reactor Makeup Water), ensure at least one reactor makeup water pump is “ON”.

3.20.5.2 IF Unit 1 RMWST is aligned to supply Unit 2 per OP/2/A/6200/012 (Reactor Makeup Water) AND a Unit 1 RMW Pump is NOT running to support Unit 2 activities, ensure at least one reactor makeup water pump is “ON”.

3.20.5.3 IF Unit 1 RMWST is aligned to supply Unit 2 per




OP/2/A/6200/012 (Reactor Makeup Water) AND a Unit 1 RMW Pump is running to support Unit 2 activities, ensure the second Unit 1 reactor makeup water pump is “ON”.

3.20.6 WHEN ~ 20 gallons of makeup water have been flushed through the makeup line, close the following valves:

• 1NV-242A (RMWST To B/A Blender Ctrl) • 1NV-186A (B/A Blender Otlt To VCT Otlt)

3.20.7 Place the following valve control switches in “AUTO”: • 1NV-242A (RMWST To B/A Blender Ctrl) • 1NV-186A (B/A Blender Otlt To VCT Otlt)

3.20.8 Ensure controller for 1NV-242A (RMWST To B/A Blender Ctrl) is set to the value recorded in Step 3.20.1. (R.M.)

3.20.9 Place controller for 1NV-242A (RMWST To B/A Blender Ctrl) in

auto. 3.20.10 IF NOT required for current plant operation, place the reactor

makeup water pump started in Step 3.20.5 in “AUTO”.

BOP

3.21 IF automatic makeup is desired, perform the following: 3.21.1 IF it is desired to change the blender outlet boron concentration,

refer to Enclosure 4.1 (Automatic Makeup). OR

3.21.2 IF makeup at the previous concentration is acceptable AND the system was previously aligned per Enclosure 4.1 (Automatic Makeup), perform the following: 3.21.2.1 Ensure the controller for 1NV-238A (B/A Xfer Pmp To

Blender Ctrl) is set to the value recorded in Step 3.7. (R.M.)

3.21.2.2 Place the “NC MAKEUP MODE SELECT” switch in “AUTO”.

3.21.2.3 Place the “NC MAKEUP CONTROL” switch to the “START” position. (R.M.)

BOP 3.22 IF initiated in Step 3.10, terminate PZR spray by securing backup heaters per OP/0/A/6200/055 (Miscellaneous Component Operation).

END OF OP/1/A/6150/009




NOTE TO EVALUATOR: The following steps are taken from OP/1/B/6300/001 (Turbine Generator) Enclosure 4.2 (Load Changing).

NOTE TO EVALUATOR: The expected load rate input to the turbine controls will be 2 MW/min.

RO

CAUTION: 1. Normal steady-state load change shall be made without exceeding limits shown on Enclosure 4.7 (Generator Operating Limits) and in the Unit One OAC Databook “Recommended Starting and Loading Curves”.

2. Unit One Reactor Operating Data, Section 2.4 shall be referred to for allowable ramp rates.

RO

3.2.3 Decrease turbine generator load by performing the following: 3.2.3.1 Select “LOAD RATE” and verify it illuminates. 3.2.3.2 Input the desired load rate. 3.2.3.3 Select “ENTER” and verify “LOAD RATE” goes dark. 3.2.3.4 Select “TARGET” and verify it illuminates. 3.2.3.5 Input the desired load target. 3.2.3.6 Select “ENTER” and verify “TARGET” goes dark. 3.2.3.7 Verify new load target appears on Target Display. 3.2.3.8 Select “GO” and verify it illuminates to start load decrease. 3.2.3.9 Coordinate with Secondary Chemistry to adjust S/G blowdown

flowrates to obtain maximum blowdown for the appropriate load.

END OF EVENT OP/1/B/6300/001




NOTE TO EVALUATOR: The following steps are from OP/1/A/6150/008 (Rod Control) Enclosure 4.16 (Control Bank Manual Operation At Power). This procedure was given to the crew as part of the turnover package with initial conditions and steps 3.1 - 3.3 signed off. Crew may decide not to perform these steps at this time.

RO NOTE: Steps 3.1 through 3.6 may be signed off as time allows ensuring operator maintains proper focus on reactivity management.

ALL

3.1 Monitor the following: • Tavg/Tref • Demand Counter positions • DRPI rod positions • ROD MOTION RODS-IN/RODS-OUT Light • ROD MOTION DEMAND SIGNALS – TEMP ERROR/POWER

MISMATCH • Power Range instruments • IR SUR (Startup Rate)

NOTE TO EVALUATOR: Step 3.4 should be N/A at this time.

RO 3.4 IF withdrawing Control Banks, pull and hold the “ROD MOTION” lever “OUT” as required until control rods are in the desired position. (R.M.)

RO 3.5 IF inserting Control Banks, push and hold the “ROD MOTION” lever “IN” as required until control rods are in the desired position. (R.M.)

Booth Operator will insert Trigger 2 for EVENT 2 at the discretion of the lead evaluator.

END OF EVENT 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 301 Scenario # 1 Event # 2 Page 17 of 67 Event Description: PZR PORV Failure



EVENT 2

NOTE TO EVALUATOR: The next event will begin with 1AD-13, F/5 “HVAC PANEL TROUBLE” annunciator. The BOP will respond to the rear of the control boards to address this alarm. When the rear board alarm is acknowledged, 1NC-36B (PZR PORV) will fail open requiring action by the RO.

Indications: 1AD-6, E/10 ‘PZR PORV DISCH HI TEMP’ 1AD-6, F/8 ‘PZR LO PRESS CONTROL’ 1AD-6, D/10 ‘PZR LO PRESS PORV NC32 & 36 BLOCKED’ 1AD-6, D/11 ‘PZR LO PRESS PORV NC34 BLOCKED’ OAC PT C1Q0756 ‘VLV NC36B PZR POWER OPERATED RELIEF’ - OPEN

RO Attempt to close 1NC-36B (PZR PORV)

RO Close 1NC-35B (Pzr PORV Isol)

NOTE TO EVALUATOR: The crew will make a plant page announcing the entry into AP/1/A/5500/011, Pressurizer Pressure Anomalies.

NOTE TO EVALUATOR: The following steps are from AP/1/A/5500/011, Pressurizer Pressure Anomalies, Case I (Pressurizer Pressure Decreasing).

RO 1. Verify all Pzr PORVs - CLOSED.

Critical Task #1 RO

1. RNO Perform the following: a. CLOSE Pzr PORV(s). b. IF any Pzr PORV cannot be closed, THEN: 1) CLOSE affected PORV(s) isolation valve.

NOTE TO EVALUATOR: Step 1.b.2) of RNO does not apply.

RO

2) IF PZR PORV isolation valve cannot be closed, THEN perform the following: a) IF in Mode 3 with CLAs isolated OR in Mode 4, THEN GO TO

AP/1/A/5500/027 (Shutdown LOCA). b) Trip Unit 1 reactor. c) WHEN reactor tripped OR S/I setpoint reached, THEN ensure

S/I initiated. d) GO TO EP/1/A/5000/E-0 (Reactor Trip or Safety Injection).

RO/BOP NOTE: Control rods may withdraw on decreasing NC pressure.




BOP 2. Verify Pzr spray valve(s) - CLOSED.

BOP 3. Verify all Pzr heaters - ENERGIZED.

NOTE TO EVALUATOR: Depending on how fast the RO responded to the PORV failure, the Pzr heaters may not be energized, however, the crew will determine that the step 3 RNO will not apply.

BOP

3.RNO Perform the following: a. IF Pzr pressure less than 2220 PSIG AND stable or decreasing,

THEN ensure all Pzr heaters energized. b. IF Pzr pressure less than 2220 PSIG AND increasing, THEN

operate Pzr heaters as required to stabilize Pzr pressure at 2235 PSIG.

c. WHEN Pzr pressure returns to normal AND automatic Pzr pressure control desired, THEN place Pzr heaters in auto.

BOP 4. Ensure 1NV-37A (NV Supply To Pzr Aux Spray) - CLOSED.

RO/BOP NOTE Positive reactivity is inserted during an increase in NC pressure which may cause auto rod insertion.

BOP 5. Verify NC pressure - STABLE OR INCREASING.

RO

6. WHEN NC pressure is stable, THEN: • Stabilize unit at appropriate power level. • Adjust the following as required to maintain T-Avg within 1°F of T-Ref:

• Turbine load • Control rods • Boron concentration.

NOTE TO EVALUATOR: Step 7 does not apply.

BOP 7. IF Pzr pressure channel failed, THEN perform following:




SRO

8. Ensure compliance with appropriate Tech Specs: • 3.3.1 (Reactor Trip System (RTS) Instrumentation) • 3.3.2 (Engineered Safety Features Actuation System (ESFAS)

Instrumentation) • 3.3.3 (Post Accident Monitoring (PAM) Instrumentation) • 3.3.4 (Remote Shutdown System) • 3.4.1 (RCS Pressure, Temperature, and Flow Departure From

Nucleate Boiling (DNB) Limits) • 3.4.4 (RCS Loops - MODES 1 and 2) • 3.4.5 (RCS Loops - MODE 3) • 3.4.6 (RCS Loops - MODE 4) • 3.4.9 (Pressurizer) • 3.4.10 (Pressurizer Safety Valves) • 3.4.11 (Pressurizer Power Operated Relief Valves) • 3.4.13 (RCS Operational Leakage).

NOTE TO EVALUATOR: TS 3.4.11 (Pressurizer Power Operated Relief Valves (PORVs)), Condition B (Close associated block valve and remove power within 1 hour, and restore PORV to operable within 72 hours) should be entered.

Tech Spec 3.4.1 (RCS Pressure, Temperature, and Flow Departure From Nucleate Boiling (DNB) Limits) Condition A (restore to within limits in 2 hours) should be entered. NOTE: This LCO may not apply based on the speed at which the operator isolates the failed PORV. Additionally, this condition will most likely be cleared prior to CRS review of TS.

SRO 9. Determine long term plant status. RETURN TO procedure in effect.

NOTE TO EVALUATOR: The SRO will conduct a “Crew Brief” or a “Focus Brief” to summarize the event.

END OF EVENT 2

Booth Operator will insert Trigger 3 for EVENT 3 at the discretion of the lead examiner.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 301 Scenario # 1 Event # 3 Page 20 of 67 Event Description: RN Strainer Hi D/P



EVENT 3

Indications: 1AD-12, A/2 ‘RN ESSENTIAL HDR A PRESSURE LO’ 1AD-12, A/4 ‘RN PUMP B FLOW-HI/LO’ 1AD-12, A/5 ‘RN ESSENTIAL HDR B PRESSURE LO’

1AD-12, C/5 ‘RN PMP B STRAINER HI D/P’ 1AD-13, F/5 ‘HVAC PANEL TROUBLE’ 1RNP7510 1B RN Flow indication indicates 0 gpm.

BOP Recognize 1B RN Pump Strainer Hi D/P.

ALL Enter AP/0/A/5500/020, Loss of Nuclear Service Water

NOTE TO EVALUATOR: The crew will make a plant page announcing the entry into AP/0/A/5500/020, Loss of Nuclear Service Water

NOTE TO EVALUATOR: The crew may initially choose to take actions of the annunciator response per OP/1/A/6100/010 M, C/5 (RN PMP B STRAINER HI D/P). See Attachment 4

NOTE TO EVALUATOR: The following steps are from AP/0/A/5500/020, Loss of Nuclear Service Water, Case I (Loss of RN Train).

BOP 1. Start idle RN pump(s) as required.

SRO 2. Ensure Unit 1 and Unit 2 OATC monitors Enclosure 1 (Foldout Page).

NOTE TO EVALUATOR: Enclosure 1 can be found as Attachment 3 in the back of this guide.

BOP

3. Verify RN System in normal alignment as follows: • Both RN Supply headers - ALIGNED AND • Both RN Discharge headers - ALIGNED

BOP 4. Verify each operating RN pump discharge flow - GREATER THAN 8,600 GPM.




BOP

4. RNO Perform the following: a. Stop any RN pump(s) not required to support system operation. b. Ensure the following suction valves to lake - OPEN:

• 1RN-1A (RN P/H Pit A Isol From Lake) • 1RN-2B (RN P/H Pit A Isol From Lake) • 1RN-5A (RN P/H Pit B Isol From Lake) • 1RN-6B (RN P/H Pit B Isol From Lake)

c. Ensure the following essential header isolation valves for required trains - OPEN: • 1RN-67A (RN Hdr 1A Supply Isol) • 1RN-69B (RN Hdr 1B Supply Isol) • 2RN-67A (RN Hdr 2A Supply Isol) • 2RN-69B (RN Hdr 2B Supply Isol)

d. Ensure the following RN to RL discharge valves - OPEN: • 1RN-57A (Station RN Disch To RL Sys) • 1RN-843B (Station RN Disch To RL Sys)

e. Ensure one of the following RL discharge valves - OPEN: • 1RL-54 (RN System Disch To A RL Header) OR • 1RL-62 (RN System Disch To B RL Header)

f. Ensure the following station RN discharge header crossover valves - OPEN: • 1RN-54A (Station RN Disch Hdr X-Over) • 1RN-53B (Station RN Disch Hdr X-Over)

NOTE TO EVALUATOR: Step 4 RNO 4.g. will not apply.

BOP

g. IF either of the following conditions is met: • RN cannot be aligned to lake

OR • No flow indicated on operating RN pump(s).

THEN align RN to SNSWP as follows:

BOP

4. RNO h. Verify the following alarms - DARK: • 1AD-12, C/2 "RN PMP A STRAINER HI D/P" • 1AD-12, C/5 "RN PMP B STRAINER HI D/P" • 2AD-12, C/2 "RN PMP A STRAINER HI D/P" • 2AD-12, C/5 "RN PMP B STRAINER HI D/P".




NOTE TO EVALUATOR: It is anticipated that the CRS will read step 4 RNO 4.i., but the action will not be taken at this time. This procedure is included as Attachment 5.

BOP

4. RNO i. IF any of the previous alarms lit, THEN backflush affected strainer. REFER TO OP/0/A/6400/006C (Nuclear Service Water System).

BOP 5. Verify each operating RN pump discharge flow - LESS THAN 23,000 GPM.

BOP 6. Ensure RN pumps - IN OPERATION AS NEEDED.

NOTE TO EVALUATOR: The KC heat exchanger outlet mode switches will be in the “KC Temp” position if the corresponding train of KC is in service. Otherwise, it will be in the “Miniflow” position.

BOP

7. Ensure proper alignment of RN to KC Hxs as follows: a. Verify RN - ALIGNED TO IN SERVICE KC HX(S). b. Ensure KC Hx Otlt Mode switches -PROPERLY ALIGNED.

BOP 8. Verify each operating RN pump discharge flow - GREATER THAN 8,600 GPM.

BOP 9. Verify RN - AVAILABLE TO ALL UNIT 1 AND UNIT 2 D/G(S).

NOTE TO EVALUATOR: The low RN flow will probably result in a trip of the operating VC/YC (Control Room Ventilation and Chilled Water System) chiller. The BOP will call the booth to dispatch an operator to perform a local reset.

BOP

10. Determine VC/YC status as follows: • Verify VC/YC - ALIGNED TO OPERATING RN TRAIN. • Verify YC Chiller - RUNNING.

BOP 10. RNO Align VC/YC to operating RN train. REFER TO OP/0/A/6450/011 (Control Room Area Ventilation/Chilled Water System).

SRO 11. Determine and correct cause of loss of RN train.




SRO

12. Ensure compliance with appropriate Tech Specs and Selected Licensee Commitments Manual:

• SLC 16.7-6 (RN Discharge Instrumentation) • 3.6.5 (Containment Air Temperature) • 3.6.6 (Containment Spray System) • 3.6.17 (Containment Valve Injection Water System (CVIWS)) • 3.7.5 (Auxiliary Feedwater (AFW) System) • 3.7.7 (Component Cooling Water (CCW) System) • 3.7.8 (Nuclear Service Water System (NSWS)) • 3.7.10 (Control Room Area Ventilation System (CRAVS)) • 3.7.11 (Control Room Area Chilled Water System (CRACWS)) • 3.8.1 (A.C. Sources - Operating) • 3.8.2 (A.C. Sources - Shutdown).

NOTE TO EVALUATOR: T.S. 3.7.8 Condition A (Restore train to OPERABLE status within 72 hours) should be entered.

NOTE TO EVALUATOR: The CRS may direct completion of OP/0/A/6400/006C (Nuclear Service Water System), Enclosure 4.11 (Operability Actions With ONE RN Pump and/or Its Associated D/G Inoperable With Both Units Entering An Action Statement).

SRO

13 Determine required notifications: • REFER TO RP/0/A/5000/001 (Classification Of Emergency) • REFER TO RP/0/B/5000/013 (NRC Notification Requirements)

BOP 14 Notify Environmental Chemistry of any RN pump shifts that have occurred.

SRO 15 Determine long term plant status. RETURN TO procedure in effect.

NOTE TO EVALUATOR: The SRO will conduct a “Crew Update” to inform the crew of any Tech Spec conditions that have been entered.


END OF EVENT 3

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 301 Scenario # 1 Event # 4 Page 24 of 67 Event Description: 1B NCDT Pump Trip



EVENT 4

Indications: 1AD-13, B/2 ‘NCDT RECIRC LO FLOW’ 1WLP5730 NCDT Recirc Flow on 1MC9 indicating < 30 gpm.

BOP Recognizes 1B NCDT Pump is OFF

NOTE TO EVALUATOR: The crew will most likely use the alarm response (listed below) to guide the required actions, and may also use OP/1/A/6500/014, Enclosure 4.18 (Shifting NCDT Pumps).

BOP 1. Verify low recirc. flow on 1WLP5730 on 1MC9.

BOP 2. IF due to pump malfunction, start alternate NCDT pump.

NOTE TO EVALUATOR: The following steps are from OP/1/A/6500/014, Enclosure 4.18 (Shifting NCDT Pumps).

BOP

3.2. IF 1B NCDT Pump is in service AND it is desired to place 1A NCDT Pump in service, perform the following:

3.2.1 Stop "NCDT PUMP 1B". 3.2.2 Start "NCDT PUMP 1A." 3.2.3 Verify discharge flow is > 85 gpm as indicated on 1WLP5670

(NCDT Pmp Disch Flow) on 1MC9.


END OF EVENT 4

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 301 Scenario # 1 Event # 5 Page 25 of 67 Event Description: Main Feed Containment Isolation Valve Fails Closed



EVENT 5

Indications: 1AD-4, A-3 ‘S/G C FLOW MISMATCH LO CF FLOW’ 1AD-4, B/3 ‘S/G C LEVEL DEVIATION’ 1AD-4, C/3 ‘S/G C FLOW MISMATCH LO CF FLOW

RO Recognizes loss of all feed flow to the 1C S/G at greater than 5% reactor power.

RO Manually trips the reactor per the immediate actions of AP/1/A/5500/06 (Loss of S/G Feedwater), Case l (Loss of CF Supply To S/Gs).

NOTE TO EVALUATOR: Automatic Reactor Trip is failed. Therefore, failure to manually trip the reactor will lead to S/G dryout within a few minutes.

ALL Enter EP/1/A/5000/E-0 (Reactor Trip or Safety Injection)

NOTE TO EVALUATOR: Due to the immediate action nature of the event, it is not anticipated that the crew will have time to make a plant page announcing the entry into AP/1/A/5500/06, Loss of S/G Feedwater.

NOTE TO EVALUATOR: The following steps are from AP/1/A/5500/06, Loss of S/G Feedwater, Case l (loss of CF Supply To S/Gs).

RO 1. Verify reactor power - LESS THAN 5%.

Critical Task #2 RO

1. RNO IF AT ANY TIME all CF supply to S/G(s) lost, THEN perform the following: a. Manually trip reactor.

ALL b. GO TO EP/1/A/5000/E-0 (Reactor Trip Or Safety Injection).

END OF EVENT 5

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 301 Scenario # 1 Event # 6, 7, 8 Page 26 of 67 Event Description: Equalization header rupture, Main Steam Isolation failure, Annulus Ventilation fan 1A Auto

start failure



EVENTS 6, 7, & 8

NOTE TO EVALUATOR: The following steps are taken from EP/1/A/5000/E-0 (Reactor Trip or Safety Injection).

RO/BOP 1. Monitor Enclosure 1 (Foldout Page).


RO

2. Verify Reactor Trip: • All rod bottom lights – LIT • All reactor trip and bypass breakers – OPEN • I/R power – DECREASING.

RO

3. Verify Turbine Trip: • All turbine stop valves - CLOSED

BOP 4. Verify 1ETA and 1ETB – ENERGIZED.

BOP

5. Verify S/I actuated: a. “SAFETY INJECTION ACTUATED” status light (1SI-13) – LIT. b. Both E/S load sequencer actuated status lights (1SI-14) – LIT.

RO 6. Announce “Unit 1 Safety Injection”.

SRO

7. Determine required notifications: • REFER TO RP/0/A/5000/001 (Classification of Emergency) • REFER TO RP/0/B/5000/013 (NRC Notification Requirements).

RO 8. Verify all Feedwater Isolation status lights (1SI-5) – LIT.

BOP

9. Verify Phase A Containment Isolation status as follows: a. Phase A “RESET” lights – DARK. b. Monitor Light Panel Group 5 St lights on energized train(s) – LIT.


start failure



BOP

10. Verify proper Phase B actuation as follows: a. Verify Containment pressure – HAS REMAINED LESS THAN 3 PSIG. b. IF AT ANY TIME containment pressure exceeds 3 PSIG while in this

procedure, THEN perform Step 10.a.

RO

11. Verify proper CA pump status as follows: a. Motor driven CA pumps – ON. b. 3 S/G N/R levels – GREATER THAN 11%.

NOTE TO EVALUATOR: 1A CA Pump will not be on. However, the SRO should determine that steps contained in the RNO associated with this step will not be effective.

RO

11.a RNO Perform the following for affected train(s): 1) Reset ECCS. 2) Reset D/G load sequencer(s) 3) Start affected pump(s) 4) IF AT ANY TIME B/O occurs, THEN restart S/I equipment

previously on. 11.b RNO Perform the following: 1) Place CA PMP #1 control switch to ON. 2) Ensure CA Pump #1 – RUNNING.

BOP

12. Verify all of the following S/I pumps – ON: • NV pumps • ND pumps • NI pumps

BOP 13. Verify all KC pumps – ON.

BOP 14. Verify all Unit 1 and Unit 2 RN pumps – ON.

NOTE TO EVALUATOR: The CRS may elect to reset “B” train ECCS and D/G load sequencer and secure 1B RN pump due to previously identified clogged strainer.


start failure



BOP

15. Verify proper ventilation systems operation as follows: • REFER TO Enclosure 2 (Ventilation System Verification). • Notify Unit 2 operator to perform Enclosure 3 (Opposite Unit

Ventilation Verification).

NOTE TO EVALUATOR: BOP will address the failure of 1A VE Fan during performance of Enclosure 2.


RO 16. Verify all S/G pressures – GREATER THAN 775 PSIG.

Critical Task #3 RO

16. RNO a Verify Main Steam Isolation as follows: • All MSIVs – CLOSED • All MSIV bypass valves – CLOSED • All S/G PORVs – CLOSED

b. IF any valve open, THEN perform the following: 1) Initiate Main Steam Isolation. 2) IF any valve still open, THEN CLOSE valve.

BOP 17. Verify proper S/I flow as follows:

a. “NV S/I FLOW” – INDICATING FLOW. b. NC pressure – LESS THAN 1620 PSIG.

BOP 17.b RNO 1) Ensure ND pump miniflow valve on operating ND pump(s) - OPEN.

NOTE TO EVALUATOR: Step 17.b.RNO 2) will not be applicable.

BOP 2) IF ND pump miniflow valve(s) cannot be opened, THEN

perform the following for affected train(s): 3) GO TO Step 18.

BOP 18. WHEN time and manpower permit (within two hours of event), THEN

monitor Spent Fuel Pool level and temperature. REFER TO EP/1/A/5000/G-1 (Generic Enclosures), Enclosure 1 (Unit 1 Spent Fuel Pool Monitoring).

NOTE TO EVALUATOR: G-1 Enclosure 1 can be found as Attachment 9 in the back of this guide.


start failure



RO

19. Control S/G levels as follows: a. Verify total CA flow – GREATER THAN 450 GPM. b. WHEN each S/G N/R level greater than 11% (29% ACC), THEN

control feed flow to maintain that S/G N/R level between 11% (29% ACC) and 50%.

RO 20. Verify all CA isolation valves – OPEN.

BOP 21. Verify S/I equipment status based on monitor light panel – IN PROPER ALIGNMENT.

BOP 21.RNO. Align equipment.

RO NOTE Enclosure 4 (NC Temperature Control) shall remain in effect until

subsequent procedures provide alternative NC temperature control guidance.

RO 22. Control NC Temperature. REFER TO Enclosure 4 (NC Temperature Control).


BOP

23. Verify Pzr PORV and Pzr Spray Valve status as follows: a. All Pzr PORVs – CLOSED. b. Normal Pzr spray valves – CLOSED. c. At least one Pzr PORV isolation valve – OPEN.

NOTE TO EVALUATOR: The CRS may elect to transition to RNO step for failed Pzr PORV

BOP

23.RNO.a. IF Pzr pressure less than 2315 PSIG, THEN perform the following: 1) CLOSE Pzr PORV(s). 2) IF any Pzr PORV cannot be closed, THEN CLOSE its isolation valve.

NOTE TO EVALUATOR: Step 23 RNO 3) and 4) will not apply.

BOP

3) IF 1NC-32B OR 1NC-34A cannot be closed OR isolated, THEN perform the following:

4) IF any Pzr PORV cannot be closed OR isolated, THEN perform the following:


start failure



BOP 23. b. Normal Pzr spray valves – CLOSED. c. At least one Pzr PORV isolation valve – OPEN.

RO 24. Verify NC subcooling based on core exit T/Cs – GREATER THAN 0°F.

RO 25. Verify main steamlines intact:

• All S/G pressures – STABLE OR INCREASING • ALL S/Gs – PRESSURIZED.

RO/BOP

26. Verify S/G tubes intact as follows: • Verify the following EMF trip 1 lights – DARK: • 1EMF-33 (Condenser Air Ejector Exhaust) • 1EMF-26 (Steamline 1A) • 1EMF-27 (Steamline 1B) • 1EMF-28 (Steamline 1C) • 1EMF-29 (Steamline 1D)

• All S/G levels – STABLE OR INCREASING IN A CONTROLLED MANNER.

BOP

27. Verify NC System intact as follows: • Containment pressure – LESS THAN 1 PSIG. • IF normal off-site power available, THEN verify containment pressure

less than 0.3 PSIG. • Containment high range EMFs – LESS THAN 3 R/HR: • 1EMF-53A (Containment Trn A) • 1EMF-53B (Containment Trn B).

• Containment EMF trip 1 lights – DARK: • 1EMF-38 (Containment Particulate) • 1EMF-39 (L) (Containment Gas (Lo Range)).

• Containment sump level – STABLE.

RO/BOP

28. Verify S/I termination criteria: a. NC subcooling based on core exit T/Cs – GREATER THAN 0°F. b. Verify secondary heat sink as follows:

• N/R level in any S/G – GREATER THAN 11% OR

• Total feed flow to S/Gs – GREATHER THAN 450 GPM c. NC pressure – STABLE OR INCREASING d. Pzr level – GREATER THAN 11%


start failure



NOTE TO EVALUATOR: Dependent upon the speed at which the crew initiates a manual Main Steam Isolation, the Pzr level requirement may not be met at this time. In this case, the crew will initiate Pzr Spray (per step 28 RNO.d.) and loop in step 28 until S/I termination criteria is met.

ALL

28.RNO.d. Perform the following: 1) IF NC pressure increasing AND normal Pzr spray available, THEN attempt to stabilize NC pressure using normal Pzr spray. 2) RETURN TO Step 28.a

BOP

29. Reset the following: a. ECCS. b. D/G load sequencers. c. IF AT ANY TIME B/O occurs, THEN restart S/I equipment previously on.

BOP 30. Ensure only one NV pump – ON.

RO/BOP 31. Verify NC pressure – STABLE OR INCREASING.

BOP 32. Verify VI pressure – GREATER THAN 50 PSIG.

BOP

33. Isolate NV S/I flowpath as follows: a. Verify the following valves – OPEN:

• 1NV-203A (NV Pumps A&B Recirc Isol) • 1NV-202B (NV Pumps A&B Recirc Isol)

BOP 33. a RNO Perform the following: 1) OPEN affected valve(s). 2) IF 1NV-203A AND 1NV-202B open, THEN GO TO Step 33.b

BOP b. CLOSE the following valves:

• 1NI-9A (NV Pmp C/L Inj Isol) • 1NI-10B (NV Pmp C/L Inj Isol)


start failure



BOP

34. Establish charging as follows: a. THROTTLE 1NV-294 (NV Pmps A&B Disch Flow Ctrl) for 32 GPM charging line flow. b. CLOSE 1NV-309 (Seal Water Injection Flow). c. Ensure one of the following valves – OPEN:

• 1NV-32B (NV Supply To Loop A Isol) • 1NV-39A (NV Supply To Loop D Isol)

d. Ensure 1NV-37A (NV Supply To Pzr Aux Spray) – CLOSED. e. OPEN the following valves:

• 1NV-312A (Chrg Line Cont Isol) • 1NV-314B (Chrg Line Cont Isol)

f. Verify 1NV-309 – ABLE TO BE OPERATED FROM THE CONTROL ROOM. g. Place 1NV-309 in auto. h. Perform the following:

• Maintain charging flow less than 180 GPM. • Maintain 32 GPM seal water flow.

BOP 35. Control charging as follows:

a. Control charging flow to maintain Pzr level stable. b. Verify Pzr level - STABLE OR INCREASING.

BOP 36. Ensure the following containment isolation signals - RESET:

• Phase A • Phase B

BOP 37. Establish VI to containment as follows:

• Ensure 1VI-77B (VI Cont Isol) - OPEN. • Verify VI pressure - GREATER THAN 85 PSIG.

ALL

38. Transition to EP/1/A/5000/ES-1.1 (Safety Injection Termination) as follows:

a. Implement EP/1/A/5000/F-0 (Critical Safety Function Status Trees).

b. Monitor EP/1/A/5000/ES-1.1 (Safety Injection Termination), Enclosure 1 (Foldout Page).

c. GO TO EP/1/A/5000/ES-1.1 (Safety Injection Termination), Step 10.


start failure



NOTE TO EVALUATOR: The following steps are taken from EP/1/A/5000/ES-1.1 (Safety Injection Termination).

BOP

10. Determine if NI pumps should be stopped: a. Verify the following:

• NC pressure - STABLE OR INCREASING • NC pressure - GREATER THAN 1620 PSIG. b. Stop NI pumps. c. GO TO Step 11. d. Verify Pzr spray valves - CLOSED. e. Verify main steamlines intact as follows:

• ALL S/G pressures - STABLE OR INCREASING • ALL S/Gs - PRESSURIZED.

NOTE If Pzr heaters are off, NC pressure may decrease slowly due to Pzr spray bypass flow. This may be considered "stable" pressure.

BOP f. Verify NC pressure - STABLE OR INCREASING. g. Verify NC pressure - GREATER THAN 1620 PSIG. h. Stop NI pumps.

BOP 11. Ensure all ND pump(s) with suction aligned to FWST - STOPPED.

BOP

12. Verify S/I flow not required: a. NC subcooling based on core exit T/Cs - GREATER THAN 0°F. b. Pzr level - GREATER THAN 11% (30% ACC).

RO

13. Transfer condenser steam dump to pressure control mode as follows:

a. Verify condenser - AVAILABLE: • "C-9 COND AVAILABLE FOR STM DUMP" status light (1SI-

18) – LIT • MSIVs on intact S/G(s) - OPEN.

RO/BOP CAUTION If Pzr is solid, lowering intact S/G pressures and NC T-Hots too rapidly can cause a loss of subcooling.

RO/BOP NOTE Quickly stabilizing NC temperature will help prevent Pzr overfill.


start failure



RO/BOP

13. RNO a. Perform the following: 1) Dump steam using intact S/G PORV(s) in subsequent steps to stabilize NC T-Hots. 2) IF Pzr is solid, THEN perform the following in subsequent steps while operating S/G PORVs: a) IF NC pressure starts decreasing, THEN perform the following: (1) IF Pzr level greater than 17%, THEN operate Pzr heaters as required to stabilize pressure. (2) Increase charging flow as required to maintain NC subcooling based on core exit T/Cs greater than 0°F. b) Closely monitor T-Hots until Pzr bubble established. 3) Perform the following to place steam dumps to pressure mode: a) Reset C-7A and C-7B by momentarily placing "STEAM DUMP SELECT" switch to "RESET". b) Place "STM DUMP CTRL" in manual. c) Adjust "STM DUMP CTRL" to 0% demand. d) Place steam dumps in pressure mode. 4) GO TO Step 14.

NOTE TO EVALUATOR: Step 13.RNO a. 2) will not be applicable.

RO 14. Verify all NC T-Hots - STABLE.

RO 14.RNO THROTTLE steam flow and total feed flow as required to maintain NC System temperatures stable.

END OF SCENARIO 1



Attachment List

Scenario 1

ATTACHMENT 1 - Crew Critical Task Summary

ATTACHMENT 2 - Shift Turnover Information

ATTACHMENT 3 - AP/0/A/5500/020 Enclosure 1 (Foldout Page)

ATTACHMENT 4 - 1AD-12, C/5 “RN PMP B STRAINER HI D/P” Annunciator Response

ATTACHMENT 5 - OP/0/A/6400/006C (Nuclear Service Water System), Enclosure 4.8

ATTACHMENT 6 - OP/1/A/6500/014, Enclosure 4.18 (Shifting NCDT Pumps)

ATTACHMENT 7 - EP/1/A/5000/E-0 Enclosure 1 (Foldout Page)

ATTACHMENT 8 - EP/1/A/5000/E-0 Enclosure 2 (Ventilation System Verification)

ATTACHMENT 9 - EP/1/A/5000/G-1 Enclosure 1 (Unit 1 Spent Fuel Pool Monitoring)

ATTACHMENT 10 - EP/1/A/5000/E-0 Enclosure 4 (NC Temperature Control)



ATTACHMENT 1

CREW CRITICAL TASK SUMMARY SAT UNSAT CT # CRITICAL TASK

1 Manually isolate failed open Pressurizer PORV prior to reactor trip or ESF actuation. 2 Manually trip the reactor from the control room before 1C S/G dryout occurs (W/R S/G level < 12%). 3 Manually actuate Main Steam Isolation before a severe (orange path) challenge develops to either the subcriticality

or the integrity CSF or before transition to ECA-2.1, whichever happens first.

Comments:



ATTACHMENT 2

SHIFT TURNOVER INFORMATION Unit 1 Status

Power Level Power History NCS Boron Xenon 75 % MOL 1055 PPM per OAC

Controlling Procedure • OP/1/A/6100/003 (Controlling Procedure for Unit Operation), Enclosure 4.2 (Power

Decrease). The steps up to step 3.15 are complete. Other Information Needed to Assume the Shift

• Unit 1 is at 75% power at the MOL. Unit 2 is at 100% power. 1A CA Pump has been removed from service for PMs. 1A CA Pump has been inoperable for 2 hours and is expected to be returned to service in 8 hours. Direction for the crew is to continue a power decrease to 13% (at 10% / hour) for turbine offline work. The Unit 1 RMWST is NOT aligned to supply Unit 2 per OP/2/A/6200/012 (Reactor Makeup Water).

AOs Available Seven AOs are available as listed on the status board

METEOROLOGICAL CONDITIONS • Upper wind direction = 315 degrees, speed = 3 mph • Lower wind direction = 315 degrees, speed = 4.5 mph • Forecast calls for clear skies over the next 24 hours.



ATTACHMENT 3



ATTACHMENT 4



ATTACHMENT 5



ATTACHMENT 6



ATTACHMENT 7



ATTACHMENT 8



ATTACHMENT 9



ATTACHMENT 10



NRC INITIAL LICENSE EXAM SCENARIO # 2



Facility: Catawba NRC Exam 2016 Scenario No.: 2 Op Test No.: 2016301 Examiners: Operators: SRO RO BOP

Initial Conditions: Unit 1 is at 100% power at EOL. Unit 2 is at 100% power. Turnover: Unit 1 is at 100% power at the EOL. Unit 2 is at 100% power. 1A CA Pump has been removed from

service for PMs. 1A CA Pump has been inoperable for 2 hours and is expected to be returned to service in 8 hours. Direction for the crew is to shift operating NV (Centrifugal Charging) Pumps by starting 1B NV Pump and securing 1A NV Pump. 1B NV Pump pre-start check has been successfully completed.

Event No.

Malf. No. Event Type*

Event Description

1 N – BOP N – SRO

Shift Centrifugal Charging Pumps

2 IDE005F C – RO C – SRO

Atmospheric Dump valve (SV-40) fails open

3 CM004F C – BOP C – SRO

1B CFPT (Main Feed Pump) suction valve fails closed / CFPT fails to auto trip

4 FWP015C R – RO C – SRO TS – SRO

Turbine runback following CFPT trip / Control rods fail to automatically insert

5 KC027F

C – BOP

C – SRO TS – SRO

KC (Component Cooling Water) Mini-Flow fails open

6 MAL-CF001A MAL-IPX003A MAL-IPX003B

C – RO C - SRO

1A CFPT (Main Feed Pump) trip / ATWS

7 CA04B CA005

C – RO 1B CA (Aux Feed) Pump fails to start

8 M – ALL CAPT#1 over speed trip / Loss of Heat Sink

9 NV014F C – BOP 1NV-37A (Aux Pzr Spray) Fails to open

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



Scenario 2 – Summary Initial Condition Unit 1 is operating at 100% power at the EOL. Unit 2 is at 100% power. Turnover: Unit 1 is at 100% power at the EOL. Unit 2 is at 100% power. 1A CA Pump has been removed from service for PMs. 1A CA Pump has been inoperable for 2 hours and is expected to be returned to service in 8 hours. Direction for the crew is to shift operating NV (Centrifugal Charging) Pumps by starting 1B NV Pump and securing 1A NV Pump. 1B NV Pump pre-start check has been successfully completed. Event 1 Shift NV Pumps by starting 1B NV pump and securing 1A NV Pump. Event 2 Atmospheric dump valve 1SV-40 fails open. Crew must take action to isolate this steam leak. This can be accomplished using AP/28 (Steam Leak), or crew can decide to use OMP 1-7 guidance to isolate a known leak. Verifiable Action – RO will close associated isolation valve (1SV-50). Event 3 1B CFPT suction valve will fail closed. The automatic CFPT trip (low flow) will not occur, requiring manual action to trip. Following the CFPT trip, the annunciator for Rod Insertion Lo/Lo limit will illuminate requiring TS evaluation. Verifiable Action – BOP will manually trip 1B CFPT. Event 4 Following the CFPT 1B trip, a turbine runback will occur and AP/03 (Load Rejection) will be entered. Due to the runback rods should auto insert, but this feature will be failed, requiring the RO to manually insert rods. Verifiable Action – RO will manually insert control rods as necessary to maintain Tavg/Tref within 1°F. Event 5 KC miniflow valve 1KC-C37A will fail open. Crew will enter AP/21 (Loss of Component Cooling) to address the miniflow valve issue. Attempts to manually close 1KC-C37A will not be successful. TS 3.7.7 Action A will be entered for ‘A’ train KC being inoperable. Verifiable Action – BOP will start additional KC pump in order to provide adequate flow to in service loads. Event 6 1A CFPT will spuriously trip. AP/06 immediate actions require the RO to trip Unit 1 reactor on loss of all CF flow to any S/G. The reactor will fail to trip from the control room requiring entry into FR-S.1. Once emergency boration flowpath is aligned (1NV-236B open), the reactor will trip. Verifiable Action – RO will manually insert control rods and BOP will initiate emergency boration.



Scenario 2 – Summary Event 7 1B CA pump will fail to start (and cannot be manually started) following the reactor trip. Verifiable Action – RO will manually start the #1 CAPT. Event 8 Twelve minutes following initiation of emergency boration the CAPT will experience an overspeed trip. With S/G N/R levels < 11% and no CA flow possible, a transition to FR-H.1 (Response to Loss of Secondary Heat Sink) will be required. Following transition to FR-H.1, steam generator depressurization will be required to establish feed flow from the CM system. Verifiable Action – Align feed flow to establish increasing S/G levels. Event 9 During performance of FR-H.1, an attempt to depressurize the RCS using Aux Pressurizer Spray will not be effective due to failure of 1NV-37A (NV Supply to Pzr Aux Spray) to open. RCS depressurization using a Pressurizer PORV will be required. Verifiable Action – BOP will depressurize RCS using a Pzr PORV. Critical Task 1 – Insert negative reactivity into the core by at least one of the following methods before completing the immediate action steps of FR-S.1:

• De-energize the control rod drive MG sets • Insert RCCAs • Establish emergency boration flow to the RCS

Critical Task 2 – Establish required feedwater (450 gpm) flow into at least one S/G before RCS bleed and feed is required.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (5–8) 8

2. Malfunctions after EOP entry (1–2) 2

3. Abnormal events (2–4) 4

4. Major transients (1–2) 1 5. EOPs entered/requiring substantive actions (1–2) 2 6. EOP contingencies requiring substantive actions (0–2) 2

7. EOP based Critical tasks (2–3) 2



EXERCISE GUIDE WORKSHEET

1. INITIAL CONDITIONS:

1.1 Reset to IC # 21

START TIME:__________ NOTES: Trigger Instructor Action Final Delay Ramp Delete In Event

2

MAL-IDE005F ATM STEAM DUMP SV40 UNCONDITIONAL FAILURE

100 :05 2

3

VLV-CM004F CM140 COND CF PMP 1B SUCTION ISOL FAIL TO POSITION

0 :10 3

N/A BST-JFB5943B (2/3 SUCT FLOW CFPT B TRIP) AS-IS 3

N/A BST-JFB5944B (2/3 SUCT FLOW CFPT B TRIP) AS-IS 3

N/A BST-JPB5972 (2/3 SUCT PRESS CFPT B TRIP - PS) AS-IS 3

N/A BST-JPB5973 (2/3 SUCT PRESS CFPT B TRIP - PS) AS-IS 3

N/A MAL-IRX009 (RODS FAIL TO MOVE) AUTO 4

5

VLV-KC027F (KCC37A TRAIN A RECIRC LINE ISOL VLV FAIL TO POSITION)

1 :02 5

6 OVR-FWP012C (CFPT 1A TRIP & RESET TRIP PB) ON 6

N/A MAL-IPX003A REACTOR TRIP BKR A FAILURE ACTIVE 6

N/A MAL-IPX003B REACTOR TRIP BKR B FAILURE ACTIVE 6

10 MAL-IPX003A REACTOR TRIP BKR A FAILURE ACTIVE :01 6

10 MAL-IPX003B REACTOR TRIP BKR B FAILURE ACTIVE :02 6

N/A MAL-CA004B FAILURE OF CA PUMP B TO START BOTH 7

10 MAL-CA005 CA PUMP OVERSPEED TRIP MECH- ANICAL 12:00 7



N/A LOA-CA017 (RACKOUT CA PMP 1A) RACK-OUT

N/A

VLV-NV014F (NV37A PRZR SPRAY LINE ISOL VLV FAIL TO POSITION)

0

11

LOA-NV078 (SEAL WATER LOW FLOW LCL REFLASH ACK (AD7,C4))

ACK 2 MIN

12

LOA-CF020 (CFPT A COMMON TROUBLE LCL REFLASH ACK )AD5/C4))

ACK 2 MIN

Ensure Event 10 = x10i247o (1NV-236B Open) Place a collar on 1A CA Pump. Ensure A Train KC in service.



2. SIMULATOR BRIEFING

2.1 Control Room Assignments:

Position Name CRS RO

BOP

2.2 Give a copy of Attachment 2 (Shift Turnover Information) to the CRS.

3. EXERCISE PRESENTATION

3.1 Familiarization Period

A. Allow examinees time to familiarize themselves with the Control Board alignments.

3.2 Scenario EVENT 1, Centrifugal Charging (NV) Pump swap

BOOTH INSTRUCTOR ACTION Following start of 1B NV pump, wait one minute and REPORT “1B NV Pumps is good for

continued operation”. 3.3 Scenario EVENT 2, 1SV-40 failure


1SV-40 to fail open.

BOOTH INSTRUCTOR ACTION IF the SWM is contacted to initiate an NCR for 1SV-40, REPEAT back the information.


IF an AO is dispatched to investigate 1SV-40, REPEAT back the information.

BOOTH INSTRUCTOR ACTION IF the Unit Supervisor is contacted to develop a clearance for isolation of 1SV-40,


BOOTH INSTRUCTOR ACTION IF RP is notified of steam leak, REPEAT back the information.



3.4 Scenario EVENT 3, 1CM-140 failure


1CM-140 (1B CFPT Suction Valve) to close.

BOOTH INSTRUCTOR ACTION IF the SWM is contacted to initiate an NCR, REPEAT back the information.


IF the SOC is notified of current unit status, REPEAT back the information.

BOOTH INSTRUCTOR ACTION IF the Reactor Group Engineer is notified of the occurrence, REPEAT back the

information.

BOOTH INSTRUCTOR ACTION IF RP is notified to sample and analyze gaseous effluents, REPEAT back the information.


IF Chemistry is notified to sample for isotopic analysis of iodine, REPEAT back the information.


IF AO is dispatched to acknowledge Low Seal Water Flow Annunciator, THEN INSERT SIMULATOR Trigger 11 to acknowledge annunciator.


IF AO is dispatched to acknowledge MFP common trouble, THEN INSERT SIMULATOR Trigger 12 to acknowledge annunciator.

3.5 Scenario EVENT 4, Auto Control Rod failure


3.6 Scenario EVENT 5, KC miniflow valve 1KC-C37A fails open

BOOTH INSTRUCTOR ACTION WHEN directed by the lead examiner, THEN INSERT SIMULATOR Trigger 5 to fail 1KC-

C37A Open.





IF an AO is dispatched to verify EKPI-29 is ON, REPEAT back the information. 3.7 Scenario EVENT 6, 1A CFPT Trip / ATWS


WHEN directed by the lead examiner, THEN INSERT SIMULATOR Trigger 6 to trip 1A CFPT


IF the SWM is contacted to initiate an NCR, REPEAT back the information.

BOOTH INSTRUCTOR ACTION IF AO is contacted to locally open RX Trip Breakers and MG Set Output Breakers,


BOOTH INSTRUCTOR ACTION IF Primary Chemistry is contacted to obtain current NC boron concentration, REPEAT

back the information. 3.8 Scenario EVENT 7, 1B CA Pump failure

BOOTH INSTRUCTOR ACTION IF AO is contacted to investigate the 1B CA Pump & breaker, REPEAT back the

information. Wait 10 Min and inform that no obvious problems found, Maintenance investigation continuing.


IF the SWM is contacted to expedite return of 1A CA Pump, REPEAT back the information.


IF the SWM is contacted to initiate an NCR for 1B CA Pump, REPEAT back the information.


IF contacted as primary chemistry to periodically perform NC boron samples, REPEAT the information.



3.9 Scenario EVENT 8, Loss of Heat Sink

BOOTH INSTRUCTOR ACTION IF AO is contacted to reset CAPT T&TV, repeat back the information. Wait 10 minutes and

inform that T&TV is mechanically bound and cannot be reset.

BOOTH INSTRUCTOR ACTION IF maintenance is contacted to perform troubleshooting procedure EM/1/A/5200/007,

REPEAT the information.

BOOTH INSTRUCTOR ACTION IF an AO is dispatched to verify CA Valve alignment per Enclosure 2, REPEAT the

information.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 301 Scenario # 2 Event # 1 Page 11 of 63 Event Description: Shift Centrifugal Charging Pumps



EVENT 1

NOTE TO EVALUATOR: Crew begins by shifting the operating charging pump per OP/1/A/6200/001 (Chemical and Volume Control System), Enclosure 4.13 (Shifting Of the Operating Charging Pump). The initial conditions are complete.

ALL

NOTE: This enclosure affects reactivity and is designated important to Reactivity Management per AD-OP-ALL-0203 (Reactivity Management). (R.M.)

BOP 3.1 IF shifting from 1A NV Pump in service to 1B NV Pump in service, perform the following:

CAUTION: • If an NV Pump has been idle for an extended period of time, a boron transient

may be initiated when it is placed in service. The volume of 1A NV Pump and associated piping is 103 gallons; the magnitude of the transient will be minimal.

• Shifting charging pumps at low NC System pressures (< 1000 psig) with NC Pump(s) in service will result in hydraulic transients being placed on the NC Pump seal packages. Operating experience shows that these transients will affect seal return flow. (PIP 09-2596)

NOTE TO EVALUATOR: Step 3.1.1 and the preceding note will not be applicable.

NOTE: A loss of 1EPD with only the 1B NV Pump running will isolate normal letdown due to an indicated loss of both charging pumps; the loss of 1EPD will also disable the LTOP function of 1NC-32B (PZR PORV) creating a challenge to LTOP. This challenge does NOT occur if either the 1A NV Pump is in service or ND Letdown is in service. (PIP C-12-1241)

BOP

3.1.1 IF Unit 1 is in Mode 4 with any RCS cold leg < 210°F, or Mode 5, or Mode 6 when the reactor vessel head on, make log entry for 1NC-32B (PZR PORV) per the applicable:

BOP 3.1.2 Ensure VCT pressure is between 18-40 psig as read on 1NVP5500 (VCT Vent Press) (1MC5).

NOTE: If in an emergency situation, the 30 second delay after starting the Aux Oil Pump is NOT required before starting the NV pump.

BOP 3.1.3 30 seconds prior to starting 1B NV pump, place "NV PUMP 1B AUX OIL PUMP" in the "ON" position.

NOTE TO EVALUATOR: The crew will make a plant page to notify personnel of the start of the 1B Charging Pump

BOP 3.1.4 Start "NV PUMP 1B". (R.M.)

BOP 3.1.5 Place "NV PUMP 1B AUX OIL PUMP" in "AUTO".

BOP 3.1.6 Stop "NV PUMP 1A".

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 301 Scenario # 2 Event # 1 Page 12 of 63 Event Description: Shift Centrifugal Charging Pumps



BOP 3.1.7 Verify proper charging flow rate.


END OF EVENT 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 301 Scenario # 2 Event # 2 Page 13 of 63 Event Description: Atmospheric Steam Dump Failure



EVENT 2

Indications: 1SV-40 red OPEN indicating light is lit, green CLSD light is dark Steam pressure decreasing Reactor power increasing

OAC PT C1Q0986 ‘1SV-40 OPEN’

NOTE TO EVALUATOR: The crew may take action, per OMP 1-7, to isolate a known leak, and close 1SV-50 instead of entering AP-28 to perform the isolation, or use the OAC alarm response as guidance to isolate 1SV-40. The OAC alarm response is included as Attachment 11.

NOTE TO EVALUATOR: The following steps are from AP/1/A/5500/028, Secondary Steam Leak.

NOTE TO EVALUATOR: If crew decides to enter AP/1/A/5500/028, then a plant page announcing the entry into this AP will be made.

RO/BOP 1. Monitor Enclosure 1 (Foldout Page)


RO 2. Verify turbine – ONLINE.

RO 3. Verify the following:

• Reactor Power – LESS THAN OR EQUAL TO 100% POWER • T-Avg – WITHIN 1.5°F OF T-Ref.

RO

3. RNO Perform the following: a. Select “MANUAL” on turbine control panel.

b. Depress “CONTROL VALVES LOWER” pushbutton and reduce turbine load to maintain:

• Reactor power – LESS THAN OR EQUAL TO 100% POWER • T-Avg – WITHIN 1.5°F OF T-Ref.

RO 4. Verify proper reactor response as follows:

• Control rods – IN AUTO AND STEPPING IN • P/R neutron flux – DECREASING.

RO 4. RNO IF T-Avg greater than 1.5°F higher than T-Ref, THEN insert control rods as required to maintain T-Avg within 1°F of T-Ref.




ALL 5. IF AT ANY TIME reactor power greater than 100%, THEN perform Step 3 RNO.

BOP 6. Verify Pzr level – STABLE OR INCREASING.

ALL 7. IF AT ANY TIME while in this procedure Pzr level decreasing in an uncontrolled manner, THEN RETURN TO Step 6.

ALL 8. IF AT ANY TIME VCT level goes below 23%, THEN align NV pump suction to FWST as follows:

BOP

9. Attempt to identify and isolate leak as follows: a. Verify the following conditions – NORMAL:

• Containment temperature • Containment pressure • Containment humidity • Containment floor & equipment sump level

BOP 9b. Dispatch operators to locate and identify source of steam leak.

RO 9c. Verify S/G PORVs – CLOSED

RO 9d. Verify condenser dump valves - CLOSED

RO 9e. Verify atmospheric dump valves - CLOSED

NOTE TO EVALUATOR: The CRS may elect not to perform step 9.e RNO due to the failure being identified and isolated.

RO

9e.RNO IF steam dump valves required to be closed, THEN perform the following: 1) Select “OFF RESET” on the following switches:

• “STEAM DUMP INTLK BYP TRN A” • “STEAM DUMP INTLK BYP TRN B”




RO 9e.RNO 2) IF valve will not close, THEN CLOSE affected atmospheric dump

valve isolation valve.

RO 9e.RNO 3) IF isolation valve will not close, THEN dispatch operator to fail air to affected atmospheric dump valve.

RO

9e.RNO 4) WHEN leaking atmospheric dump valve isolated OR repaired, THEN return the following switches to “ON”: • “STEAM DUMP INTLK BYP TRN A” • “STEAM DUMP INTLK BYP TRN B”

BOP 9f. Verify CA PMP #1 - OFF

NOTE TO EVALUATOR: Step 9.g will not be applicable.

RO 9g. IF leak suspected to be in a doghouse, THEN CLOSE the following

valves:

SRO 10. Determine required notifications:

• REFER TO RP/0/A/5000/001 (Classification of Emergency) • REFER TO RP/0/B/5000/013 (NRC Notification Requirements)

BOP 11. Notify RP of leak.

ALL 12. Verify – LEAK ISOLATED.

ALL 13. Determine long term plant status. RETURN TO procedure and step in effect.

NOTE TO EVALUATOR: SRO may have a crew or focus brief at this time.

Booth Operator will insert Trigger 3 for EVENTS 3 & 4 at the discretion of the lead examiner.

END OF EVENT 2

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 301 Scenario # 2 Event # 3 & 4 Page 16 of 63 Event Description: 1B CFPT Suction Valve Fails Closed. Automatic Control Rod Insertion Failure on Runback



EVENTS 3 & 4

Indications: 1AD-5, C/4 CFPT B COMMON TROUBLE 1AD-5, D/4 CFPT B LO SUCT FLOW 1AD-5, F/5 CFPT B LO SUCT PRESS

1B CFPT suction flow decreasing

BOP Recognize 1B CFPT (Main Feed Pump) Flow decreasing

BOP Trip 1B CFPT

NOTE TO EVALUATOR: CFPT suction flow < 3000 GPM for > 20 seconds will cause a CFPT trip. The crew may elect to not wait the full 20 seconds and may decide to trip 1B CFPT. Following trip of the CFPT a turbine runback will initiate. During the runback, control rods will fail to automatically insert. This will require the RO to manually insert control rods.

NOTE TO EVALUATOR: The crew may make a plant page announcing entry into AP/1/A/5500/003 (Load Rejection). The following steps are taken from AP/1/A/5500/003 Ca

Documents

NRC INITIAL LICENSE EXAM SCENARIO # 1for PMs. 1A CA Pump has been inoperable for 2 hours and is expected to be returned to service in 8 hours. Direction for the crew is to continue