ML13073A545
| ML13073A545 | |
| Person / Time | |
|---|---|
| Site: | Arkansas Nuclear  |
| Issue date: | 03/01/2013 |
| From: | Clyde Osterholtz Operations Branch IV |
| To: | Entergy Operations |
| Laura Hurley | |
| References | |
| ES-301-1 05-313/13-002 | |
| Download: ML13073A545 (431) | |
Text
Appendix D Scenario Outline Facility: ANO-1 Scenario No.: 1 R2 Op-Test No.: 2013-1 Examiners: ____________________________ Operators: _____________________________
Initial Conditions:
- 100% Power. - #2 EDG will not Auto-Start.
- EFIC failed and will not auto-actuate. - Provide picture of RS-4.
- C-28B IA Compressor is out of service for overhaul. - P-36C MU Pump in service.
- CV-3806 SW to #1 EDG is failed closed.
Turnover:
- Day shift - normal working day. - Need to Drain RB Sump to 40%. This is not
- C-28B IA Compressor is out of service for overhaul. the first draining of the month and sampling
- Currently in a Severe Thunderstorm Warning for the next is not required.
hour. All required actions of 1203.025, Natural Emergencies have been completed.
Event Event Event Malf. No.
No. Type* Description N-(BOP) Perform draining of the Reactor Building Sump per 1104.014 1 CV-4400 C-(SRO) with failure of CV-4400 to close.
TS (Technical Specification 3.6.3, Reactor Building Isolation Valves)
Lightning Lightning strike strike N/A DI-DG1S #1 EDG auto-start 2
K01A1 #1 EDG Auto Start alarm C-(BOP)
- 1 EDG shutdown TS R-(ATC) Dispatcher directs a power reduction to 700MW in the next 10 3 N/A N-(SRO) minutes Lightning Lighting strike strike I-(ATC) 4 I-(SRO)
ED451 Loss of NNI-Y power supply ED183 M-(ALL) Loss of Offsite Power/Degraded Power 5 DG176 C-(BOP) #2 EDG will not auto start 6& C-(SRO) 7 DI_DG2_VR-LW CT #2 EDG voltage low (<4100V)
C-(ATC)
FW621 C-(SRO) EFIC fails CT TS M-(ALL)
DG173 #2 EDG will trip TS 8
N/A A901 Alternate AC Generator available CT
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 1 of 24
Appendix D Scenario Outline SCENARIO 1 OBJECTIVES
- 1) Evaluate individual ability to perform Draining of the Reactor Building Sump.
- 2) Evaluate individual ability to recognize and respond to the false auto start of emergency diesel generator.
- 3) Evaluate individual ability to recognize and respond to the failure to open of the service water supply valve on an operating emergency diesel generator.
- 4) Evaluate individual ability to reduce plant power.
- 5) Evaluate individual ability to recognize and respond to the loss of power to the Y Non-Nuclear Instrumentation system.
- 6) Evaluate individual ability to recognize and respond to a loss of offsite power.
- 7) Evaluate individual ability to recognize and respond to failure of the emergency diesel generator to auto start.
- 8) Evaluate individual ability to recognize and respond to the failure of the Emergency Feedwater Initiation and Control system to automatically actuate emergency feedwater.
- 9) Evaluate individual ability to recognize and respond to the tripping of the remaining emergency diesel generator putting the plant in a blackout condition.
- 10) Evaluate individual ability to perform the energizing of a vital bus from the Alternate AC generator.
- 11) Evaluate individual ability to recognize when conditions require the entry into technical specifications conditions.
Page 2 of 24
Appendix D Scenario Outline SCENARIO 1 NARRATIVE The crew will assume plant responsibility at 100% power. The SRO will direct draining of the Reactor Building Sump per 1104.014. Sump Drain valve CV-4400 will fail in the open position requiring the operator to close CV-4446 to stop the draining of the Reactor Building Sump. The inoperability of CV-4400 will require entry into Technical Specification 3.6.3 Condition A.
C-(BOP) C-(SRO) TS A lightning strike will cause the auto start of the #1 EDG. The CRS should direct operations per 1203.012A Annunciator K01 Corrective Actions. The crew should determine it is a spurious actuation. The #1 EDG SW valve CV-3806 will not open resulting in no cooling flow to the EDG (BOP-C) (SRO-C). The crew should take the #1 EDG to lockout to prevent an automatic trip of the EDG (TS).
TS 3.8.1. Condition B The dispatcher will call and direct U1 to reduce net generator output to 700MWe (SRO-N)
(ATC-R).
A second lightning strike will result in the loss on NNI-Y power supply (ATC-I) (SRO-I). The crew should recognize the loss of NNI-Y power. The CRS should implement 1203.047 Loss of NNI Power. The power supply breakers on RS-4 bkr 9 and Y01 bkr 39 will not reset. Breakers S-1 and S-2 on the NNI-Y power supply will not be tripped.
Letdown flow and pressure indication will be lost on C04. The letdown orifice bypass valve will fail to 50% reducing letdown flow. CFT pressure instrumentation will be lost along with NaOH tank temperature. All NNI-Y inputs to PMS/PDS will be lost or fail to mid scale.
A loss of offsite power will occur due to storm related grid instabilities (SRO-M) (ATC-M)
(BOP-M). The reactor will trip automatically. The CRS will direct operations per 1202.001 Rx Trip. After the immediate actions are complete the CRS will transition to either 1202.008 Blackout or 1202.007 Degraded Power depending on when the BOP manually starts the #2 EDG.
The #2 EDG will not auto start requiring the BOP to manually start the EDG (BOP-C) (BOP-CT).
CT criteria - The BOP should start the #2 EDG before the 15 minute criteria for declaring an SAE for a station blackout. The Alternate AC (AAC) Generator initially will not come up to speed. Unit 2 operations will dispatch maintenance personnel to make repairs.
The EFIC system is failed and will not automatically actuate EFW on the Loss of Offsite Power (ATC-C) (SRO-C). The ATC should manually actuate EFW from the remote switch matrix (ATC-CT) (TS). The ATC will perform 1202.012 Repetitive Tasks RT-5 Verify proper EFW actuation and control. EFW may be manually actuated before the step in the EOP that directs verifying EFW actuated.
TS 3.3.11 Condition B CT - EFW should be manually actuated before the ERV opens in automatic.
The #2 EDG will trip putting the plant into a blackout (SRO-M) (ATC-M) (BOP-M) (TS). The CRS will direct operations per 1202.008 Blackout.
TS 3.8.1 Condition E, 3.0.3 The AAC generator will become available. The BOP should energize the A3 or A4 bus from the AAC generator (BOP-CT).
CT criteria - The AAC generator should be placed in service within 10 minutes of the AAC Generator being reported as available.
The scenario can be terminated when the AAC Generator is powering a vital bus.
Page 3 of 24
Appendix D Scenario Outline Simulator Instructions for Scenario 1 Recall IC 285 Verify the following:
- Install Caution Card and make status board entry for C-28B OOS.
- Verify tags correct on HPI pumps (P36A ES, P36B STBY, P36C OP)
Manually set constant CAKLAG to 1 Turn off RB sump level lag Insert remote C28BRUN to OFF Turn off C28B IA compressor Insert override DO_C28BSLG to Off Turn off C28B green light on C19 Insert override DO_C28BSLR to Off Turn off C28B red light on C19 Insert malfunction FW621 EFIC Auto-actuation is failed Insert malfunction CV3806 to 0 #1 EDG SW valve is failed CLOSED Insert malfunction DG176 #2 EDG fails to AUTOSTART Insert Malfunction CV4400 to 1 on Event 1 Fails RB Sump outlet valve OPEN Insert remote LIGHTNING to TRUE on event 2 delete in 5 Activate lightning strike simulation Insert override DI_DG1S to TRUE on event 2 Start #1 EDG Insert override DI_DG1SP to FALSE on event 2 Deactivate #1 EDG Stop Button Insert malfunction K01A1 to ON on event 2 Alarm #1 EDG Auto-start Command annunciator Insert remote LIGHTNING to TRUE on event 3 delete in 5 Activate lightning strike simulation Insert malfunction ED451 on event 3 Loss of NNI-Y Power Insert malfunction ED183 on event 4 Loss of Off-site Power Insert malfunction DG174 on event 5 #2 EDG Trips Insert remote A901 to CLOSED on event 6 Aligns AAC Generator to A3/A4 cross-tie Event Value/Ramp Time Malf. No. Event Description No. Time Perform Draining of the Reactor Building Sump Trigger 1 1/
1 0 per 1104.014 with failure of CV-4400 to close.
CV4400 N/A (TS)
Trigger 2 Lightning TRUE Lightning strike will cause auto-start of #1 12 DI_DG1S TRUE EDG.
DI_DG1SP FALSE 2
K01A1 ON
- 1 EDG SW valve will not open following the Initial CV3806 0 EDG auto-start. This will require the operators to shutdown #1 EDG (TS).
Dispatcher will call and direct a power 3 20 N/A N/A reduction to 700MWe in the next 10 minutes.
Trigger 3 Another lightning strike will result in the loss of 4 30 Lightning TRUE the NNI-Y power supply.
ED451 N/A Trigger 4 A Loss of Off-site power will occur resulting in 38 N/A ED183 an automatic reactor trip.
The #2 EDG will not auto-start requiring the operators to manually start the EDG.
Initial DG175 N/A (BOP-CT) criteria - The BOP should start 5,6 & the #1 EDG before 15 minute criteria for 7 declaring an SAE for a Station Blackout EFIC is failed and will not automatically actuate EFW. (TS)
Initial FW621 N/A (ATC-CT) criteria - EFW should be manually actuated before the ERV opens in automatic.
Unit 2 will report the AAC Generator is running slow. Maintenance has been dispatched.
Trigger 5 The #2 EDG will trip putting the plant into a 50 N/A DG174 Blackout. (TS) 8 At T=54 Unit 2 will report the AAC Generator has been repaired and is running normally with breaker 2A-901 closed.
Continued on next page Page 4 of 24
Appendix D Scenario Outline Event Value/Ramp Time Malf. No. Event Description No. Time The Alternate AC Generator will become available.
8 Trigger 6 54 CLOSED (BOP-CT) criteria - The AAC Generator (cont.) A901 should be placed in service within 10 minutes of regaining the AAC Generator.
Page 5 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 1 Event
Description:
Drain RB sump to AB sump using 1104.014 section 8.0 and failure of CV-4400 to close.
Time Position Applicants Actions or Behavior T=0 BOP Conduct pre-job brief with SRO.
EVALUATOR NOTE:
Based on turnover, this is not the first sump drain of the month, therefore sampling is not required.
8.1 IF in modes 1 - 4 AND this is the first sump drain of the month, THEN BOP GO TO "Sampling RB Sump" section of this procedure.
BOP Determines that sump sampling is not required.
BOP 8.2 Notify RP of intent to drain RB sump.
8.3 Allow liquid in RB sump to gravity drain to AB sump by performing the following:
- Place RB Sump to AUX Sump CV-4446 handswitch (HS-4446) to OPEN.
- Place RB Sump to AUX Sump CV-4400 handswitch (HS-4400) to OPEN.
8.4 Check Aux Building Sump level (LI-4403) goes up while RB Sump level BOP (LI-1405) goes down.
EVALUATOR NOTE:
Based on turnover, the desired final RB Sump level is 40%.
8.5 WHEN one of the following is met:
- Aux Building Sump (LI-4403) 60%
- Prior to Rx Bldg Sump Level (SPDS L1405) reaching 30.4%
- Rx Bldg Sump Level (SPDS L1405) at desired level THEN place RB Sump to AUX Sump CV-4400 handswitch (HS-4400) to CLOSE.
When RB sump level reaches desired level (40%), close CV-4400 by BOP placing HS-4400 in the close position.
EVENT 1 CONTINUED Page 6 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 1 CONTINUED Event
Description:
Drain RB sump to AB sump using 1104.014 section 8.0 and failure of CV-4400 to close.
Time Position Applicants Actions or Behavior Identify failure of CV-4400 to close and that sump level continues to lower.
BOP (Red light ON and Green Light OFF for CV-4400 and RB sump level continues to lower).
BOP Report failure of CV-4400 to the SRO.
8.6 IF further draining of RB Sump is desired AND Aux Building Sump level BOP shows capacity to receive water, THEN place RB Sump to AUX Sump CV-4400 handswitch (HS-4400) to OPEN AND GO TO step 8.5.
8.7 Place RB Sump to AUX Sump CV-4446 handswitch (HS-4446) to BOP CLOSE.
EXAMINER NOTE:
The following step cannot be performed due to CV-4400 being failed open.
8.8 Place RB Sump to AUX Sump CV-4400 handswitch (HS-4400) to OPEN BOP to allow penetration #68 to drain.
Identify Technical Specification is applicable.
SRO TS (3.6.3 Condition A, due to failure of one Reactor Building penetration valve inoperable.
[48 hour completion time to isolate the flow path.])
EVENT TERMINATION CRITERIA This event is complete when CV-4446 is closed and Tech Spec action statement is entered OR As directed by the Lead Evaluator.
Page 7 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 2 Event
Description:
Lightning strike will cause the auto start of #1 EDG.
- 1 EDG SW valve will not open following the EDG auto start. This will require the operators to shutdown #1 EDG.
Time Position Applicants Actions or Behavior Acknowledge and report Annunciator K01A1 EDG 1 AUTO START 12 ATC COMMAND.
Direct plant operation per 1203.012A, K01 Annunciator Corrective CRS Action, K01A1 EDG 1 AUTO START COMMAND.
BOP 1. Verify that DG1 auto-starts.
BOP 2. Check bus A3 energized from bus A1.
BOP 3. Check bus B5 energized.
ANY 4. Verify SERV WTR to DG1 CLRS (CV-3806) opens.
ANY Recognize and report CV-3806 will not open.
CRS Direct an AO to attempt to open CV-3806 locally manually.
BOP 5. Verify a Service Water pump powered from A3 running.
CRS Determines that all buses are energized.
- 7. Refer to Emergency Operating Procedures, (1202.XXX series) as CRS necessary.
BOP 8. Verify DG1 at 4160V and 60 Hz.
ANY 9. Restart needed equipment.
- 10. Record DG1 parameters hourly per Diesel Generator Log (OPS-BOP A15a).
- 11. WHEN DG1 is no longer required on bus A3, THEN secure DG1 CRS using Emergency Diesel Generator Operation (1104.036).
EVENT 2 CONTINUED Page 8 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 2 CONTINUED Event
Description:
Lightning strike will cause the auto start of #1 EDG.
- 1 EDG SW valve will not open following the EDG auto start. This will require the operators to shutdown #1 EDG.
Time Position Applicants Actions or Behavior IA OPERATOR CUE:
If called the AO will report CV-3806 cannot be opened locally.
EXAMINER NOTE:
When it is determined that CV-3806 will not open, the CRS should direct that DG1 be placed in lockout to prevent engine damage due to overheating.
Direct #1 EDG be placed in lockout (BOP may try to push stop P/B first.
CRS EDG will stop but then restart).
TS 3.8.1. Condition B IA OPERATOR CUE:
If called U2 will report Alternate AC Generator is available.
CRS Contact work management to investigate cause of EDG start.
EXAMINER NOTE:
P-36B Makeup pump is already aligned to #2 EDG as required. Only P-4B SW pump power supply and MCC B55/56 will need to be transferred to the #2 EDG side.
- 13. IF DG1 inoperable, Verify proper MOD alignment for Service Water Pump (P-4B) and Makeup Pump (P-36B) per Makeup & Purification CRS System Operation (1104.002) AND Service Water and Auxiliary Cooling System (1104.029).
CRS/ References step 8.0, Normal Operation section of 1104.029 Service BOP Water and Auxiliary Cooling System procedure.
8.1 During normal operation, SW system and ACW system conditions are as follows:
CRS/ 8.1.1 Component breakers aligned per ES Electrical System BOP Operations (1107.002).
8.1.2 Instrument air system in operation per Instrument Air System (1104.024).
8.1.3 SW and ACW systems aligned per Attachments A and B.
EVENT 2 CONTINUED Page 9 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 2 CONTINUED Event
Description:
Lightning strike will cause the auto start of #1 EDG.
- 1 EDG SW valve will not open following the EDG auto start. This will require the operators to shutdown #1 EDG.
Time Position Applicants Actions or Behavior 8.1.4 IF in Modes 1-4, THEN check two independently-powered SW CRS/ pumps operating. A. IF desired to Transfer Service Water Pump (P-BOP 4B) MOD, THEN refer to 1107.002 Motor-Operated Disconnect Operation.
8.3 SW Pump P-4B aligned as follows:
References table in step 8.3 to determine alignment of P-4B power supply and sluice gates.
Note 1: IF P4B selected to A4, THEN preferred alignment is SG-3 CRS/
closed & SG-4 open.
BOP IF P4B selected to A3, THEN preferred alignment is SG-3 open &
SG-4 closed.
SG-3 & SG-4 may be positioned as required by CRS/SM.
Note 5: IF one EDG is inoperable (projected or actual) for >1 hour, THEN P-4B should be fed from bus with operable EDG.
CRS/ References step 21.0, Transfer Service Water Pump (P-4B) MOD (A6) to BOP Bus A4 of 1107.002 ES Electrical System Operation.
21.1 To transfer Service Water Pump (P-4B) MOD (A6) to Bus A4 BOP perform the following:
21.1.1 Verify both Service Water Pump (P-4B) breakers are open:
BOP Service Water Pump (P-4B) breaker (A-303)
Service Water Pump (P-4B) breaker (A-403)
BOP 21.1.2 Place P-4B Bus select MOD (A6) Control switch to Bus A4.
21.1.3 Check Service Water Pump (P-4B) MOD (A6) has switched to A4 BOP by observing closed indicating light under Service Water Pump (P-4B) handswitch on C16.
21.1.4 IF both EDGs are operable AND Service Water Pump (P-4B)
MOD will remain aligned to an electrical train opposite of B55/56, BOP THEN transfer B55/56 to B6 per "Transfer MCC B55 & B56 to B6" section of this procedure.
BOP Determines that only one EDG is inoperable.
EVENT 2 CONTINUED Page 10 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 2 CONTINUED Event
Description:
Lightning strike will cause the auto start of #1 EDG.
- 1 EDG SW valve will not open following the EDG auto start. This will require the operators to shutdown #1 EDG.
Time Position Applicants Actions or Behavior 21.1.5 IF required due to switching Service Water Pump (P-4B) MOD (A6), THEN align Sluice Gates SG-3 and SG-4 per "Normal BOP Operation" section of Service Water and Auxiliary Cooling System (1104.029).
Aligns Sluice Gates as previously determined in step 8.3.
CRS/
BOP Opens SG-4 by placing HS-3723 to open.
Closes SG-3 by placing HS-3722 to close.
CRS/ References Sep 17.0, Transfer MCC B55/56 to B6 of 1107.002 of ES BOP ELECTRICAL SYSTEM OPERATION procedure.
BOP 17.1 To transfer MCC B55/56 to B6 perform the following:
EXAMINER NOTE:
P-40B Spent Fuel Cooling Pump is the only component that will have to be stopped per the following step. The other components are not running or not modeled (VUC-9).
17.1.1 Stop the following motor equipment, supplied from B55/56:
Spent Fuel Pool Circ Pump (P-40B) using handswitch HS-2001 on C19 Turb Gen Turning Gear (K-6) using handswitch HS-9205 on C01 Turb Gen HP Lift Oil Pump (P-76) using handswitch HS-9208 on BOP C01 Turb Gen Bearing Oil Pump (P-20) using handswitch HS-9206 on C01 Control Room Emerg A/C Unit Assembly (VUC-9) using HS-7829 on cooling unit (Not Modeled) 17.1.2 Perform transfer to bus B6 per one of the following:
At C10, momentarily select B6 with the MCC B55 & 56 power BOP supply selector switch.
At MCC B56, depress B6 pushbutton. (Local) 17.1.3 Verify transfer has taken place by observing indicator lights on BOP C10 or MCC B56.
EVENT 2 CONTINUED Page 11 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 2 CONTINUED Event
Description:
Lightning strike will cause the auto start of #1 EDG.
- 1 EDG SW valve will not open following the EDG auto start. This will require the operators to shutdown #1 EDG.
Time Position Applicants Actions or Behavior 17.1.4 IF any of the following was secured for B55/56 transfer, THEN restart affected equipment as needed:
Spent Fuel Pool Circ Pump (P-40B) using handswitch HS-2001 on C19 Turb Gen Turning Gear (K-6) using handswitch HS-9205 on C01 BOP Turb Gen HP Lift Oil Pump (P-76) using handswitch HS-9208 on C01 Turb Gen Bearing Oil Pump (P-20) using handswitch HS-9206 on C01 Control Room Emerg A/C Unit Assembly (VUC-9) using HS-7829 on cooling unit (Not Modeled) 17.1.5 IF Boric Acid Pump (P-39A or P-39B) was running at the time of BOP the transfer, THEN restart the pump per Soluble Poison Concentration Control (1103.004).
EVENT TERMINATION CRITERIA This event is complete when #1 EDG is in lockout and P-4B SW pump has been realigned OR As directed by the Lead Evaluator.
Page 12 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 3 Event
Description:
Dispatcher directs a power reduction to 700MWe in the next 10 minutes.
Time Position Applicants Actions or Behavior 20 CRS Direct operations per 1203.045 Rapid Plant Shutdown.
EXAMINER NOTE:
Power reduction will be to 700MWe net. The ULD reads out in gross MW, therefore will have to be adjusted to ~730 MWe to achieve 700 MWe net CRS 1. Commence a plant shutdown at 0.5 to 10% per minute.
CRS directs the ATC to commence power reduction by providing a rate CRS of change and desired ULD setpoint.
Adjusts Rate of Change on controller ICC-0012 to directed setpoint (reads out in 0.25 - 10%/min)
ATC Places ULD (ICC-0009) in manual Lower ULD setpoint to ~730 MWe ATC
- 3. Stabilize power ~700 Mwe.
ATC Refer to "Contingency Reactivity Plans in the Plant Data Book.
- 4. Secure systems as follows:
Request Chemistry secure Zinc Injection per Unit 1 Reactor CRS Coolant System (RCS) Zinc Control (1052.036).
Perform Chemical Addition (1104.003) "Securing Zinc Injection" section.
EVENT TERMINATION CRITERIA This event is complete when power is stable at ~700 MWe OR As directed by the Lead Evaluator.
Page 13 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 4 Event
Description:
Second lightning strike results in the loss of the NNI Y power supply.
Time Position Applicants Actions or Behavior Recognize the loss of NNI-Y power.
Recognize and report loss of letdown flow and pressure indication on 30 ANY C04.
Recognize and report CV-1223 at 50%.
CRS Direct operations per 1203.047 Loss of NNI Power.
- 1. Check ICS and NNI Instrument Power Supply Status lights on C13 AND perform the following:
IF all indications are normal other than loss of all ICS and NNI Instrument Power Supply Status lights on C13, THEN reset CRS/ D11 breaker 25 using Reclosing Tripped Individual Load ATC Supply Breakers section of Electrical System Operations (1107.001).
Check all NNI X power available.
Check all NNI Y power available.
- GO TO step 8.
- 8. IF only NNI Y power is lost, THEN perform the following:
Verify NNI X-powered instruments selected on C03, C04, and ATC C13.
BOP IF MFW pumps are on P control, THEN operate MFW pumps in HAND as necessary to control FW flow.
Check NNI Y AC power available.
EXAMINER NOTE:
The BOP will go to back of control room to a picture of RS-4 to simulate resetting Breaker RS-4 bkr 9.
EXAMINER CUE:
Notify the BOP that RS-4 Breaker 9 is in mid-position.
BOP Reset AND close NNI Y Cabinet C48 Normal supply breaker RS-4 bkr 9.
EXAMINER CUE: If the BOP questions that the step, notify the BOP that CRS directs you to reset and close RS-4 Breaker 9.
EXAMINER CUE:
Notify the BOP that RS-4 Breaker 9 has returned to the mid-position.
Dispatch an operator to reset AND close Alternate supply breaker Y01 CRS bkr 39, while continuing with this procedure.
EVENT 4 CONTINUED Page 14 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 4 CONTINUED Event
Description:
Second lightning strike results in the loss of the NNI Y power supply.
Time Position Applicants Actions or Behavior IA OPERATOR CUE:
The AO will report that Y01 bkr 39 has tripped open and will not reset.
BOP Notifies the CRS that RS-4 Breaker 9 is tripped and will not reset.
EVENT TERMINATION CRITERIA This event is complete when instruments are verified selected to NNI-X power and power supply breakers Y01 bkr 39 and RS-4 bkr 9 are reported as tripped OR As directed by the Lead Evaluator.
Page 15 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 5, 6 & 7 Event
Description:
A Loss of Offsite Power will occur resulting in an automatic reactor trip.
The #2 EDG will not auto start requiring the operators to manually start the EDG.
EFIC fails to Auto-actuate.
Time Position Applicants Actions or Behavior 38 ANY Recognize and report a loss of offsite power.
CRS Direct operations per 1202.001 Reactor Trip EOP.
- 1. Depress Reactor Trip PB.
ATC Verify all rods inserted AND reactor power dropping.
- 2. Depress Turbine Trip PB.
BOP Check Turbine throttle and governor valves closed.
ANY 3. Check adequate SCM.
Reports Immediate Actions complete, Transitioning to Degraded Power CRS procedure.
CRS Direct operations per 1202.007 Degraded Power procedure.
CRS 1. Record time of Degraded Power.
CRS 2. Verify proper operation of both EDGs (RT-21).
BOP Performs actions of 1202.012, RT-21, Check EDG Operation.
- 1. Verify running EDG(s) supplying associated ES bus(es) with proper voltage, frequency, and loading:
BOP 4100 to 4200 V 59.5 to 60.5 Hz 2750 KW ANY Recognize #2 EDG failed to auto start.
- 2. IF EDG(s) failed to start, THEN perform the following:
Check associated EDG CRITICAL TROUBLE and associated bus L.O. RELAY TRIP alarm clear:
BOP IF associated EDG alarms are clear, THEN attempt to start associated EDG at C10. OTHERWISE dispatch an operator to investigate and report EDG malfunction.
Notify CRS/SM of EDG status.
Manually start #2 EDG.
BOP (BOP-CT) CT criteria - The BOP should start the #2 EDG before the 15 minute criteria for declaring an SAE for a station blackout.
Event 5, 6 & 7 Continued Page 16 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 5, 6 & 7 CONTINUED Event
Description:
A Loss of Offsite Power will occur resulting in an automatic reactor trip.
The #2 EDG will not auto start requiring the operators to manually start the EDG.
EFIC fails to Auto-actuate.
Time Position Applicants Actions or Behavior BOP Recognize #2 EDG voltage is low.
BOP Adjust #2 EDG voltage to ~4160V.
CRS Back to the actions of 1202.007 Degraded Power procedure.
- 2. (Contingency) - IF only one EDG OR only the AAC Gen (2K9) is in CRS service, THEN perform the following:
A. IF an EDG is operating, THEN verify proper operation of EDG BOP (RT-21).
BOP B. Verify 480V MCC B55 and 56 power supply is selected to B6.
BOP Close ACW Isolation (CV-3643).
BOP Close SW Cross Tie (CV-3644).
BOP Close SW to ICW Coolers Supply (CV-3811).
D. Attempt to restore non-running EDG using Annunciator K01 CRS Corrective Action (1203.012A) and Emergency Diesel Generator Operation (1104.036), while continuing with this procedure.
Dispatch an operator to restore EDG. (May not be performed as #1 EDG CRS is known to be OOS.)
CRS E. IF AAC Gen is available, THEN perform the following:
- 1) Energize vital bus using ES Electrical System Operation CRS (1107.002), "Placing Alternate AC Generator on bus A3 (A4)"
section, while continuing with this procedure.
CRS Requests U2 start AAC Generator.
CRS 2) GO TO step 3.
Recognize and report Service Water Pump discharge pressure high ANY alarm (CRS may elect to place additional SW loads in service).
- 3. Verify SERV WTR to DG1 and DG2 CLRs open to operating EDGs:
ANY CV-3807 Event 5, 6 & 7 Continued Page 17 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 5, 6 & 7 CONTINUED Event
Description:
A Loss of Offsite Power will occur resulting in an automatic reactor trip.
The #2 EDG will not auto start requiring the operators to manually start the EDG.
EFIC fails to Auto-actuate.
Time Position Applicants Actions or Behavior
- 4. Verify a Service Water pump running on each operating DG, after 15-BOP second time delay (P4A, P4B, P4C).
- 5. Actuate MSLI for both SGs AND verify proper actuation and control of EFW and MSLI (RT-6): (Depresses 8 MSLI buttons and 4 EFW ATC buttons on the C09 switch matrix)
TS TS 3.3.11 Condition B CT (ATC-CT) - EFW should be manually actuated before the Electromatic Relief Valve (ERV) opens in automatic.
A. Operate ATM Dump CNTRL valves in HAND to minimize cycling ATC and conserve Instrument Air.
B. IF Instrument Air to ATM Dump CNTRL valves is lost, THEN perform the following:
Establish SG press control using ATM Dump ISOL valves in MANUAL.
ATC Dispatch an operator with a radio to place ATM Dump CNTRL valves on hand jack and fully open. (Refer to Alternate Shutdown (1203.002) Exhibit A).
Maintain SG press 1000 to 1040 psig using ATM Dump ISOL valves.
IA OPERATOR CUE :
Report as Unit 2 that the AAC Generator is not coming up to speed. Maintenance is in route.
Unit 2 will notify you when the AAC Generator is available.
CRS Performs step 2.F. for AAC Generator not available.
CRS F. IF AAC Gen is not available, THEN perform the following:
- 3) IF SG press associated with de-energized ATM Dump ISOL is >
1040 psig, THEN as time permits, dispatch an operator with a ATC radio to hand jack associated ATM Dump CNTRL to maintain SG press 1000 to 1040 psig (Refer to Alternate Shutdown 1203.002, Exhibit A).
Event 5, 6 & 7 Continued Page 18 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 5, 6 & 7 CONTINUED Event
Description:
A Loss of Offsite Power will occur resulting in an automatic reactor trip.
The #2 EDG will not auto start requiring the operators to manually start the EDG.
EFIC fails to Auto-actuate.
Time Position Applicants Actions or Behavior EVENT TERMINATION CRITERIA This event is complete when EFW has been manually actuated AND
- 2 EDG has been manually started AND Actions taken for AAC Generator unavailability have been performed OR As directed by the Lead Evaluator.
Page 19 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 8 Event
Description:
The #2 EDG will trip putting the plant into a blackout.
The Alternate AC Generator will become available.
Time Position Applicants Actions or Behavior ANY Recognize and report #2 EDG tripped.
50 TS TS 3.8.1 Condition E, 3.0.3 CRS Direct operations per 1202.008 Blackout procedure.
CRS 1. Record time of Blackout.
ATC (CRS may direct ATC to re-perform RT 5. RT 5 was performed during the Degraded Power event.)
IA OPERATOR CUE:
If called, U2 will report Maintenance is working on the ACC Generator.
- 3. Notify Unit 2 of need for AAC Generator (2K9) AND attempt to restore EDG using Annunciator K01 Corrective Action (1203.012A) and CRS Emergency Diesel Generator Operation (1104.036), while continuing with this procedure..
CRS Dispatch an operator to restore #2 EDG.
ATC 4. Check adequate SCM.
CRS 5. Manually isolate Letdown and RCP Seal Return as follows:
ATC A. Close Orifice Bypass (CV-1223).
B. Place RCP Seal Bleedoff (Alternate Path to Quench Tank)
BOP controls in CLOSE:
BOP SV-1270 BOP SV-1271 BOP SV-1272 BOP SV-1273 C. Dispatch an operator to manually close the following valves in UNPPR:
CRS Letdown Coolers Outlet (CV-1221)
RCP Bleedoff Normal Return (CV-1274)
EVENT 8 CONTINUED Page 20 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 8 CONTINUED Event
Description:
The #2 EDG will trip putting the plant into a blackout.
The Alternate AC Generator will become available.
Time Position Applicants Actions or Behavior
- 6. Actuate MSLI for both SGs.
ATC This was already performed in Degraded Power.
CRS 7. Verify the following handswitches in PULL-TO-LOCK:
ATC EFW Pump P-7B A1 and A2 feeder breakers:
- A-111
- A-112 BOP - A-113
- A-211
- A-212
- A-213 H1 and H2 feeder breakers:
- H-13
- H-14 BOP - H-15
- H-23
- H-24
- H-25 Condensate Pumps:
- P-2C ICW Pumps ATC - P-33A BOP - P-33B
- P-33C IA OPERATOR CUE:
Call as Unit 2 and report that the AAC Generator is running at normal speed and is ready for loading. Output breaker to Unit 1, 2A901 is CLOSED.
54 CRS Transition to step 3 of 1202.008 Blackout (floating step).
3.
A. IF AAC Gen becomes available, THEN energize a vital bus using CRS ES Electrical System Operation (1107.002), "Placing Alternate AC Generator on bus A3 (A4)" section.
EVENT 8 CONTINUED Page 21 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 8 CONTINUED Event
Description:
The #2 EDG will trip putting the plant into a blackout.
The Alternate AC Generator will become available.
Time Position Applicants Actions or Behavior Directs BOP to energize A3 or A4 using ES Electrical System Operation (1107.002), Alternate AC Generator Operation" section.
CRS (BOP-CT) CT criteria - The AAC generator should be placed in service within 10 minutes of regaining the AAC Generator.
EXAMINER NOTE:
The steps directly following this note are for energizing bus A3 from the AAC Generator. If A4 is being energized, skip this section and go to the A4 section.
- Energize A3 Bus from AAC Generator Performs actions of 1107.002 step 37.0, Placing Alternate AC BOP Generator (2K9) on Bus A3.
BOP 37.1 Place DG1 Output Breaker (A-308) in PULL-TO-LOCK.
BOP 37.2 Verify A1 to A3 Supply Breaker (A-309) open.
37.3 IF Alternate AC Generator is NOT supplying bus A4, THEN verify BOP A3-A4 Crosstie Breakers (A-310 and A-410) open.
37.4 Verify no bus A3 Lockout.
BOP A3 L.O. RELAY TRIP (K02B6) clear EXAMINER NOTE:
Step 37.5 has already been reported complete by Unit 2.
BOP 37.5 Request Unit 2 CRS/SM to perform the following:
BOP 37.5.1 Start Alternate AC Generator (2K9).
BOP 37.5.2 Close AAC Generator to A3/A4 (2A-901).
37.6 If ES has actuated, THEN momentarily depress ES Electrical BOP Alignment MAN PB on C18 (ES has not actuated).
37.7 Place A3-A4 Crosstie Breakers (A-310 and A-410) Synchronize BOP switch to ON.
37.8 IF an EFIC initiate signal is present AND starting of EFW Pump (P-BOP 7B) is NOT desired, THEN place EFW Pump (P-7B) handswitch in ATC PULL-TO-LOCK.
37.9 WHEN Unit 2 reports Alternate AC Generator is ready for loading, BOP THEN close A3-A4 Crosstie (A-310).
EVENT 8 CONTINUED Page 22 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 8 CONTINUED Event
Description:
The #2 EDG will trip putting the plant into a blackout.
The Alternate AC Generator will become available.
Time Position Applicants Actions or Behavior 37.10 Place A3-A4 Crosstie Breakers (A-310 and A-410) Synchronize BOP switch to OFF.
37.11 Coordinate with Unit 2 to ensure 2K9 is NOT overloaded when BOP starting loads on bus A3.
37.12 If desired, Then start Service Water Pump P-4A or B per Service BOP Water and Auxiliary Cooling System (1104.029) or applicable Emergency Operating Procedure.
Per step 3.B. of Blackout EOP, CRS GO TO 1202.007, "DEGRADED POWER" procedure.
- Energize A4 Bus from AAC Generator Performs actions of 1107.002 step 39.0, Placing Alternate AC BOP Generator (2K9) on Bus A4.
BOP 39.1 Place DG2 Output Breaker (A-408) in PULL-TO-LOCK.
BOP 39.2 Verify A2 to A4 Supply Breaker (A-409) open.
39.3 IF Alternate AC Generator is NOT supplying bus A3, THEN verify BOP A3-A4 Crosstie Breakers (A-310 and A-410) open.
39.4 Verify no bus A4 Lockout.
BOP A4 L.O. RELAY TRIP (K02B7) clear EXAMINER NOTE:
Step 39.5 has already been reported complete by Unit 2.
BOP 39.5 Request Unit 2 CRS/SM to perform the following:
BOP 39.5.1 Start Alternate AC Generator (2K9).
BOP 39.5.2 Close AAC Generator to A3/A4 (2A-901).
39.6 If ES has actuated, THEN momentarily depress ES Electrical BOP Alignment MAN PB on C16(ES has not actuated).
39.7 Place A3-A4 Crosstie Breakers (A-310 and A-410) Synchronize BOP switch to ON.
39.8 WHEN Unit 2 reports Alternate AC Generator is ready for loading, BOP THEN close A3-A4 Crosstie (A-410).
EVENT 8 CONTINUED Page 23 of 24
Appendix D Scenario Outline Op-Test No.: 2013-1 Scenario No.: 1 Event No.: 8 CONTINUED Event
Description:
The #2 EDG will trip putting the plant into a blackout.
The Alternate AC Generator will become available.
Time Position Applicants Actions or Behavior 39.9 Place A3-A4 Crosstie Breakers (A-310 and A-410) Synchronize BOP switch to OFF.
39.10 Coordinate with Unit 2 to ensure 2K9 is NOT overloaded when BOP starting loads on bus A4.
39.11 If desired, Then start Service Water Pump P-4B or C per Service BOP Water and Auxiliary Cooling System (1104.029) or applicable Emergency Operating Procedure.
Per step 3.B. of Blackout EOP, CRS GO TO 1202.007, "DEGRADED POWER" procedure.
EVENT TERMINATION CRITERIA This scenario is complete when A3 or A4 is powered from the AAC Generator OR CRS transitions back to 1202.007 Degraded Power OR As directed by the Lead Evaluator.
END OF SCENARIO Page 24 of 24
Appendix D Scenario Outline Form ES-D-1 Facility: ANO-1 Scenario No.: 2-R1 Op-Test No.: 2013-1 Examiners: ____________________________ Operators: _____________________________
Initial Conditions:
- 12 EFPD BOL
- Reactor Power ~2%
- Group 6 Control Rods ~78% withdrawn, Group 7, 0% withdrawn.
- Ready to place A MFW pump in service per step 17.16 of 1102.002 Plant Startup procedure.
Turnover:
- Reactor Power is ~2%.
- Ready to place the A MFW pump is service and secure P-75 AFW pump.
- Commence raising power when A MFW pump is in service.
- A 3rd RO is performing activities not related to placing the MFW pump in service and raising power.
Event Event Event Malf. No.
No. Type* Description N-(BOP) Place A MFW Pump in service and secure P-75 Aux FW 1 N/A N-(SRO) pump.
N-(BOP) 2 N/A N-(SRO) Reset anticipatory trip (ARTS) for the A MFW pump.
N/A Commence power escalation to ~7% power.
C-(BOP) Group 7 rods do not sequence on resulting in no overlap RD271 C-(SRO) between groups 6 & 7.
TS C-(BOP) 5 CV6604 Gland Seal regulator fails closed.
C-(SRO)
I-(ATC) 6 TR049 I-(SRO) Controlling Pressurizer level instrument fails low.
TS ED452 C-(ATC)
Loss of ICS power requiring Manual Reactor Trip and EFW C-(SRO)
Actuation.
M-(ALL) 7&8 C-(ATC)
CV2648 C-(SRO) Failed EFW control valves cause overcooling.
CV2626 TS M-(ALL) LOCA resulting in ESAS actuation and LOSM RC005 CT (Trip all RCPs within 2 minutes of LOSM).
9 & 10 C-(BOP)
ES660 C-(SRO) ES Standby HPI pump fails to auto-start.
TS
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 1 of 19
Appendix D Scenario Outline Form ES-D-1 SCENARIO 2 OBJECTIVES
- 1. Evaluate individual ability to Place the A MFW pump in service and stop P-75 Aux Feedwater Pump per 1102.002, Plant Startup procedure.
- 3. Evaluate individual ability to raise reactor power from ~2% to ~7%.
- 4. Evaluate individual ability to recognize and respond to failure to have proper overlap between Group 6 and Group 7 control rods.
- 5. Evaluate individual ability to recognize and respond to a failed gland seal regulator valve.
- 6. Evaluate individual ability to recognize and respond to a failed controlling pressurizer level instrument.
- 7. Evaluate individual ability to recognize and respond to a failure of the Control Rod Sequencing circuit.
- 8. Evaluate individual ability to recognize and respond to a Loss of ICS power.
- 9. Evaluate individual ability to recognize and respond to failed EFW control valves resulting in overfeed of the affected steam generator.
- 11. Evaluate individual ability to recognize and respond to a Loss of Subcooling Margin requiring all RCPs to be tripped within 2 minutes.
- 12. Evaluate individual ability to recognize and respond to the ES Standby HPI pump failure to auto-start.
Page 2 of 19
Appendix D Scenario Outline Form ES-D-1 SCENARIO 2 NARRATIVE The crew will be allowed to brief placing the A MFW pump in service and the ensuing power escalation.
The crew will assume the watch with the plant at ~2% power.
The CRS will direct placing the A MFW pump in service as directed in 1102.002 Plant Startup procedure step 17.16 (1106.016, Sec. 15.0) When the A MFW pump is supplying feedwater to the steam generators, the CRS will direct P-75, Aux. FW pump be secured.
The CRS will then direct that the Anticipatory Reactor Trips (ARTS) be reset in RPS for the A MFW pump. Failure to perform the ARTS reset will result in a reactor trip when reactor power exceeds 7% power. (CT) ARTS must be reset prior exceeding 7% NI Power.
When ARTS is reset, the CRS will then direct that plant power will be raised to ~7% power.
As reactor power is raised, a failure of the group 7 Control Rod Sequencing circuit will result in group 7 Control Rods not withdrawing when group 6 Control Rods are between 75% and 85%.
This should be recognized by the ATC and/or BOP and the CRS should be notified. The CRS should direct that rod withdrawal be stopped and then reference Tech Specs. (TS)
After Control Rod withdrawal has been stopped, and the CRS has referenced Tech Specs, the gland seal regulator CV-6604 will fail in the closed direction resulting in lowering gland seal pressure and gland seal alarms on annunciator K05. The operator will restore gland seal pressure to normal by throttling opening the gland seal regulator bypass, CV-6606 as directed in the K05 annunciator corrective action procedure.
When Gland Seal Header Pressure has been restored, the controlling pressurizer level instrument will fail low causing the pressurizer level control valve to open. 1203.015, Pressurizer Systems Failure, Section 4 -- Pressurizer Level Indication Malfunction, will be entered to address the failed instrument. The alternate (valid) instrument will be selected and pressurizer level will be allowed to return to normal. TS LCO 3.3.15 will be entered due to the failed instrument. Additionally TS 3.4.1 for RCS Steady State Pressure Limits will be referenced and entered if appropriate. (TS)
A loss of ICS power will occur which will require the CRS to enter 1203.001, ICS Abnormal Ops AOP. The CRS will direct a manual reactor trip. The crew will perform the reactor trip immediate actions and then the CRS will direct that EFW be actuated.
EFW control valve CV-2648 and EFW isolation valve CV-2626 are failed open resulting in an over-feed of the B Steam Generator and an overcooling condition to exist. The Overcooling EOP will be entered and CRS will direct that the failed flow path be isolated. When it is determined that the EFW valves are failed open, the Waste Control Operator (WCO) may be dispatched to attempt to manually close CV-2626 to stop the over-feeding of EFW and thus terminate the Overcooling. The CRS may alternately direct that the affected EFW pump, P-7B (electric driven) be secured to terminate the overcooling. The remaining EFW pump, P-7A (steam driven) will remain in service to provide feedwater to both steam generators. (TS) When the Overcooling is terminated, the A & B Atmospheric Dump Valves will be operated in manual to stabilize RCS temperature as the Turbine Bypass Valves are unavailable due to the loss of ICS power.
Page 3 of 19
Appendix D Scenario Outline Form ES-D-1 CONTINUED ON NEXT PAGE SCENARIO 2 NARRATIVE (cont.)
An intermediate sized loss of coolant accident will occur causing a loss of RCS pressure and an automatic actuation of ESAS to occur. The loss of RCS pressure will also result in a loss of adequate subcooling margin and will require that all reactor coolant pumps be tripped within 2 minutes of the loss of adequate subcooling margin. (CT) Reactor Coolant Pumps must be tripped within 2 minutes of loss of Subcooling margin. (TCOA). 1202.002, the Loss of Subcooling Margin EOP will be entered and actions will be directed to attempt to regain subcooling margin (i.e. full HPI, EFW selected to reflux boiling).
The ES Standby HPI pump will not auto-start when ES is actuated and must be started manually to provide full HPI flow. Full HPI flow is required for a loss of subcooling margin. (TS)
(CT) HPI FLOW CRITERIA:> 200 gpm/pump as indicated on FIRS-1209 (C18) and FIRS-1228 (C16)
The scenario can be terminated when the ES HPI pump has been started and full HPI is being injected in the core.
Page 4 of 19
Appendix D Scenario Outline Form ES-D-1 Simulator Instructions for Scenario 2 Recall IC 286 Verify the Following:
- Tags correct on HPI pumps (P36A OP, P36B STBY, P36C ES)
- Marked-up copies of required Startup and Feedwater procedures available to provide the CRS.
- Copy of reactivity plan available.
- White board updated Insert override DI_RPSB4 to TRUE on event 1 delete in 5 Reset ARTS for B RPS Channel Insert override DI_RPSC4 to TRUE on event 1 delete in 5 Reset ARTS for C RPS Channel Insert override DI_RPSD4 to TRUE on event 1 delete in 5 Reset ARTS for D RPS Channel Insert malfunction RD271 Loss of Sequence Enable Insert malfunction CV6604 to 0.05000 in 10 on event 2 GS Supply Regulator fails low Insert malfunction TR049 to 0 in 60 on event 3 Fail controlling PZR level low Insert malfunction ED452 on event 4 Loss of ICS Power Insert malfunction RC005 to 0.05000 on event 5 RCS LOCA (Intermediate sized)
Insert malfunction CV2648 to 1.00000 EFW control valve (P-7B to SG-B) failed open Insert malfunction CV2626 to 1.00000 EFW isolation valve (P-7B to SG-B) failed open Insert malfunction ES660 HPI pump P-36C will not autostart Event Value/Ramp Time Malf. No. Event Description No. Time Place A MFW Pump in service and secure P-1 0 N/A N/A 75 Aux FW pump starting at step 17.16 of 1102.002.
Trigger 1 DI_RPSB4 TRUE 2 10 Reset ARTs for the A MFW pump. (CT)
DI_RPSC4 TRUE DI_RPSD4 TRUE N/A N/A Commence power escalation to ~7%.
3&4 15 Group 7 rods do not sequence on resulting in RD271 Active no overlap between groups 6 & 7. (TS)
Trigger 2 5 30 0.05/10sec Gland Seal Pressure regulator fails closed.
CV6604 Trigger 3 Controlling Pressurizer Level instrument fails 6 40 0/60sec TR049 low. (TS)
Trigger 4 Loss of ICS power requiring manual reactor trip 50 Active ED452 and initiation of EFW.
7&8 CV2648 1/ EFW from P-7B to SG-B control valves are Initial CV2626 N/A failed open.(TS)
Trigger 5 Intermediate sized RCS LOCA resulting in 60 0.05/0 RC005 LOSM requiring trip of all RCPs. (CT) 9 & 10 Initial ES660 Active ES Standby HPI pump will not autostart. (TS)
Page 5 of 19
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 1 Event
Description:
Place A MFW Pump in service and secure P-75 Aux FW pump.
Time Position Applicants Actions or Behavior EXAMINER NOTE:
The CRS has been informed that any steps in the startup procedure that direct action outside of placing the A MFW pump in service and raising power to 10 -12% will be performed by another operator.
Directs actions per 1102.002 plant startup procedure starting at step T=0 CRS 17.16, WHEN the second condensate pump is running, THEN perform the following in the order listed:
Directs the BOP:
17.16.1 Place the A MFW pump in service and stop the Auxiliary CRS Feedwater Pump per 1106.016, Placing MFWP Into Service section (Section 15.0).
Performs actions of 1106.016, Condensate, Feedwater and Steam BOP System Operation, step 15.0, Placing MFWPs Into Service.
15.1 Initial conditions:
At least 1 MFWP (P-1A) at minimum speed.
BOP Aux FW Pump P-75 supplying feedwater.
2 Condensate Pumps running EXAMINER NOTE:
The Low Load Valves are already closed for this situation. The operators should monitor Startup Valve position to verify that the MFWP is feeding. These positions can be monitored at the Startup Valve Hand/Auto stations on C03 or on the computer.
15.2 To ensure MFWP is supplying feedwater, raise desired MFWP speed until the Startup Control Valves or Low Load Control Valves start to close.
BOP Startup Valve Loop A (CV-2623)
Low Load Valve Loop A (CV-2622)
Startup Valve Loop B (CV-2673)
Low Load Valve Loop B (CV-2672)
BOP 15.3 Stop P-75 EVENT TERMINATION CRITERIA This event is complete when the A MFW pump is supplying feedwater and P-75 has been secured OR As directed by the Lead Evaluator.
Page 6 of 19
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 2 Event
Description:
Reset ARTS for the A MFW pump.
Time Position Applicants Actions or Behavior EXAMINER NOTE:
The CRS has been informed that any steps in the startup procedure that direct action outside of placing the A MFW pump in service and raising power to 10 -12% will be performed by another operator.
15.4 Reset RPS trips per Plant Startup (1102.002), Attachment E, T=10 BOP "Anticipatory Reactor Trip System (ARTS) Reset" for the first MFWP.
EXAMINER NOTE:
Channel A of RPS is the only channel of RPS that is fully simulated. Channels B, C & D controls are on panels within the A RPS cabinet. Not all indications are included on these panels.
Performs actions of 1102.002 Att. E, Anticipatory Reactor Trip (ARTS)
BOP Reset, Step 1.0, WHEN first Main Feedwater Pump is placed into service, THEN perform the following to reset RPS ARTS trip:
BOP 1.1 In RPS Channel A Cabinet (C41) perform the following:
EXAMINER NOTE:
1102.002, Attachment E requires a concurrent and an independent verifier for performing the steps in RPS for resetting ARTS.
1.1.1 Obtain SRO/RO Concurrent Verification of steps in this BOP subsection.
EXAMINER CUE:
The examiner will inform the BOP that the concurrent verification will be simulated.
1.1.2 Depress the test switch labeled RESET on the contact CT BOP buffer lower module for the started MFW pump. (A MFWP) 1.1.3 Verify that the two red lights on the contact buffer change state BOP (Top ON, Bottom OFF).
1.1.4 Verify white light MFWP A (B) TRIPPED (for the started BOP MFWP) goes dim. (On Contact Monitor)
EXAMINER CUE:
When the ARTS for the A MFWP has been reset, notify the BOP that another operator has completed resetting ARTS in the remaining RPS channels. Independent Verifications have been completed.
EVENT 2 CONTINUED Page 7 of 19
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 2 CONTINUED Event
Description:
Reset ARTS for the A MFW pump.
Time Position Applicants Actions or Behavior IA OPERTOR CUE:
When the ARTS for the A MFWP has been reset, reset ARTS on the remaining Channels by activating Trigger 1 Notifies the CRS that ARTS is reset for the A MFW pump and that BOP independent verifications are complete.
BOP Continues actions of 1106.016 step 15.0, Placing MFWPs Into Service.
15.5 Close Aux FW Pump Recirc to E-11A (FW-1).
BOP (This action directed to the AO).
EVENT TERMINATION CRITERIA This event is complete when ARTS has been reset for the A MFW Pump.
OR As directed by the Lead Evaluator.
Page 8 of 19
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 3 & 4 Event
Description:
Commence power escalation to ~7% power.
Group 7 rods do not sequence on resulting in no overlap between groups 6 & 7.
Time Position Applicants Actions or Behavior T=15 CRS Performs steps of 1102.002, Plant Startup, starting at step 17.16.3.
EXAMINER NOTE:
The CRS has been informed that any steps in the startup procedure that direct action outside of placing the A MFW pump in service and raising power to 10 -12% will be performed by another operator.
17.16.3 With a MFWP H/A station in HAND and both main feedwater block CRS valves closed, adjust MFWP speed to maintain discharge pressure between 1025 and 1075 psig.
ATC/ Adjusts A MFW pump speed to achieve a discharge pressure between BOP 1025 and 1075 psig.
CRS 17.16.4 Begin reactor power escalation to ~7%.
Directs ATC to commence raising reactor power. CRS should provide a rate CRS of change.
Begins raising reactor power by withdrawing control rods in sequence using ATC the Diamond panel.
References steps in 1105.009, CRS System Operation Procedure, step ATC 11.7, Regulating Group Sequential Withdrawal.
11.7.3 Move manual command switch to WITHDRAW as needed for incremental rod withdrawal as required by Approach to Criticality ATC 1102.008 (or other approved procedure) AND continue.
(This is a continuous action step).
CRS Declares entry into Mode 1 when reactor power reaches 5%.
11.7.7 WHEN Group 6 is withdrawn 75% to 85% (25% to 15% overlap)
ATC THEN observe Group 7 starts to withdraw.
ATC Recognizes group 6/7 overlap outside limits and reports it to the CRS.
CRS Directs ATC to stop power escalation.
EVENT 3 & 4 CONTINUED Page 9 of 19
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 3 & 4 Event
Description:
Commence power escalation to ~7% power.
Group 7 rods do not sequence on resulting in no overlap between groups 6 & 7.
Time Position Applicants Actions or Behavior References Technical Specifications TS 3.2.1 Regulating Rod Insertion Limits Condition C, Regulating rod groups sequence or overlap requirements not CRS met.
TS Restore regulating rod groups to within limits in 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> or be in Mode 3 in 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
COLR limit: Operating rod group overlap is 20% +/- 5% between two sequential groups, except for physics tests.
IA OPERATOR CUE:
If Reactor Engineering is contacted, tell the CRS to maintain current rod configuration until notified.
EVALUATOR NOTE:
The following steps are not procedurally required therefore the CRS may not direct it to be performed to exit the TS condition.
Directs the ATC to insert Group 6 Control Rods (reduce power) to return the CRS Control Rods to <85% withdrawn to return to within tech spec limits.
Inserts Group 6 Control Rods by placing the Tee-Handle on the Diamond ATC Panel to insert.
ATC Notifies the CRS when Group 6 Control Rods are <85% withdrawn.
EVENT TERMINATION CRITERIA This event is complete when the power escalation has been stopped AND The CRS has entered the appropriate TS OR As directed by the Lead Evaluator.
Page 10 of 19
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 5 Event
Description:
Gland Seal Pressure regulator fails closed.
Time Position Applicants Actions or Behavior Announces GS Pressure Lo alarms on #3, #4, #5 & #6 bearings (K05-B4, T=30 ATC C4, D4 & E4).
ALL Determine that Gland Seal Steam Header Pressure is low (<75psig).
ATC Observes and reports that condenser vacuum is slowly lowering.
CRS Directs the BOP to use the ACA for K05 to address the Gland Seal alarms.
References 1203.12D, Annunciator K05 Corrective Actions for K05-B4, BOP C4, D4, or E4.
- 1. IF Gland Seal Steam Header Press <75 psig, THEN slowly open Gland BOP Sealing Steam Main Regulator Bypass (CV-6606) located on panel C12.
- 2. Check the status of the following alarms:
BOP GS PRESS #5 BRG LO (K05-D4)
ATC Reports that all Gland Seal Low Pressure alarms are clear.
BOP Adjusts CV-6606 to maintain GS Header Pressure ~150 psig.
EVENT TERMINATION CRITERIA This event is complete Gland Seal Header Pressure has been restored and Condenser Vacuum is recovering OR As directed by the Lead Evaluator Page 11 of 19
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 6 Event
Description:
Controlling Pressurizer level instrument fails low.
Time Position Applicants Actions or Behavior T=40 ATC Announces Pressurizer Level Lo alarm (K09-C3).
ATC/
Determines that LRS-1001 is failing low.
BOP Enters 1203.015, Pressurizer Systems Failure AOP and goes to section 4, CRS PRESSURIZER LEVEL INDICATION MALFUNCTION.
- 1. IF all Pressurizer level indication is lost, THEN GO TO "Loss of All CRS Pressurizer Level Indication" section of this procedure.
- 2. IF one level indicator differs from the rest, THEN assume that indicator CRS invalid AND GO TO step 5.
- 3. WHEN validity of transmitters and indicators is determined, THEN ensure CRS Pressurizer Level Transmitter hand switch is positioned to the valid transmitter.
CRS Directs the ATC to select LT-1002 for control.
ATC Selects HS-1002 on C04 to the LT-1002 position.
Reports Pressurizer Level Lo alarm is clear and that CV-1235 makeup valve ATC is positioning to restore pressurizer level.
- 6. IF invalid instrument indication is >16" from other level indications, THEN CRS instrument is inoperable. Refer to TS 3.3.15.
CRS Declares LT-1001 Pressurizer Level instrument inoperable per TS 3.3.15 TS and enters 30 day required action.
CRS 7. Verify proportional heater control in automatic.
Places the proportional heater control station in AUTO at PIC-1004 on C04 if ATC not in AUTO.
- 8. Refer to RCS Pressure, Temperature and Flow DNB Surveillance Limits CRS of the ANO1 COLR (TS 3.4.1).
Refers to the COLR per TS 3.4.1 to determine if steady state RCS pressure CRS limits have been exceeded. 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> to restore if exceeded.
TS (Minimum RCS Pressure w/ 4 RCPs, 2082.2psig)
EXAMINER NOTE:
This event is complete when LT-1002 has been selected for control and required TS have been applied, OR As directed by the Lead Evaluator Page 12 of 19
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 7 & 8 Event
Description:
Loss of ICS power requiring manual reactor trip and initiation of EFW.
EFW from P-7B to SG-B control valves are failed open.
Time Position Applicants Actions or Behavior T=50 ATC Announces ICS/AUX SYS POWER SUPPLY TROUBLE alarm, (K07-A4).
Observes ICS Power supply status lights on C13 and light indications on ALL ICS stations and determines there is a loss of all ICS power.
EXAMINER NOTE:
The CRS may direct the ATC to trip the reactor prior to entering the ICS Abnormal Operation procedure. This is allowed per the note at the front of the procedure.
Enters 1203.001, Section 11, Loss of Either ICS DC Power or Both ICS DC CRS and AC Power.
Directs the ATC to trip the reactor and perform immediate actions of CRS 1202.001 Reactor Trip EOP.
ATC 1. Trip reactor.
- 2. While continuing with this section, refer to Emergency Operating CRS Procedure (1202.001).
CRS Directs actions of 1202.001, Reactor Trip.
- 1. Pushes the Rx Trip push button and verifies all control rods are inserted ATC and reactor power is dropping.
EXAMINER NOTE:
The Turbine is already tripped as part of this scenario.
- 2. Pushes the Turbine Trip push button and verifies all throttle and governor BOP valves are closed.
ATC/
- 3. Verifies adequate Subcooling margin.
BOP EXAMINER NOTE:
The CRS may continue in 1202.001 Reactor Trip until step 13 is reached. It is acceptable to perform the actions of 1203.001 Section 11 after immediate actions are performed.
- 4. Advise Shift Manager to implement Emergency Action Level Classification CRS (1903.010).
ATC 5. Verify Orifice Bypass (CV-1223) demand adjusted to zero.
BOP 6. Open BWST T3 Outlet (CV-1407 or CV-1408) to operating HPI pump.
Event 7 & 8 Continued Page 13 of 19
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 7 & 8 CONTINUED Event
Description:
Loss of ICS power requiring manual reactor trip and initiation of EFW.
EFW from P-7B to SG-B control valves are failed open.
Time Position Applicants Actions or Behavior
- 7. IF Emergency Boration is not in progress, THEN adjust Pressurizer Level ATC Control setpoint to 100".
ATC 8. Control RCS press within limits of Figure 3 (RT-14).
BOP 9. Check for proper electrical response (RT-19).
ATC 10. Check OP HPI pump supplying normal Makeup and Seal Injection.
ATC 11. Check both SG levels remain 410".
ATC 12. Check Instrument Air Header Press > 75 psig.
ATC 13. Check NNI and ICS power available (RT-20).
A. IF any NNI AC or DC Instrument Power Supply is lost, THEN perform Loss of NNI Power (1203.047) in conjunction with this CRS procedure.
(Not Applicable)
B. IF any ICS AC or DC Instrument Power Supply is lost, THEN CRS perform the following:
- 2) Trip both Main Feed Pumps:
ATC A Main Feed Pump BOP B Main Feed Pump
CRS Transitions back to 1203.001 Section 11, step 3.
- 3. Trip main and auxiliary feedwater pumps as applicable:
ATC/ Main Feedwater Pump (P-1A)
BOP Main Feedwater Pump (P-1B)
Auxiliary Feedwater Pump (P-75)
ATC 4. Manually actuate EFW AND perform RT-5.
EVENT 7 & 8 CONTINUED Page 14 of 19
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 7 & 8 CONTINUED Event
Description:
Loss of ICS power requiring manual reactor trip and initiation of EFW.
EFW from P-7B to SG-B control valves are failed open.
Time Position Applicants Actions or Behavior
- 5. Open both ATM Dump Isols:
ATC SG-A ATM Dump Isol (CV-2676)
SG-B ATM Dump Isol (CV-2619)
EXAMINER NOTE:
Due to EFW feeding, SG pressures may be <1000 psig with the ATM DUMP valves closed.
- 7. WHEN plant conditions have stabilized, THEN determine cause of ICS CRS power failure and initiate corrective action.
EXAMINER NOTE:
Steps to restore power to ICS may not be performed if the CRS stays in the Reactor Trip procedure.
EXAMINER NOTE:
Breaker panel, RS-3 does not actually exist in the simulator. There is a picture of the panel in the back of the simulator in the approximate location of the panel in the plant.
- 8. WHEN cause of ICS power failure is corrected such that power can be CRS restored to ICS, THEN perform the following system checks:
EXAMINER CUE:
Notify the BOP that RS-3 Breaker 4 is in mid-position.
CRS A. Verify the following breakers closed:
BOP At RS3, ICS Pnl C46 (breaker #4)
EXAMINER CUE:
If the BOP attempts to reset the breaker, notify the operator that RS-3 Breaker 4 has returned to the mid-position.
The BOP will determine the status of RS-3, Breaker 4 and report to the CRS BOP that the breaker is tripped open.
At Y02, To Sola Trans. Bypass Switch XY-234 (to ICS Y CRS Bus) (breaker #34)
CRS Notifies the AO to determine the status Y02 Breaker 34.
Event 7 & 8 Continued Page 15 of 19
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 7 & 8 CONTINUED Event
Description:
Loss of ICS power requiring manual reactor trip and initiation of EFW.
EFW from P-7B to SG-B control valves are failed open.
Time Position Applicants Actions or Behavior EXAMINER NOTE:
Approximately 2 minutes after the AO is directed to determine the status of Y02, Breaker 34, report to the control room that Y02, Breaker 34 is tripped open.
Reports that CV-2648, EFW flow control valve is full open causing rising B ATC SG level and cooldown of the RCS EXAMINER NOTE:
The Overcooling EOP will not be entered until SG pressure reaches 900 psig or SG level approaches 410. Direction in RT-5 will be utilized to control/isolate EFW as required.
ATC Performs actions of RT-5 Step 4.A.
A. Verify EFW CNTRL valves operate to establish and maintain applicable ATC SG level band per Table 1.
- 1) IF EFW flow is less than adequate OR EFW flow is excessive, THEN control EFW to applicable SG in HAND as necessary to ensure the following:
Maintain sufficient EFW flow to prevent rise in CET temp.
ATC Maintain continuous EFW flow until applicable level band is reached.
Maintain sufficient EFW flow to ensure SG level is either stable OR rising until applicable level band is reached.
ATC Takes CV-2648 to HAND and attempts to close.
Attempts to close CV-2626 and determines that the valve is failed and will ATC not close.
Notifies the CRS that both CV-2626 and CV-2648 are failed open causing ATC an overfeed of the B SG.
EXAMINER NOTE:
The CRS may direct the ATC to secure P-7B and/or direct the WCO to close CV-2626 manually to stop the overfeed condition. It is acceptable to secure EFW feed from P-7B because P-7A is running and maintaining SG levels.
Directs one or both of the following:
CRS Stop P-7B EFW pump by placing it in Pull-to-Lock Direct the WCO to manually close CV-2626 locally Event 7 & 8 Continued Page 16 of 19
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 7 & 8 CONTINUED Event
Description:
Loss of ICS power requiring manual reactor trip and initiation of EFW.
EFW from P-7B to SG-B control valves are failed open.
IA OPERATOR CUE:
If the WCO is directed to close CV-2626 locally, wait approximately 2 minutes and then close CV-2626 over a 60 second period. Notify the control room when CV-2626 has been closed.
If directed, places P-7B in Pull-to-Lock and verifies that the overfeed is ATC terminated.
Directs the ATC to stop P-7B EFW pump by placing it in Pull-to-Lock OR CRS directs the WCO to manually close CV-2626 locally.
EVENT TERMINATION CRITERIA This event is complete when the EFW overfeed has been terminated OR As directed by the Lead Evaluator.
Page 17 of 19
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 9 & 10 Event
Description:
Intermediate sized RCS LOCA resulting in LOSM requiring trip of all RCPs.
ES Standby HPI pump will not autostart.
Time Position Applicants Actions or Behavior T=60 ATC Announces RCS pressure and pressurizer level lowering.
ATC Announces actuation of ESAS channels 1 through 4.
ALL Announce Loss of Subcooling Margin (LOSM).
EXAMINER NOTE:
The CRS may enter the ESAS EOP initially but will be directed back to the LOSM EOP from the ESAS EOP.
CRS Directs actions per 1202.002, Loss of Subcooling Margin EOP.
EXAMINER NOTE:
Time since Subcooling Margin has been lost is displayed at the bottom of the ICCMDS monitor at the top of C19
- 1. Check elapsed time since loss of adequate SCM AND perform the CRS following:
A. IF 2 minutes have elapsed, THEN trip all RCPs:
P-32A CRS P-32B P-32C P-32D CT BOP Trips all RCPs within 2 minutes of LOSM.
CRS B. Initiate full HPI (RT-3)
- 1) IF Makeup Tank level drops below 18", THEN close Makeup Tank ATC Outlet (CV-1275).
EXAMINER NOTE:
ESAS channels 1 & 2 result in full HPI. Actuation of ESAS is verified by RT-10.
ATC C. Verify proper EFW actuation and control (RT-5).
ATC Selects Reflux Boiling setpoint for EFW on C09 (per RT-5).
EVENT 9 & 10 CONTINUED Page 18 of 19
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 2 Event No.: 9 & 10 CONTINUED Event
Description:
Intermediate sized RCS LOCA resulting in LOSM requiring trip of all RCPs.
ES Standby HPI pump will not autostart.
Time Position Applicants Actions or Behavior
ATC A Main Feed Pump B Main Feed Pump CRS 3. Check ESAS ACTUATION alarms clear on K11.
BOP 3. (Contengency) Verify proper ESAS actuation (RT-10).
BOP Commences performance of RT-10.
Recognizes failure of the ES HPI pump (P-36C) to start and reports it to the BOP CRS.
EXAMINER NOTE:
The CRS may send an AO to check for any problems at the HPI pump breaker. If directed, wait approximately 2 minutes and report there are no drop flags and nothing abnormal at the HPI Pump breaker.
CRS Directs the BOP to start the ES HPI pump (P-36C).
If ES signal to P-36C is overridden (MAN), THEN start P-36C Aux. Oil Pump BOP P-64C by placing HS-1294 (C16) to start and verify that P-64C starts.
Starts the ES HPI pump by placing the P-36C (HS-1243) handswitch in START.
CT BOP HPI FLOW CRITERIA:> 200 gpm/pump as indicated on FIRS-1209 (C18) and FIRS-1228 (C16 BOP Verifies proper flow from P-36C HPI pump by observing flow on FIRS-1228.
EVENT TERMINATION CRITERIA This event is complete when P-36C ES HPI pump is running with full HPI being injected into the core OR As directed by the Lead Evaluator.
END OF SCENARIO Page 19 of 19
Appendix D Scenario Outline Form ES-D-1 Facility: ANO-1 Scenario No.: 3-R1 Op-Test No.: 2013-1 Examiners: ____________________________ Operators: _____________________________
Initial Conditions:
- 100% Power.
- P-4A Service Water Pump out of service for motor replacement.
- RPS is failed.
- Rx Trip pushbutton on C03 is failed
- A CFT Low Pressure Alarm K10-A5 in due to low pressure on A CFT Turnover:
- P-4A Service Water Pump out of service for motor replacement.
- Add N2 to A CFT to ~585# per 1104.001 per step 11.0.
Event Event Event Malf. No.
No. Type* Description N-(BOP) 1 N/A Add N2 to A CFT to raise pressure to ~585#.
N-(SRO)
WCO reports broken oil sight glass on P-7A EFW Pump 2 N/A TS outboard pump bearing.
FW086 N/A P-8A heater drain pump winding failure and trip.
3 R-(ATC)
N/A Power Reduction.
N-(SRO)
C-(BOP)
Spurious actuation of ESAS channel 8 resulting in actuation of 4 ES258 C-(SRO)
Reactor Building Spray.
TS I-(ATC) 5 TR580 I-(BOP) Controlling Header Pressure fails low.
I-(SRO)
CO_P14B Operating EH pump trips.
CO_P14A C-(BOP)
Turbine trip >43%.
DI_ICC0020 C-(ATC)
RP246,7,8,9 RPS is failed.
6&7 C-(SRO)
TS DI_ICC0020 C-(ATC) C03 manual trip pushbutton failed.
TS M-(ALL) Manual Reactor Trip.
CT M-(ALL)
RC002 TS ~150 GPM tube leak in the B SG.
8&9 CT N/A N-(ATC) Plant cooldown and depressurization.
10 CV061 C-(ALL) Operating HPI Pump trips.
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 1 of 27
Appendix D Scenario Outline Form ES-D-1 SCENARIO 3 OBJECTIVES
- 1) Evaluate individual ability to pressurize a Core Flood Tank per 1104.001 step 11.0 for adding N2 to the CFT.
- 2) Evaluate individual ability to assess operability of P-7A EFW pump.
- 3) Evaluate individual ability to recognize and respond to a heater drain pump trip.
- 4) Evaluate individual ability to perform a rapid plant power reduction.
- 5) Evaluate individual ability to recognize and respond to a spurious ESAS channel 8 actuation.
- 6) Evaluate individual ability to recognize and respond to a turbine header pressure instrument failing low.
- 7) Evaluate individual ability to recognize and respond to the loss of the operating EH oil pump and resultant turbine trip.
- 8) Evaluate individual ability to recognize and respond to a reactor protection system failure to complete an automatic trip.
- 9) Evaluate individual ability to recognize and respond to a steam generator tube leak.
- 10) Evaluate individual ability to commence a reactor coolant system cool down and depressurization.
- 11) Evaluate individual ability to recognize and respond to the operating HPI pump trip.
Page 2 of 27
Appendix D Scenario Outline Form ES-D-1 SCENARIO 3 NARRATIVE The crew will be allowed to brief adding N2 to the A CFT prior to entering the control room.
The crew will assume the watch with the plant at 100% power. P-4A SW pump is out of service for overhaul.
The CRS will direct adding N2 to the A CFT as soon as they have responsibility for the plant.
The CBO will perform 1104.001 Core Flood System Operating Procedure to raise CFT pressure
~10 psig.
The WCO will call in to the control room and report that the outboard pump bearing oil sightglass on P-7A EFW pump is broken and all the oil is on the floor. P-7A will be declared inoperable and maintenance should be contacted for repairs. (SRO-C) TS P8A heater drain pump will experience a winding failure causing a high temperature alarm and P8A trip (SRO-C) (BOP-C). The CRS should reference 1203.012E Annunciator Corrective Action P8A/P8B FLOW LO and CONDENSATE PUMP AUTOSTART.
A plant power reduction is required to maintain MFW pump suction pressure and limit HD tank level. The CRS should direct the power reduction per 1203.045 Rapid Plant Shutdown. (ATC-R)
(SRO-N)
After the power reduction, a spurious actuation of ESAS channel 8 will occur which will start P-35B RB Spray Pump and open RB Spray block valve CV-2400. The CRS will enter 1105.003, ENGINEERED SAFEGUARDS ACTUATION SYSTEM operating procedure and perform step 14.0 for ESAS Operation After Spurious or Inadvertent Actuation. The crew will validate that there is no valid signal for actuation and P-35B will be overridden and stopped and CV-2400 will be overridden and closed to prevent/stop injecting spray fluid into the reactor building. The CRS will enter tech specs for inoperability of ESAS features and the Spray pump and block valve.
(BOP-C) (SRO-C) (TS)
The controlling Turbine Header Pressure instrument will fail low. (SRO-C) (ATC-C) (BOP-C)
This will result in the turbine lowering demand to raise header pressure. The reactor and feedwater will rise as a result of the header pressure error. A SASS mismatch alarm will be received. The CRS will direct operations per 1203.012F Annunciator Corrective actions for SASS mismatch alarm and 1203.001 ICS Abnormal Operation. The crew should verify the turbine in manual and control SG/RX master and both turbine bypass valves in manual. Once the plant is stable the crew will verify the alternate instrument is good and select the good instrument on C04. The crew should return ICS to automatic.
After the power reduction the operating EH oil pump will trip. The standby EH oil pump will not start. (BOP-C). The loss of both EH pumps will result in a spurious turbine trip. (Crew may complete a manual RX trip prior to the turbine trip) The reactor will fail to trip do to a failure of RPS (ATC-C) (TS). The manual RX trip pushbutton is failed. (ATC-C) The ATC should manually trip the reactor using the CRD supply breakers. (ATC-CT) (ATC-M) (BOP-M) (SRO-M)
TS 3.3.1 Condition C TS 3.3.2 Condition A CT criteria - The reactor should be manually tripped before the pressurizer goes solid.
A ~150 gpm tube leak will occur in the B SG. (ATC-M) (BOP-M) (SRO-M) (TS) The CRS should direct operation per 1202.006 Tube Rupture. The leak will be large enough to require HPI be initiated. (BOP-CT) An RCS depressurization and cooldown should be started. (ATC-N)
Page 3 of 27
Appendix D Scenario Outline Form ES-D-1 TS 3.4.13 Condition B CT criteria - HPI should be initiated before SCM is lost.
The Operating HPI pump breaker trips due to a motor fault. (SRO-C) (ATC-C) (BOP-C) The CRS should direct operations per 1203.026 Loss of Reactor Coolant Makeup section 1 Loss of HPI Pump. The crew should diagnose the pump trip as a breaker fault and start the standby HPI pump. HPI should be restarted using the standby HPI pump as directed in RT-4. (BOP-CT)
(TS) (BOP-CT) TS 3.5.2 Condition A CT criteria - Standby HPI should be started before SCM is lost.
The scenario may be terminated when HPI has been restarted or at the direction of the lead evaluator.
Page 4 of 27
Appendix D Scenario Outline Form ES-D-1 Simulator Instructions for Scenario 3 Recall IC 287 Insert remote N2_3 to 0.08000 on event 1 Open A CFT supply valve Insert malfunction FW086 on event 2 A HD pump winding heats up and then trips Insert Malfunction ES258 on event 3 Spurious actuation on ESAS Channel 8 Insert malfunction TR580 to 600.00000 in 300 on event 4 Controlling Steam Header pressure fails low Insert remote CO_P14A to OFF on event 5 A EH Oil pump trips Insert remote CO_P14B to OFF on event 5 B EH Oil pump trips Insert override DI_PB9201 to TRUE on event 6 Trip the Main Turbine Insert malfunction RP246 A RPS channel will not trip Insert malfunction RP247 B RPS channel will not trip Insert malfunction RP248 C RPS channel will not trip Insert malfunction RP249 D RPS channel will not trip Insert override DI_ICC0020 to FALSE Manual reactor trip push button is failed Insert malfunction RC002 to 0.3 on event 7 ~ 150 GPM tube leak on B SG Insert malfunction CV061 on event 8 A HPI trips on motor fault Event Value/Ramp Time Malf. No. Event Description No. Time Trigger 1 1 0 0.08/0 Add N2 to A CFT per 1104.001 N2_3 WCO reports broken oil sightglass on P-7A 2 10 N/A N/A EFW Pump outboard pump bearing.
P-8A heater drain pump will experience a Trigger 2 winding failure causing it to heat up and 3 15 N/A FW086 eventually trip requiring a power reduction to ~
70%
Trigger 3 Spurious actuation of ESAS channel 8 4 25 Active ES258 resulting in actuation of Reactor Building Spray Trigger 4 Controlling turbine header pressure transmitter 5 35 600/300 TR580 fails low over 300 seconds Trigger 5 The operating EH pump will trip and the 50 CO_P14A OFF standby pump will not start causing a loss of CO_P14B OFF EH Oil pressure.
Trigger 6 Main Turbine trip > 43% power. (Crew my 50.5 TRUE DI_PB9201 complete a manual RX trip prior to the turbine trip) 6&7 RPS is failed and will not cause a automatic reactor trip. (TS) The manual trip pushbutton is failed requiring the operators to manually trip RP246,7,8,9 N/A Initial the reactor using the backup pushbuttons. (TS)
DI_ICC0020 FALSE (ATC-CT) Criteria - The reactor should be manually tripped before the pressurizer goes solid.
A ~150 GPM SG tube leak will develop in the Trigger 7 B SG requiring initiation of HPI. (TS) (BOP-55 0.3 RC002 CT) Criteria - HPI should be initiated before 8&9 subcooling margin is lost.
A plant cooldown is required to allow for N/A N/A N/A isolation of the B SG.
Page 5 of 27
Appendix D Scenario Outline Form ES-D-1 Operating HPI pump breaker trips due to motor fault. (TS) (BOP-CT) Criteria - Standby HPI Trigger 8 10 65 N/A pump should be started or HPI flow raised CV061 on ES pump before subcooling margin is lost.
Page 6 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 1 Event
Description:
Add N2 to A CFT per 1104.001 to raise pressure to 585#.
Time Position Applicants Actions or Behavior 0 BOP Performs step 12.0, Pressurizing Core Flood Tanks (CFTs) 12.1 Initial Conditions Both Core Flood Tanks (T-2A and T-2B) are filled and borated as required for operation.
CFTs at or below normal operating pressure OR Pressurizing BOP CFTs has been called for by Plant Startup (1102.002),
"Preparation for Heatup" section.
Core flood system aligned per System Alignment Verifications section of Conduct of Operations (1015.001).
12.2 Align High Pressure Nitrogen per Exhibit A "Nitrogen Manifold BOP Operations" of N2 System (1104.009).
IA OPERATOR CUE:
When directed wait 30 seconds and report, High Pressure Nitrogen is aligned per Exhibit A of 1104.009.
12.3 Open High Pressure Nitrogen Supply HDR Isol (N2-2).
IA OPERATOR CUE:
When directed wait 30 seconds and report, N2-2 is Open.
BOP 12.4 IF pressurizing CFT T-2A, THEN perform the following:
12.4.1 IF in Modes 1 - 4, THEN perform one of the following (A or BOP B):
A. IF dedicated individual will NOT be stationed, AND Check Vlv on T-2A Fill Line (MU-36A) is operable, THEN perform the following:
- 1. Make a station log entry stating Entered Tech Spec 3.6.3 Condition A for Penetration 31 (48-BOP hours and 31 day).
- 2. IF inoperability will last past shift change, THEN place the following in the eSOMs LCO Tracker database:
TS 3.6.3 Condition A (31 day) for Pen 31 TS 3.6.3 Condition A (48 hrs) for Pen 31 EVENT 1 CONTINUED Page 7 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 1 Event
Description:
Add N2 to A CFT per 1104.001 to raise pressure to 585#.
Time Position Applicants Actions or Behavior B. IF dedicated individual will be stationed, OR Check Vlv on T-2A Fill Line (MU-36A) is inoperable, OR evolution expected to exceed 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />, THEN perform the following:
- 1. Station a dedicated individual at N2 Supply to CF Tank T-2A and PZR (N2-3) (or low-dose area BOP 354 elev U1 Aux Bldg) with direct CRS communication with the Control Room, to remain in area while N2 Supply to CF Tank T-2A and PZR (N2-3) is open.
- 2. Make a Station Log entry.
- 3. IF inoperability will last past shift change, THEN enter in eSOMs LCO Tracker database similar to, TS 3.6.3 applied Note 1 for Penetration 31.
BOP 12.4.3 Perform the following:
A. Unlock N2 Supply to CF Tank T-2A and PZR (N2-3).
B. Open N2-3.
CRS Make appropriate entry on Category E/Locked Component Log (E-DOC 1015.001H).
IA OPERATOR CUE:
When directed to open N2-3, wait 30 seconds and activate Trigger 1. Report, N2-3 is Open.
C. Monitor CFT pressurization rate.
BOP 1. Adjust Unit 1 HP N2 Supp (PCV-8330) as necessary to maintain pressurization `rate limits.
- 2. Make appropriate log entry in Containment CRS Penetration Valve Log (Form 1015.001D).
EXAMINER NOTE:
The crew has been directed to pressurize A CFT to 585 psig.
D. IF ESAS actuates, THEN immediately perform the following:
BOP 1. Close N2 Supply to CF Tank T-2A and PZR (N2-3).
- 2. Lock N2-3.
12.4.4 IF RCS pressure is > 800 psig, AND T-2A is between 580 BOP and 620 psig, THEN perform the following:
Page 8 of 27
Appendix D Scenario Outline Form ES-D-1 EVENT 1 CONTINUED Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 1 Event
Description:
Add N2 to A CFT per 1104.001 to raise pressure to 585#.
Time Position Applicants Actions or Behavior A. Close N2 Supply to CF Tank T-2B (N2-3).
IA OPERATOR CUE:
When directed to close N2-3, wait 30 seconds and use Remote N2_3 to 0. Report, N2-3 is Locked Closed.
B. Lock N2-3.
C. Perform independent verification N2-3 closed AND locked:
Make appropriate entry on Category E/Locked Component Log (E-DOC 1015.001H).
BOP 12.4.6 Perform the following:
BOP A. IF applicable, THEN release dedicated individual.
C. IF applicable, THEN update Containment Penetration CRS Valve Log (Form 1015.001D).
E. IF Check Vlv on T-2A Fill Line (MU-36A) is operable, CRS THEN exit TS 3.6.3 for Penetration 31.
12.6 Close High Pressure Nitrogen Supply HDR Isol (N2-2).
IA OPERATOR CUE:
When directed wait 30 seconds and report, N2-2 is Closed.
12.7 Secure High Pressure Nitrogen per Exhibit A "Nitrogen BOP Manifold Operations" of N2 System (1104.009).
IA OPERATOR CUE:
When directed wait 30 seconds and report, High Pressure Nitrogen is secured per Exhibit A of 1104.009.
EVENT TERMINATION CRITERIA:
This event is complete A CFT pressure is raised and procedure is complete OR As directed by the Lead Evaluator.
Page 9 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 2 Event
Description:
WCO reports P-7A EFW Pump outboard pump oil sightglass is broken.
Time Position Applicants Actions or Behavior IA OPERATOR CUE:
Call the CRS on the phone as the WCO and notify him that the outboard pump bearing sightglass on P-7A EFW pump is broken and all the oil is on the floor.
10 CRS Receives call from the WCO regarding status of P-7A.
CRS References technical specifications.
Declares P-7A inoperable.
TS CRS 3.7.5 Condition B - 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> action to restore operability EXAMINER NOTE:
The following steps are not procedurally driven but may be taken as prudent action based on the condition of P-7A.
Option 1 Directs the ATC/BOP to close steam supply valves. CV-2667 & CV-2617 CRS are placed in MANUAL and CLOSED.
ATC/
Places CV-2667 & CV-2617 in MANUAL and closes the valves.
BOP ATC/
Reports that CV-2667 & CV-2617 are in MANUAL and CLOSED.
BOP Option 2 Directs the ATC/BOP to place P-7A Steam Admission Valves CV2613 &
CRS CV-2663 in MANUAL.
ATC/
Places CV-2613 & CV-2663 in MANUAL.
BOP ATC/
Reports that CV-2613 & CV-2663 are in MANUAL.
BOP EVENT TERMINATION CRITERIA:
This event is complete when P-7A has been declared inoperable, AND The correct Tech Spec has been identified, OR As directed by the Lead Evaluator.
Page 10 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 3 Event
Description:
P8A heater drain pump will experience a winding failure causing it to heat up and eventually trip.
A power reduction is required to get within the capacity of the HD tank High Level Dump system and to raise MFW pump suction pressure.
Time Position Applicants Actions or Behavior Recognize and report P8A winding temperature is going up (Crew may 15 ANY elect to stop P8A prior to the pump tripping.).
Direct operations per 1203.012E Annunciator K06 Corrective action CRS (K06-E8).
1.0 Operator Actions BOP 1. Determine which point is in alarm from Heater Drain, Condensate, Circulating and Service Water Pumps Motor Winding Temperatures (TR-2808) on C19.
CRS 2. Initiate steps to determine cause of high temperature alarm
- 3. IF temperature rises to 300°F, THEN commence reducing power at ~ 10%/minute per Rapid Plant Shutdown (1203.045)
CRS to within the capacity of T-40 high level dump (~ 630 MW or
~70% power) and secure affected pump.
(The pump may trip before a power reduction can be started.)
IA OPERATOR CUE:
If asked the AO will report nothing abnormal at P-8A Heater Drain Pump.
EXAMINER NOTE:
When the Heater Drain Pump trips, the CRS can use either of the following ACAs to direct required actions:
K06-A8 P8A/P8B FLOW LO K06-B7 CONDENSATE PUMP TRIP When P-8A Heater Drain Pump trips, directs actions per 1203.012E, CRS Annunciator K06 Corrective action (K06-A8 or K06-B7).
1.0 Operator Actions:
ATC 1. Monitor MFWP suction pressure and feedwater flow very closely for adverse effect on feedwater flow.
- 2. IF either heater drain pump tripped, THEN perform the following:
BOP A. Verify standby Condensate Pump (one of P-2A thru P-2C) has auto started.
EVENT 3 CONTINUED Page 11 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 3 CONTINUED Event
Description:
P8A heater drain pump will experience a winding failure causing it to heat up and eventually trip.
A power reduction is required to get within the capacity of the HD tank High Level Dump system and to raise MFW pump suction pressure.
Time Position Applicants Actions or Behavior B. Commence reducing power at ~ 10%/minute per Rapid ATC Plant Shutdown (1203.045) to within the capacity of T-40 high level dump (~ 630 MW or ~70% power).
D. IF Heater Drain Pump P-8A tripped, THEN inform Auxiliary Operator Heater Drain Pump P-8A tripped BOP AND to perform Local Actions for Heater Drain Tank T-40A Level Control On High Level Dump Exhibit A of this procedure.
IA OPERATOR CUE:
When the AO is directed to perform Exhibit A, wait ~ 5 minutes and report that exhibit A is complete and T-40A High Level Dump control valve controlling level properly.
ATC, Monitor ICS and EHC subsystems for proper integrated response.
BOP ATC, E. Place Low Level Condenser Spray CV-2907 AND CV-BOP 2868 in service by placing HS-2907 on C02 in OPEN.
CRS References and directs actions from 1203.045, Rapid Plant Shutdown.
- 1. Commence power reduction at 0.5 to 10% per minute.
CRS IF power reduction is NOT due to automatic runback, THEN verify ATC has been given a specific end point for the power reduction and rate of desired power change.
BOP EVENT 3 CONTINUED Page 12 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 3 CONTINUED Event
Description:
P8A heater drain pump will experience a winding failure causing it to heat up and eventually trip.
A power reduction is required to get within the capacity of the HD tank High Level Dump system and to raise MFW pump suction pressure.
Time Position Applicants Actions or Behavior
- 3. IF plant has been stabilized with the reactor critical, THEN perform the following:
Instruct ATC to refer to "Contingency Reactivity Plans" located in the Plant Data Book.
Use Power Operation (1102.004), Exhibit A, Operation of APSR Group to control imbalance (ref. Plant Data Book).
Provide desired control bands to ATC. Recommended Rx Power control band is +/- 2%.
CRS Instruct ATC to notify CRS if it becomes difficult maintaining desired power band.
WHEN time permits, THEN perform transient brief stressing reactivity control aspects:
- Reactor status versus Contingency Reactivity Plan
- Review and maintain COLR limits
- Expected rod movement
- Expected boration / dilution
- 4. Secure systems as follows:
IF reducing power < 90%,THEN secure Zinc Injection per one of the following:
CRS - Request Chemistry secure Zinc Injection per Unit 1 Reactor Coolant System(RCS) Zinc Control (1052.036).
- Perform Chemical Addition (1104.003) "Securing Zinc Injection" section.
EVENT TERMINATION CRITERIA:
This event is complete when reactor power has been stabilized at ~70%
OR As directed by the Lead Evaluator.
Page 13 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 4 Event
Description:
Spurious actuation of ESAS channel 8 resulting in actuation of Reactor Building Spray.
Time Position Applicants Actions or Behavior T=25 ATC Announces K11-D3 RB SPRAY CHANNEL 8 alarm.
ATC/
References 1203.012J, K11-D3 Annunciator Corrective action procedure.
CRS Directs actions from 1105.003 ENGINEERED SAFEGUARDS CRS ACTUATION SYSTEM operating procedure step 14.0, ESAS Operation After Spurious or Inadvertent Actuation.
14.1 Determines that trip signal is invalid based on RB pressure indications ALL on C18 and SPDS indicate <30 psig.
CRS 14.2 Determines that the trip signal has not cleared and N/As step.
14.3 Determines that the trip signal has not cleared AND has been CRS determined to be a system fault.
EXAMINER NOTE:
P-35B will start ~35 seconds after the Channel 8 actuation. If P-35B is overridden prior to this time delay, there will be no injection of fluid into the reactor building.
CRS 14.3.1 Directs the BOP to override and stop, P-35B, RB Spray Pump.
BOP Depresses the white MAN button above the P-35B handswitch on C16.
Momentarily places the P-35B Handswitch (HS-2402) on C16 in STOP BOP and verifies the GREEN light is ON and the RED light is OFF for P-35B.
Reports to the CRS that P-35B, RB Spray Pump has been overridden and BOP stopped.
CRS Directs the BOP to override and close, RB Spray Block valve CV-2400.
BOP Depresses the white MAN button above the CV-2400 handswitch on C16.
Holds the CV-2400 handswitch in CLOSE on C16 until the GREEN light BOP is on and the RED light is off for CV-2400.
EVENT 4 CONTINUED Page 14 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 4 CONTINUED Event
Description:
Spurious actuation of ESAS channel 8 resulting in actuation of Reactor Building Spray.
BOP Reports to the CRS that CV-2400 has been overridden and closed.
14.3.2 Performs any or all of the following to determine required actions for the applicable condition:
Refers to Tech Specs.
CRS Considers plant mode, automatic and manual ESAS actuation availability, and the ESAS train and components affected.
Considers contacting Licensing for Technical Specification guidance.
EXAMINER NOTE:
The following Tech Specs apply for this Event:
TS 3.3.6 - One RB Spray channel inoperable. 72 Hour action to restore operability per Condition A.
TS 3.3.7 - One digital actuation logic channel inoperable. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> action to place in ES configuration per Condition A.1 or declare components inoperable per A.2.
TS 3.6.3 - One RB penetration flowpath with 1 inoperable isolation valve. 48 hour5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> action to close and deactivate automatic valve and verify it isolated every 31 days and if entering MODE 4 from MODE 5 if not performed within previous 92 days.
TS 3.6.5 - One RB Spray train inoperable in MODE 1 or 2. 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> action to restore to operable status.
14.3.3 If actual trip signal is present, THEN action shall be taken to return CRS overridden devices or components to ES position.
CRS 14.3.4 Initiate steps to determine and correct cause of actuation.
CRS 14.4 Determines that Spent Fuel Cooling is not lost and N/As step.
EVENT TERMINATION CRITERIA:
This event is complete when P-35B, RB Spray pump has been stopped and CV-2400, RB Spray Block valve is closed and the CRS has referenced Tech Specs OR As directed by the Lead Evaluator.
Page 15 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 5 Event
Description:
Controlling Header Pressure Instrument Fails Low.
Time Position Applicants Actions or Behavior 35 ANY Recognize and report turbine header pressure instrument failing low.
Direct operations per 1203.001 ICS Abnormal Operation, Section 8 -
CRS Selected Turbine Header Pressure Low.
- 1. Perform the following:
Verify Turbine in OPER AUTO or TURB MAN control.
- If Turbine in OPER AUTO then perform the following to raise header pressure:
A. While monitoring SG pressure, raise SETTER as necessary to raise turbine load to stabilize BOP RCS Pressure.
B. Depress GO pushbutton AND release.
C. Verify REFERENCE matches SETTER.
- IF Turbine in TURB MAN, THEN while monitoring SG pressure and reactor power, operate GV Raise pushbuttons as necessary on C01 Lower Operator Console to raise Turbine Load to stabilize RCS pressure.
ATC Verify SG/RX Demand H/A station in HAND ATC Place BOTH TURB BYP Valve H/A stations in HAND ANY 2. Select the good Turbine Header Pressure instrument for indication.
- 3. Adjust SG/RX Demand H/A station as necessary to stabilize power <
ATC 100%.
CRS 4. Proceed as directed by CRS/SM.
Direct returning ICS to automatic per 1105.004 Integrated Control CRS System.
ATC 9.0 Turbine Control Transfer to Integrated Control.
9.1 Verify main steam header pressure is at the setpoint selected BOP on Header Pressure Controlling substation.
9.2 Monitor Governor Valve demand and the following PMS/PDS points for stable conditions:
IC57 TVGV XFER TO SEL HDR PRES (PPAS)
BOP EH02 GOVERNOR VLV DEMAND (PPAS)
CRS ZT6631 GOVERNOR VLV #1 POSITION (PPAS)
ZT6662 GOVERNOR VLV #2 POSITION (PPAS)
ZT6628 GOVERNOR VLV #3 POSITION (PPAS)
ZT6661 GOVERNOR VLV #4 POSITION (PPAS)
EVENT 5 CONTINUED Page 16 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 5 CONTINUED Event
Description:
Controlling Header Pressure Instrument Fails Low.
Time Position Applicants Actions or Behavior 9.4 WHEN turbine header pressure is at setpoint (+/-5 PSI) AND BOP stable (rate of change <10 PSI/minute), THEN transfer turbine controls as follows:
9.5.1 Select integrated control by pressing INTEG BOP CONTROL button on C33.
9.5.2 Check OPER AUTO and TURBINE MANUAL lamps BOP off.
BOP 9.5.3 Check INTEG CONTROL lamp on.
BOP 9.6 Verify turbine control is steady.
BOP 19.1 Turbine Bypass Valve Transfer to Auto - Preferred Method BOP 19.1.1 Verify MEAS VAR reads less than or equal to 50%.
19.1.2 Verify Turbine Bypass Valves are fully closed.
BOP Loop A (CV-6689, CV-6690)
Loop B (CV-6687, CV-6688)
BOP 19.1.3 Place Turbine Bypass Valve H/A station in AUTO.
19.1.4 Verify Header Pressure and Turbine Control remain BOP steady.
BOP 14.0 SG/RX Demand Transfer to Auto.
14.1 Check that POS and MEAS VAR demands are BOP approximately equal (normally 2% or less).
14.2 IF PDS Integrated Master MW Calibrating Integral screen is available, THEN check that SG/RX Master (SG/RX Demand) input and output are within 30 MW of each other:
BOP Input - MW&THP Comp ULD, IC01 Output - SG/Reactor Demand, IC03 EVENT 5 CONTINUED Page 17 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 5 CONTINUED Event
Description:
Controlling Header Pressure Instrument Fails Low.
Time Position Applicants Actions or Behavior 14.2.1 IF significant error exists such as one of the following:
>3% between POS and MEAS VAR
>30 MW between IC01 and IC03 BOP THEN perform one of the following:
Notify CRS/SM AND obtain permission prior to proceeding.
Place applicable H/A stations in manual and re-perform applicable sections of this procedure.
ATC 14.3 Place SG/RX Demand H/A station in AUTO.
14.4 IF main feedwater flow changes significantly OR neutron error changes significantly, THEN return SG/RX Demand to ATC HAND.
14.4.1 Stabilize the Plant.
Reference Annunciator Corrective Action for K07-B4 SASS MISSMATCH CRS for guidance [ACA 1203.012F, p20].
IA OPERATOR CUE:
If an operator is directed to bypass the SASS MISMATCH alarm, wait ~10 minutes and bypass using Remote SASS14 to BYPASS.
Notify operator outside the control room to bypass the SASS MISMATCH CRS alarm on C47-2 as directed in 1203.012F ACA for K07-B4 SASS MISMATCH alarm.
EVENT TERMINATION CRITERIA:
This event is complete when the ICS is in automatic OR As directed by the Lead Evaluator.
Page 18 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 6 & 7 Event
Description:
The operating EH pump breaker will trip causing a loss of EH fluid pressure and a main turbine trip >43% power.
RPS is failed and will not cause an automatic trip. Manual trip P/B is failed requiring the operators to manually trip the reactor using the backup trip P/Bs.
Time Position Applicants Actions or Behavior 50 ANY Recognize and report P-14A tripped and P-14B failed to start.
Dispatch operator to reset P-14A breaker (B-3225) (Crew may not have CRS time to dispatch this operator before the turbine trips).
ANY Recognize turbine valves closing.
50.5 ANY Recognize turbine tripped >43% power.
Recognize RPS failed to automatically trip the reactor.
ANY TS 3.3.1 Condition C Recognize manual reactor trip push button is failed.
ATC TS 3.3.2 Condition A Trip the reactor using the shunt trip push buttons.
ATC CT criteria - The reactor should be manually tripped before the pressurizer goes solid.
CRS Direct operations per 1202.001 Reactor Trip.
- 1. Depress Reactor Trip PB.
ATC A. Verify all rods inserted and Reactor power dropping.
- 2. Depress Turbine trip PB.
BOP A. Check Turbine throttle and governor valves closed.
ANY 3. Check adequate SCM.
EXAMINER NOTE:
This section contains all the steps of the Reactor Trip procedure. There is a floating step that directs the CRS to go to the Tube Rupture procedure if a tube leak of 1gpm exists.
- 4. Advise Shift Manager to implement Emergency Action Level CRS Classification (1903.010).
ATC 5. Verify Orifice Bypass (CV-1223) demand adjusted to zero.
BOP 6. Open BWST Outlet to OP HPI pump CV-1407.
ATC 7. Adjust Pressurizer Level Control setpoint to 100".
EVENT 6 & 7 CONTINUED Page 19 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 6 & 7 CONTINUED Event
Description:
The operating EH pump breaker will trip causing a loss of EH fluid pressure and a main turbine trip >43% power.
RPS is failed and will not cause an automatic trip. Manual trip P/B is failed requiring the operators to manually trip the reactor using the backup trip P/Bs.
Time Position Applicants Actions or Behavior ATC 8. Control RCS press within limits of Figure 3 (RT-14).
BOP 9. Check for proper electrical response (RT-19).
ANY 10. Check OP HPI pump supplying normal Makeup and Seal Injection.
ATC 11. Check both SG levels remain <410".
ANY 12. Check Instrument Air Header press >75 psi.
ATC 13. Check NNI and ICS power available (RT-20).
ATC 14. Check SG press >900 psig.
ATC 15. Check MSSV OPEN alarm clear (K07-C5).
- 16. Check both MSIVs open.
ATC CV-2691 CV-2692
- 18. Place both Feedwater Demands in HAND AND verify demand at zero.
ATC Feedwater Demand Loop A Feedwater Demand Loop B
- 19. Check Main Block valves closed (CV-2625 and 2675).
ATC CV-2625 CV-2675
- 20. Check Low Load Block valves closed (CV-2624 and 2674).
ATC CV-2624 CV-2674 EVENT 6 & 7 CONTINUED Page 20 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 6 & 7 CONTINUED Event
Description:
The operating EH pump breaker will trip causing a loss of EH fluid and a main turbine trip >43% power.
RPS is failed and will not cause an automatic trip. Manual trip P/B is failed requiring the operators to manually trip the reactor using the backup trip P/Bs.
Time Position Applicants Actions or Behavior ATC 21. Check Startup valves maintain SG levels 20 to 40".
CRS 23. Check the following in service:
BOP A. Check Service Water pump supplying SW Loop 1.
BOP B. Check Service Water pump supplying SW Loop 2.
ANY C. Check ICW pump supplying Nuclear loop (P33C or B).
ANY D. Check ICW pump supplying Non-nuclear loop (P33A or B).
BOP E. Check RB Cooling Fans (VSF1A, B, C, D, and E).
BOP F. Check Previously running Main Chiller(s) (VCH1A, B).
ANY 24. ESAS Actuation alarms clear on K11.
ANY 25. Check Spent Fuel Pool cooling in service.
ANY 26. Check RCS press > 1700 psig.
- 27. Check Pressurizer Level Control valve (CV-1235) maintains PZR ATC level > 55".
ATC A. Verify Proportional Control Pressurizer Heaters in AUTO.
BOP 28. Check PZR steam space integrity.
- 29. Verify ERV, Pressurizer Spray, and Pressurizer Heaters operate to CRS control RCS press 2050 to 2250 psig.
ATC 30. Check at least one RCP running.
ATC 31. Check adequate SCM.
EVENT 6 & 7 CONTINUED Page 21 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 6 & 7 CONTINUED Event
Description:
The operating EH pump breaker will trip causing a loss of EH fluid and a main turbine trip >43% power.
RPS is failed and will not cause an automatic trip. Manual trip P/B is failed requiring the operators to manually trip the reactor using the backup trip P/Bs.
Time Position Applicants Actions or Behavior ATC 32. Check RCS T-cold remains 540°F.
- 33. Check RCS temp remains either:
ATC < 580°F T-hot with any RCP on OR
< 610°F CET temp with all RCPs off ATC 34. Check SG tube integrity (RT-18).
EVENT TERMINATION CRITERIA:
This event is complete when the operators recognize the SG tube leak OR As directed by the Lead Evaluator.
Page 22 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 8 & 9 Event
Description:
A ~150 GPM tube leak will develop in the B SG requiring initiation of HPI.
Time Position Applicants Actions or Behavior Recognize SG tube leak on the B SG.
55 ANY TS 3.4.13 Condition B CRS Transition to 1202.006 Tube Rupture.
- 1. IF reactor or turbine has tripped OR trips during plant runback OR CRS PZR level drops below 100" during plant runback, THEN GO TO step 11.
CRS Direct operations per 1202.006 Tube Rupture starting at step 11.
- 11. Depress Reactor Trip PB.
ATC A. Verify all rods inserted and Reactor power dropping.
(This step already performed by the Rx Trip EOP.)
- 12. Verify Turbine tripped.
BOP A. Verify Turbine throttle and governor valves closed.
(This step already performed by the Rx Trip EOP.)
ANY 13. Check adequate SCM.
ATC 14. Verify Header Pressure Controlling setpoint adjusted to 45.
ATC A. Check TURB BYP valves controlling SG press 950 to 990 psig.
ATC B. Check MSSV OPEN (K07-C5) alarm clear.
- 15. Verify Shift Manager advised to perform BOTH of the following:
CRS Notify Nuclear Chemistry to begin off-site dose projections.
Implement Emergency Action Level Classification (1903.010).
ATC 16. Verify Orifice Bypass (CV-1223) closed.
- 19. Check Main Generator and Exciter Field breakers open.
BOP 5114 5118 Exciter Field Breaker EVENT 8 & 9 CONTINUED Page 23 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 8 & 9 Continued Event
Description:
A ~150 GPM tube leak will develop in the B SG requiring initiation of HPI.
Time Position Applicants Actions or Behavior EXAMINER NOTE:
The following step commences depressurization of the RCS.
- 20. Operate Pressurizer Heaters AND Pressurizer Spray valve (CV-ATC 1008) to maintain RCS press low within limits of Figure 3 (RT-14).
ATC, A. IF RCS press drops below 1700 psig AND SCM is adequate BOP AND RCS press is controlled, THEN bypass ESAS.
ANY Recognize Lowering PZR level.
CRS 21. Stabilize PZR level 55" as follows:
ATC A. Adjust Pressurizer Level Control setpoint to 100.
B. IF HPI is in service, THEN adjust HPI flow as necessary to BOP maintain PZR level 55 AND RCS press low within limits of Figure 3 (RT-14).
Initiate RT2 HPI.
CT BOP CT criteria - HPI should be initiated before SCM is lost.
C. IF PZR level is < 55, OR if PZR level is predicted to drop BOP below 55, THEN initiate HPI (RT-2).
BOP RI-2691 RI-2692
- 23. Verify bad SG determined using one or more of the following:
OTSG N-16 Gross Detectors SGTR display on SPDS Plant Monitoring System Alarms Steam Line High Range Radiation Monitors (may be inconclusive ANY due to insufficient shielding between MS lines)
Local steam line radiation survey Nuclear Chemistry sample Bad SG should have:
- Higher than expected SG level
- Lower than expected FW flow rate
- 24. Verify Control of Secondary System Contamination (1203.014) being CRS performed in conjunction with this procedure.
EVENT 8 & 9 CONTINUED Page 24 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 8 & 9 Continued Event
Description:
A ~150 GPM tube leak will develop in the B SG requiring initiation of HPI.
Time Position Applicants Actions or Behavior CRS 26. Determine that Emergency Cooldown Rate is not required.
- 27. IF emergency cooldown rate is not required OR RCS T-hot is ATC 500°F, THEN establish RCS cooldown rate of 100°F/hr as follows:
EXAMINER NOTE:
The following step commences RCS cooldown.
A. For good SG, place TURB BYP Valves in HAND AND adjust to ATC maintain cooldown rate 100°F/hr.
B. IF RCS press drops below 1700 psig AND SCM is adequate ATC AND RCS press is controlled, THEN bypass ESAS.
C. IF only one SG is bad, THEN steam bad SG only as necessary ATC to maintain Exhibit 1 limits.
EVENT TERMINATION CRITERIA:
This event is complete when an RCS cooldown and depressurization have been started OR As directed by the Lead Evaluator.
Page 25 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 10 Event
Description:
Operating HPI pump breaker trips due to a motor fault.
Time Position Applicants Actions or Behavior IA OPERATOR CUE:
If asked to investigate the status of A-306 breaker, report that the A HPI pump breaker A306 has an instantaneous over-current relay tripped.
If asked to investigate P-36A motor locally, wait ~ 2 minutes and report that P-36A motor feels and smells hot.
65 ATC Recognize and report P36A HPI pump trip.
BOP Place Standby HPI pump in service per 1202.012 RT-2 HPI step 3.
- 3. IF either OP or STBY HPI pumps are available AND both pumps are BOP off, THEN place OP or STBY HPI pump in service as follows:
A. Verify BWST outlet to OP and STBY HPI pump (CV-1407)
BOP open.
BOP B. Verify RCP Seal INJ Block (CV-1206) closed.
BOP C. Close RCS Makeup Block (CV-1233 or CV-1234).
D. Prevent dead heading pump by verifying one of the following:
BOP Both HPI RECIRC valves open (CV-1300 and 1301)
One HPI Block valve associated with ES HPI pump (CV-Steps 1220 or 1285) fully open to start E. IF HPI Pump (P-36B) will be used, THEN verify the following STBY selected to energized bus:
BOP HPI P36B/P64B Bus select MOD control pump P64B Transfer Switch BOP F. Start AUX Lube Oil pump for OP or STBY HPI pump.
BOP G. Start OP or STBY HPI pump.
CT Criteria: HPI restored prior to losing SCM.
BOP H. Stop AUX Lube Oil pump.
I. WHEN associated BWST T3 Outlet is open, THEN open HPI BOP Block valve associated with OP or STBY HPI pump (CV-1220 or CV-1285) to maintain PZR level and RCS press.
- 1) IF PZR level or RCS press continues to drop, THEN BOP open additional HPI Block valves associated with OP or STBY HPI pump:
EVENT 10 CONTINUED Page 26 of 27
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 3 Event No.: 10 CONTINUED Event
Description:
Operating HPI pump breaker trips due to a motor fault.
Time Position Applicants Actions or Behavior Steps BOP Start Aux lube oil pump for STBY HPI pump.
to start STBY BOP Start STBY HPI Pump.
HPI pump (cont.) BOP Stop Aux Lube Oil Pump.
EVENT TERMINATION CRITERIA:
This scenario is complete when the Standby HPI pump is started and HPI is being injected as needed OR As directed by the Lead Evaluator.
Page 27 of 27
Appendix D Scenario Outline Form ES-D-1 Facility: ANO-1 Scenario No.: 4 R2 Op-Test No.: 2013-1 Examiners: ____________________________ Operators: _____________________________
Initial Conditions:
- 100% MOL; Severe Thunderstorm Warning for Pope and Conway counties.
- #2 EDG Tagged out for repairs.
Turnover:
- National Weather service has issued a Severe Thunderstorm Warning for Pope and Conway Counties until 8:00 pm today. AOP 1203.025, Natural Emergencies, Section 3, Tornado Watch
/Severe Thunderstorm Warning, all required actions have been completed.
- #2 EDG OOS for fuel leak repairs. 1104.036 Supplement 11 starting at step 2.4 is due right after turn-over.
Event Event Event Malf. No.
No. Type* Description 1 N/A N (ALL) Perform 1104.036 Supplement 11 for EDG #1.
2 TR568 I (ATC) A OTSG operating level transmitter fails high.
DI_RX7460S I (SRO) RB atmosphere radioactivity monitor fails low. TS 3.4.15 3 DI_RX7460SP TS determination.
R (ATC) 4 N/A C (SRO) #1 EDG inoperability (common mode) requires plant shutdown to TS comply with Technical Specifications.
I (BOP) Turbine EHC fails to respond in auto mode for ICS (manual 5 RX150 CT control required).
C (ATC) One MSIV for B OTSG drifts shut-requires manual reactor trip 6 CV2692 CT per EOP 1202.001.
A OTSG steam leak in containment (MSLI activates). Transfer 7 MS131 M (ALL) to 1202.003 overcooling if necessary.
Containment pressure >4psig but B train RBIC will fail to I (ATC) actuate automatically and an ICW isolation valve will fail open ES264 8 C (BOP) that should shut. Operator will be required to manually initiate B CV2214 RBIC and verify shut the redundant ICW valve to ensure ICW TS isolated.
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 1 of 18
Appendix D Scenario Outline Form ES-D-1 SCENARIO 4 OBJECTIVES
- 1) Evaluate individual ability to perform the control room portion of #1 EDG Operability Test 1104.036 Supp. 11.
- 2) Evaluate individual ability to recognize and respond to the A SG Operating Level transmitter failing high.
- 3) Evaluate individual ability to recognize and respond to the failure of the RB Atmosphere Radioactivity Monitor (RX-7460) failing low.
- 4) Evaluate individual ability to recognize and apply Technical Specifications.
- 5) Evaluate individual ability to reduce plant power.
- 6) Evaluate individual ability to recognize and respond to failure of the Turbine EHC system to respond to ICS signals.
- 7) Evaluate individual ability to recognize and respond to MSIV closure at power.
- 8) Evaluate individual ability to recognize and respond to a failure of RPS to trip the reactor.
- 9) Evaluate individual ability to recognize and respond to Steam Leak inside containment.
- 10) Evaluate individual ability to throttle HPI to prevent the pressurizer from going solid.
- 11) Evaluate individual ability to recognize and respond to the failure of Train B of Reactor Building Isolation to automatically actuate.
- 12) Evaluate individual ability to recognize and respond to the failure of ICW to RB valve CV-2214 to close on ES signal.
Page 2 of 18
Appendix D Scenario Outline Form ES-D-1 SCENARIO 4 NARRATIVE The crew will assume plant responsibility at 100% power. A Severe Thunderstorm Warning is in effect for Pope and Conway Counties. The #2 EDG is inoperable and tagged out due to a fuel leak. Repairs are in progress. Performance of 1104.036 Supp. 11, DG1 Operability Test has been directed to be performed at the start of shift starting at step 2.4. The SRO will direct performance of Supp. 11 when the crew takes responsibility. N-(ALL)
After the EDG is stopped, a failure (fails high slowly) of the controlling A SG Operating Range Level transmitter, LT-2659 (X instrument) will occur resulting in a K07-B4 SASS MISMATCH alarm and requiring the A MFW Pump ICS HAND/AUTO station to be taken to HAND to prevent ICS from rapidly lowering feedwater in response to the false high level signal. This is directed from 1203.001, section 6. With the A MFW demand in HAND, the Y instrument, LT-2660 will be verified to have a valid signal and will be selected for control and the A MFW Demand will be placed back in AUTO. (I-ATC)
The Reactor Building Atmosphere Radiation Monitor, RX-7460 sample pump will fail requiring entry into TS 3.4.15 for inoperability of a required RCS leaking monitoring system. Required action is to enter a timeclock to return the monitor to operable status within 30 days AND perform one of the following: 1) Analyze grab samples of the RB atmosphere every 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
OR 2) perform an RCS inventory balance every 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. (I-BOP), (I-SRO) TS The EDG system engineer will call and report that the same fuel leak that is being repaired on the #2 EDG is now present on #1 EDG and it cannot complete its mission time. The CRS will need to reference TS to determine operability. TS 3.8.1 Condition E, restore one DG to operable status in 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. If this is not met, be in Mode 3 in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> per Condition F.
(N-SRO) (R-ATC) TS. When the TS action has been entered, the Shift Manager will call and direct a power reduction @ 1%/min to take the plant off-line per TS 3.8.1.F.
As power is reduced, the Main Turbine EHC will not respond to the ICS signal resulting in lowering steam header pressure and electrical output not lowering as expected. The Main Turbine must be placed in Operator Auto or Manual (CT) mode to lower power. The crew may also place the ICS SG/RX Demand station in HAND to control reactor and feedwater demand manually. (I-BOP)
The Main Steam Isolation valve (CV-2692) for the B SG will drift closed requiring a reactor trip per 1202.001 Reactor Trip EOP. The ATC will trip the reactor (CT) and perform the reactor trip immediate actions. The SRO will direct the crew from the Reactor Trip follow up actions.
(C-ATC)
A steam leak will develop on the A SG inside the reactor building. (M-ALL) This will result in lowering steam pressure on the A SG and rising pressure inside the reactor building. SG pressure <900 psig or actuation of ESAS on RB pressure of 4 psig alone will require entry into the Overcooling EOP. ESAS RB Isolation Channel 6 will fail to automatically actuate and will require manual actuation. (TS 3.3.7) (I-ATC) RB ICW isolation valve CV-2214 will fail to close automatically or manually. This is reported and determined that the redundant valve (CV-2215) is closed and the function is not lost. ESAS actuation will result in full HPI flow to core. This will initially help maintain RCS inventory as the RCS is excessively cooled but must be overridden and throttled/secured to prevent overfilling the pressurizer and opening the ERV. Actuation of ESAS channels 5 & 6 will result in a loss of RCP services which will require the RCPs to be secured. The event is terminated by isolating feed to the A SG and allowing the SG to boil dry.
RCS temperature will be stabilized using the B SG Atmospheric Dump Control Valve (MSIV is closed).
Page 3 of 18
Appendix D Scenario Outline Form ES-D-1 Simulator Instructions for Scenario 4 Recall IC 288 Verify caution card installed and status board updated for #2 EDG.
Provide marked-up copy of 1104.036 Supp. 11 through step 2.3.
Have 2 stopwatches available for timing EDG start.
Insert malfunction ES264 ESAS Channel 6 Fails to Actuate Insert malfunction CV2214 to 1 ICW Letdown Clrs Iso Vlv failed open Insert malfunction RP246 A RPS channel will not trip Insert malfunction RP247 B RPS channel will not trip Insert malfunction RP248 C RPS channel will not trip Insert malfunction RP249 D RPS channel will not trip Insert malfunction TR568 to 292 in 180 on Event 1 A OTSG Operate Level (LT2659)
Insert override DI_RX7460S to FALSE on Event 2 Start, Pump Control RX7460 Insert override DI_RX7460SP to TRUE on Event 2 Stop, Pump Control RX7460 Insert override DO_RX7460A2 to ON on Event 2 AMB LP, Pump Fail RX7460 Insert malfunction RX150 on Event 3 Freeze ICS signal to EHC at current value Insert malfunction CV2692 to 0 in 60 on Event 4 B MSIV closes Insert malfunction MS131 to 0.4 in 180 on Event 5 A MS Line Rupture inside RB Event Value/Ramp Time Malf. No. Event Description No. Time 1 0 N/A N/A Perform 1104.036 Supplement 11 for EDG #1.
Trigger 1 2 15 292 / Ramp 3 A OTSG operating level transmitter fails high.
TR568 Min.
Trigger 2 3 20 DI_RX7460S FALSE RB atmosphere radioactivity monitor fails low. (TS)
DI_RX7460SP TRUE
- 1 EDG inoperability (common mode) requires 30 N/A N/A plant shutdown to comply with Technical 4&5 Specifications. (TS)
Trigger 3 Turbine EHC fails to respond in auto mode for ICS.
30.5 N/A RX150 (ATC-CT)
Cued by Trigger 4 One MSIV for B OTSG drifts shut-requires 0/60 sec Examiner CV2692 manual reactor trip.
RPS is failed and will not cause a automatic reactor 6 trip. (TS) The manual trip pushbutton is failed RP246,7,8,9 N/A requiring the operators to manually trip the reactor Initial DI_ICC0020 FALSE using the backup pushbuttons. (TS) (ATC-CT)
Criteria - The reactor should be manually tripped before the pressurizer goes solid.
Rx Trip + A OTSG steam leak in containment (MSLI Trigger 5 .4 /
30 activates). Transfer to 1202.003 overcooling if MS131 Ramp 3 Min.
Seconds necessary.
B Train of Reactor Bldg. Isolation and Cooling 7&8 fails to auto actuate (ESAS channel 6).
ICW valve CV2214 fails to close upon ESAS ES264 N/A Initial actuation. (TS) (ATC-CT) Criteria - Actuate CV2214 1 channel 6 to isolate Nuc ICW from RB due to CV-2214 failure. (BOP-CT) Criteria - Throttle HPI before Pzr. goes solid.
Page 4 of 18
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event No.: 1 Event
Description:
Perform surveillance test of the #1 EDG per Supplement 11 of 1104.036 starting at step 2.4, for operability verification due to maintenance of #2 EDG.
Time Position Applicants Actions or Behavior Directs the performance of the #1 EDG surveillance test per Supplement 11 T=0 CRS of 1104.036 starting at step 2.4.
BOP Make plant announcement for the starting of #1 EDG.
BOP 2.4 Perform the following to verify Remote Start capability:
BOP 2.4.1 Perform remote start of diesel as follows:
BOP A. Verify DG1 Volts Select switch NOT in OFF on C10.
B. Simultaneously depress the START pushbutton for #1 EDG BOP and start the stopwatch.
BOP C. Stop the stopwatch when DG1 voltage exceeds 4000 volts.
BOP 2.4.2 Record the following in section 3.0:
A. Time elapsed from operation of start switch until voltage BOP exceeded 4000 volts.
B. Record M&TE number of the stopwatch from which start BOP time is taken.
BOP 2.4.3 IF time is greater than 15 seconds, THEN perform the following:
BOP B. Declare DG1 inoperable.
BOP C. Discontinue test.
2.4.4 Verify service water to DG1 coolers (CV3806) opens.
BOP A. Record Verification in section 3.0.
BOP 2.4.5 Perform the following to stop diesel:
BOP A. Adjust frequency to ~ 60 Hz using DG1 governor control.
BOP B. Adjust voltage to ~ 4160 volts using DG1 voltage regulator.
EVENT 1 CONTINUED Page 5 of 18
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event No.: 1 CONTINUED Event
Description:
Perform surveillance test of the #1 EDG per Supplement 11 of 1104.036 starting at step 2.4, for operability verification due to maintenance of #2 EDG.
Time Position Applicants Actions or Behavior BOP C. Depress DG1 STOP pushbutton at C10.
2.5 Verify associated critical AND non-critical alarms clear:
BOP EDG1 CRITICAL TROUBLE (K01-C2)
EDG1 NON-CRITICAL TROUBLE (K01-D2) 2.6 WHEN DG1 has been stopped for at least 20 minutes, THEN close BOP Service Water to DG1 Coolers (CV-3806).
EVENT TERMINATION CRITERIA
Page 6 of 18
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event No.: 2 Event
Description:
A OTSG Operating Range Level Transmitter fails high.
Time Position Applicants Actions or Behavior T=12 BOP Acknowledge and report annunciator K07-B4, SASS MISMATCH.
ANY Observe SASS ENBL lights on panels C03, C04 and C13.
ATC/ Determine affected instrument by observing SASS ENBL light not illuminated BOP for the A SG Operating Range level recorder on C13.
Directs operations from 1203.001 ICS Abnormal Operation, Section 6, SG CRS Operate Level High.
ATC 1. Place affected MFW Pump H/A to HAND.
- 2. IF Main Feedwater Block Valve(s) closed, THEN place associated Startup ATC and Low Load Control Valves in HAND.
- 3. IF desired, THEN place the following in HAND:
ATC Feedwater Loop A Demand H/A Feedwater Loop B Demand H/A
- 4. Perform the following to stabilize RCS parameters:
IF Main Feedwater Block Valve(s) closed, THEN operate associated ATC Startup and Low Load Control Valves in HAND.
Raise affected MFW Pump H/A as necessary.
- 5. IF in Modes 1, 2 or 3 AND Startup or Low Load Control Valve(s) placed in CRS HAND, THEN enter associated condition per TS 3.7.3.
Observe redundant instrument and other SG instrumentation and determine ALL that the Y instrument for A SG Operate Range Level is valid.
- 6. Select the good (Y) SG Operate Level instrument for indication.
BOP (HS-2609 on C13.) (Green X light goes out and blue Y light comes on.)
BOP Verify the Operating Range Level for A SG is indicating properly on C13.
CRS 7. Proceed as directed by CRS/SM.
Directs the ATC/BOP to return ICS to AUTO using 1105.004, Integrated CRS Control System.
EVENT 2 CONTINUED Page 7 of 18
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event No.: 2 Event
Description:
A OTSG Operating Range Level Transmitter fails high.
Time Position Applicants Actions or Behavior EXAMINER NOTE:
The following steps assume that only the A MFW Pump ICS H/A station has been placed in HAND as directed by procedure and that it may be placed in AUTO without additional action. If additional stations were taken to HAND, additional steps will be required.
ATC References step 18.0, Main Feedwater Pump Transfer to Auto of BOP 1105.004, Integrated Control System.
ATC 18.1 IF in P control (Main FW Block Valve closed), THEN transfer as follows:
BOP (N/A - Not in P Control)
ATC 18.2 IF in flow control (Main FW Block Valve open), THEN transfer as follows:
BOP 18.2.1 Null flow error by performing either or both of the following:
ATC Adjust associated Feedwater Demand H/A in HAND.
BOP Slowly adjust pump speed/auto demand using MFW Pump H/A station to null flow error.
ATC 18.2.2 Place MFW Pump H/A station in AUTO.
BOP Reference Annunciator Corrective Action for K07-B4 SASS MISSMATCH for CRS guidance [ACA 1203.012F, p20].
IA OPERATOR CUE:
If an operator is directed to bypass the SASS MISMATCH alarm, wait ~10 minutes and bypass using Remote SASS16 to BYPASS.
Notify operator outside the control room to bypass the SASS MISMATCH CRS alarm on C47-2 as directed in 1203.012F ACA for K07-B4 SASS MISMATCH alarm.
EVENT TERMINATION CRITERIA ICS returned to AUTO OR As directed by the Lead Evaluator.
Page 8 of 18
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event No.: 3 Event
Description:
RB atmosphere radioactivity monitor fails low.
Time Position Applicants Actions or Behavior Acknowledge and report annunciator K12-F1, K15 NON-CRITICAL T=19 ATC TROUBLE.
BOP Report Annunciator K15-C2, RB Atmosphere Detector Trouble.
Observe monitors at C25 and determine that RX7460/61 has no running BOP sample pump as indicated by amber Low Flow and Pump Fail lamps ON.
Direct actions from 1203.012M Annunciator K15 Corrective Action for CRS corrective action and guidance, as well as [ACA 1203.012M].
- 1. Confirm alarm by checking for low flow or RB ATMOS Particulate Detector BOP (RE-7460) failure at RB Leak Detector RX-7460 (C25).
- 2. IF necessary, THEN adjust flow setting on RB Leak Detector RX-7460 by BOP adjusting potentiometer to raise flow above alarm setpoint.
IA OPERATOR CUE:
If directed to check the status of Y2 bkr #18, wait 2 minutes and report that Y2 bkr #18 is closed.
BOP 3. Check power supply to RX-7460 (Y2, bkr #18).
IA OPERATOR CUE:
If the WCO is directed to check the status of the rad monitor locally, wait 2 minutes and report that there are no pumps running and everything else looks normal.
BOP 4. Refer to Reactor Building Ventilation (1104.033).
- 5. IF filter suspected of being dirty, THEN open Reactor Building Leak BOP Detector RE-7461 Filter F-39 Bypass (GCH-7).
- 6. IF alarm condition clear, THEN verify WR/WO initiated to check Filter (F-BOP 39).
- 7. IF alarm condition can NOT be cleared, THEN declare affected component CRS inoperable and refer to TS 3.4.15.
EVENT 3 CONTINUED Page 9 of 18
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event No.: 3 CONTINUED Event
Description:
RB atmosphere radioactivity monitor fails low.
Time Position Applicants Actions or Behavior Determine RB Atmosphere Gaseous Monitor is inoperable and refer to Tech Spec 3.4.15.B.
Analyze grab samples of the reactor building atmosphere - Once per 24 hrs.
OR CRS Verify RCS operational LEAKAGE is within limits by performance of an RCS water inventory balance - Once per 24hrs.
AND Restore required reactor building atmosphere radioactivity monitor to OPERABLE status within 30 days.
CRS Initiate steps to have the failed monitor checked and repaired.
EVENT TERMINATION CRITERIA Tech Spec determination made OR As directed by the Lead Evaluator.
Page 10 of 18
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event No.: 4 & 5 Event
Description:
- 1 EDG inoperability (common mode) requires plant shutdown to comply with Technical Specifications.
Time Position Applicants Actions or Behavior IA OPERATOR CUE:
Call the CRS as the EDG system engineer and report that the same leak that is being repaired on #2 EDG is now present on #1 EDG and it can no longer complete its mission time. Action is being taken to contain the leakage.
References Technical Specifications to determine operability and required action.
T=30 CRS TS 3.8.1 Condition E. Restore one DG to operable status in 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. If this is not met, be in Mode 3 in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> per Condition F.
IA OPERATOR CUE:
When the CRS has declared the #1 EDG inoperable and entered the associated action statement, call the CRS as the Shift Manager and direct him to commence a rapid plant shutdown at 1%/min to take the plant off-line to comply with Tech Specs.
Direct operations per 1203.045, Rapid Plant Shutdown - Section 1, Rapid CRS Plant Shutdown Without Small SG Tube Leak.
- 1. Commence power reduction at 0.5 to 10% per minute.
IF power reduction is NOT due to automatic runback, THEN verify ATC has been given a specific end point for the power reduction and rate of desired power change.
CRS Instruct ATC to report power level at CRS directed frequency.
IF necessary to maintain Makeup tank level, THEN open BWST T3 Outlet to operating HPI Pump (CV-1407 or CV-1408) AND minimize or isolate Letdown.
Manual control of ICS or EHC subsystems may be initiated at any time deemed appropriate by the operator.
ATC IF desired to restore automatic control of a subsystem, THEN refer to BOP Integrated Control System (1105.004).
IF desired to stop downpower above final ULD setpoint, THEN perform Stopping Downpower With SG/RX Demand (Exhibit 1) of this procedure.
ATC/ Recognize and report to the CRS that the turbine is not responding during the BOP power reduction.
EVENT 4 & 5 CONTINUED Page 11 of 18
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event No.: 4 & 5 CONTINUED Event
Description:
- 1 EDG inoperability (common mode) requires plant shutdown to comply with Technical Specifications.
Time Position Applicants Actions or Behavior EXAMINER NOTE:
The crew may elect to place both the SG/RX master and the Turbine in the MANUAL mode.
In this configuration, the ATC controls the change in load demand and the BOP will maintain turbine header pressure.
CRS Direct the BOP to place the turbine in Operator Auto or Manual mode.
Take the turbine to manual or operator auto by depressing the OPER AUTO CT BOP or TURBINE MANUAL pushbutton on C33 Turbine Control Panel.
ATC Acknowledges and reports annunciator K07-A1, UNIT MASTER IN TRACK.
If OPER AUTO is used:
On C33, set load rate to 1%/min.
Use down arrow on Reference Control to lower reference value.
Depress GO on the Reference Control.
BOP If TURBINE MANUAL is used:
Use GV down arrow on the Turbine Manual controls to close the governor valves.
The rate of reduction will be determined by the duration and frequency of depressing the GV down arrow button.
BOP Verify Turbine EHC responds to lowering load.
Verify that reactor power and feedwater are tracking the main turbine at ATC
~1%/min.
EVENT TERMINATION CRITERIA Power reduction is in progress using the Main Turbine in OPER AUTO or TURBINE MANUAL AND Reactor Power is < 95% power OR As directed by the Lead Evaluator.
Page 12 of 18
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event No. 6 Event
Description:
The B Main Steam Isolation Valve drifts shut, requiring a manual reactor trip per EOP 1202.001.
Time Position Applicants Actions or Behavior Cued ATC Acknowledge and report annunciator K07-B4, SASS MISMATCH.
ATC Acknowledge and report annunciator K07-C6, Main Steam Pressure Hi/Lo ATC/
Observe the B MSIV, CV2692, closing.
BOP CRS Direct operations from 1202.001, Reactor Trip.
CRS Direct the ATC to TRIP the reactor and Carryout the immediate actions.
- 1. Depress Reactor Trip PB.
CT ATC A. Verify all rods inserted AND reactor power dropping.
Criteria - The reactor should be manually tripped before the pressurizer goes solid.
- 2. Depress Turbine trip PB.
BOP A. Check Turbine throttle and governor valves closed.
ATC/
- 3. Check adequate SCM.
- 4. Advise Shift Manager to implement Emergency Action Level Classification CRS (1903.010).
ATC 5. Verify Orifice Bypass (CV-1223) demand adjusted to zero.
- 6. Open BWST T3 Outlet (CV-1407 or CV-1408) to operating HPI pump.
BOP (CV-1407 is for the operating HPI pump)
- 7. IF Emergency Boration is not in progress, THEN adjust Pressurizer Level ATC Control setpoint to 100".
BOP 8. Control RCS press within limits of Figure 3 (RT-14).
EVENT TERMINATION CRITERIA B MSIV closed and Reactor is tripped OR As determined by the Lead Evaluator.
Page 13 of 18
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event 7 & 8 Event
Description:
A Main Steam Line rupture inside containment.
Channel 6 of ESAS fails to auto actuate. ICW valve CV-2214 fails to close.
Time Position Applicants Actions or Behavior Rx Trip Recognize A OTSG pressure dropping OR noticeably lower than B OTSG ATC
+ 30 pressure.
Sec.
ATC Acknowledge and report annunciator K11-E1, RB Pressure HIGH.
ATC Monitor RB pressure and temperature.
EXAMINER NOTE:
Annunciator K12-A1, FIRE ALARM, will alarm due to the environmental conditions inside the Reactor Building EXAMINER CUE:
If the BOP investigates the cause of the Fire Alarm, provide mimic showing the reactor building fire alarms in alarm.
ATC/
Identify and announce ESAS has actuated on high RB Pressure.
BOP ATC/
TS Recognize failure of ESAS Channel 6 to auto actuate. Tech Spec 3.3.7A.
BOP EXAMINER NOTE:
Manual actuation of Channel 6 is critical because the failed ICW valve is closed by the redundant Channel 5. No credit is given for a closed system.
Manually actuate ESAS Channel 6 using the red CH. 6 TRIP pushbutton on ATC C04.
CRS Direct actions from the ESAS Procedure, 1202.010.
ATC 1. Check adequate SCM.
BOP 2. Verify proper ESAS actuation (RT-10).
- 3. IF Makeup Tank level drops below 18", THEN close Makeup Tank Outlet ATC (CV-1275).
- 4. IF ESAS actuated on high RB press alone AND a steam or feed leak is indicated, THEN perform the following:
CRS A. IF 4160V bus A1 or A2 is energized, THEN GO TO 1202.003, "OVERCOOLING" procedure.
EVENT 7 & 8 CONTINUED Page 14 of 18
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event 7 & 8 CONTINUED Event
Description:
A Main Steam Line rupture inside containment.
Channel 6 of ESAS fails to auto actuate. ICW valve CV-2214 fails to close.
Time Position Applicants Actions or Behavior ATC Verify proper actuation of ESAS per RT 10.
EXAMINER NOTE:
The following are actions that the CRS will direct from the Overcooling procedue.
CRS Transition to Overcooling Emergency Operating procedure (1202.003).
CRS Uses floating step to perform step 7.
CRS 7. Check ESAS ACTUATION alarms clear on K11.
CRS 7. (Contingency) Perform the following:
CRS A. Perform the following to throttle HPI:
BOP CV-1300 CV-1301
- 2) IF ES HPI pump is only HPI pump in service OR HPI pump BOP recirc flow path to Makeup Tank is unavailable, THEN maintain HPI pump flow 90 gpm.
CV-1219 CV-1220 CV-1278 CT BOP CV-1279 CV-1227 CV-1228 CV-1284 CV-1285 Criteria - HPI throttled prior to pressurizer going solid.
CRS B. Verify proper ESAS actuation (RT-10).
Page 15 of 18
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event 7 & 8 CONTINUED Event
Description:
Main Steam Line rupture inside containment.
Channel 6 of ESAS fails to auto actuate. ICW valve CV-2214 fails to close.
Time Position Applicants Actions or Behavior EXAMINER NOTE:
The following are actions that the BOP will take during performance of RT-10.
- 1. Verify BWST T3 Outlets open:
BOP CV-1407 CV-1408
- 2. Verify SERV WTR to DG1 and DG2 CLRs open:
BOP CV-3806 CV-3807
- 3. IF any RCP is running, THEN perform the following:
BOP A. IF ES Channel 5 or 6 has actuated, THEN perform the following:
- 1) IF SCM is adequate, THEN trip all running RCPs due to loss of ICW:
BOP P-32A P-32B P-32C P-32D
- 4. Verify proper ESAS Channels tripped:
BOP RB press 18.7 psia - 1,2,3,4,5,6
- 5. Perform the following:
A. Verify each component properly actuated on C16 and C18, except BOP those overridden in previous steps.
B. Verify proper ES system flow rates.
Identify and report failure of CV-2214, green train RB Outlet, Nuclear ICW, BOP (C18) to close.
Direct the BOP to verify the redundant valve on Channel 6, CV-2215 (C16)
CRS closed.
CRS Acknowledges that isolation function is met due to CV-2215 being closed.
CRS Returns to step 1 of 1202.003, Overcooling.
ATC 1. Check adequate SCM.
EVENT 7 & 8 CONTINUED Page 16 of 18
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event 7 & 8 CONTINUED Event
Description:
Main Steam Line rupture inside containment.
Channel 6 of ESAS fails to auto actuate. ICW valve CV-2214 fails to close.
Time Position Applicants Actions or Behavior
- 2. Open BWST T3 Outlet to OP HPI pump (CV-1407 or CV-1408).
- 3. Check Pressurizer Level Control valve (CV-1235) maintains PZR level ATC 55.
(Level will be high due to Full HPI actuation)
ATC 4. Check RCS press remains 1700 psig.
ATC 5. Check RCS T-cold 430°F.
ATC 6. Control RCS press within limits of Figure 3 (RT-14).
CRS 7. (Previously Performed).
ATC 8. Check MSSV OPEN (K07-C5) alarm clear.
ATC 9. Check RB press < 17 psia and stable.
CRS 9. (Contingency) Perform the following for bad SG:
A. Place bad SG EFW ISOL valves in MANUAL AND verify closed (modulating valves):
ATC CV-2627 CV-2670 ATC B. Actuate EFW.
C. Actuate MSLI for bad SG AND verify proper actuation and control ATC (RT-6).
CRS Provide RT6 to ATC to verify proper MSLI and EFW actuation and control.
BOP Verify proper MSLI and EFW actuation and control per RT6.
EVENT 7 & 8 CONTINUED Page 17 of 18
Appendix D Scenario Outline Form ES-D-1 Op-Test No.: 2013-1 Scenario No.: 4 Event 7 & 8 CONTINUED Event
Description:
Main Steam Line rupture inside containment.
Channel 6 of ESAS fails to auto actuate. ICW valve CV2214 fails to close.
Time Position Applicants Actions or Behavior D. Maximize RB cooling (RT-9).
CRS (Already done due to ESAS actuation)
E. IF EFW is in service, THEN trip both MFW pumps:
ATC Main Feed Pump A Main Feed Pump B EXAMINER NOTE:
The overcooling will terminate when the A SG boils dry and is indicated by CET temperatures rising.
CRS F. IF overcooling is terminated, THEN GO TO step 25.
- 25. WHEN overcooling is terminated, THEN perform the following for each CRS SG:
EXAMINER NOTE:
If it is directed to start the Startup Boiler, start it using remote SUBOILER to ON.
A. IF MSIV is open AND TURB BYP Valves are available, THEN ATC operate TURB BYP Valves as necessary to prevent RCS heatup.
A. Contingency - Perform the following:
- 1) Operate ATM Dump Control System as necessary to prevent RCS heatup:
ATM isol - CV-2619 ATC ATM isol - CV-2618 a) Place TURB BYP Valves for SG(s) with closed MSIV in HAND AND close to prevent loss of condenser vacuum ATC B. Check feedwater aligned for each SG.
EVENT AND SCENARIO TERMINATION CRITERIA RCS pressure and temperature have been stablized with the A OTSG isolated AND Channel 6 of ESAS manually actuated AND ICW flowpath isolated OR As determined by the Lead Evaluator.
Page 18 of 18
ES-301 Competencies Checklist Form ES-301-6 Facility: ANO Date of Examination:2/25/2013 Operating Test No.: 2013-1 APPLICANTS RO RO RO RO R3, R5 R1, R6 R7, R8 R2, R4 SCENARIO SCENARIO SCENARIO SCENARIO Competencies 4 1 2 4 1 2 4 1 2 4 1 2 Interpret/Diagnose 2, 3, 5, 6, 7, 8 2, 4, 5, 7, 8
N/A 2, 5, 6,7,8 1, 2, 4, 5, 6, 8 4, 5, 6, 7, 9, 10 2, 3, 5, 6, 7, 8 N/A 4, 5, 6, 7, 8, 9, 10 2, 5, 6,7,8 1, 2, 4, 5, 6, 8 N/A Events and Conditions 1, 2, 3, 4, Comply With and 1, 2, 3, 5, 6, 7, 8 3, 4, 5, 7 N/A 2, 5, 6, 7, 8
1, 4, 5, 6, 8
5, 6, 7, 9, 1, 2, 3, 5, 6, 7, 8 N/A 3, 4, 6, 7, 8, 9, 10 2, 5, 6, 7, 8
1, 4, 5, 6, 8
N/A Use Procedures (1) 10 Operate Control 1, 2, 5, 6, 7, 8 3, 4, 5, 7 N/A 2, 4, 5, 6, 7, 8 1, 2, 5, 6, 8
1, 2, 5, 7, 9, 10 1, 2, 5, 6, 7, 8 N/A 3, 4, 6, 7, 8, 9 2, 4, 5, 6, 7, 8 1, 2, 5, 6, 8
N/A Boards (2) 1, 2, 3, 4, 1, 2, 3, 4, Communicate 1, 2, 3, 4, 5, 6, 7, 8 1, 2, 3, 4, 5, 6, 7, 8 N/A 1, 2, 3, 4, 5, 6, 7, 8 1, 2, 3, 4, 5, 6, 8 5, 6, 7, 9, 1, 2, 3, 4, 5, 6, 7, 8 N/A 5, 6, 7, 8, 1, 2, 3, 4, 5, 6, 7, 8 1, 2, 3, 4, 5, 6, 8 N/A and Interact 10 9, 10 Demonstrate N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A Supervisory Ability (3)
Comply With and N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A Use Tech. Specs. (3)
Notes:
(1) Includes Technical Specification compliance for an RO.
(2) Optional for an SRO-U.
(3) Only applicable to SROs.
Facility: ANO Date of Examination: 2/25/2013 Operating Test No.: 2013-1 APPLICANTS SRO-I SRO-U SRO-U S1, S2 U1, U4 U2-U3 SCENARIO SCENARIO SCENARIO Competencies 4 1 2 4 1 2 4 1 2 Interpret/Diagnose 2, 3, 4, 5, 6, 7, 8,
2, 4, 5, 7, 8 N/A N/A 1, 2, 4, 5, 6, 7, 8
4, 5, 6, 7, 8, 9, 10 2, 3, 4, 5, 6, 7, 8,
1, 2, 4, 5, 6, 7, 8
N/A Events and Conditions Comply With and 2, 3, 4, 5, 6, 7, 8,
3, 4, 5, 7 N/A N/A 1, 2, 3, 4, 5, 6,
,7, 8 1, 2, 3, 4, 5, 6, 7, 8, 9, 10 2, 3, 4, 5, 6, 7, 8,
1, 2, 3, 4, 5, 6,
,7, 8 N/A Use Procedures (1)
Operate Control N/A 3, 4, 5, 7 N/A N/A N/A N/A N/A N/A N/A Boards (2)
Communicate 1, 2, 3, 4, 5, 6, 7, 8, 1, 2, 3, 4, 5, 6, 7, 8 N/A N/A 1, 2, 3, 4, 5, 6,
,7, 8 1, 2, 3, 4, 5, 6, 7, 8, 9, 10 1, 2, 3, 4, 5, 6, 7, 8, 1, 2, 3, 4, 5, 6,
,7, 8 N/A and Interact Demonstrate 1, 2, 3, 4, 5, 6, 7, 8 N/A N/A N/A 1, 2, 3, 4, 5, 6,
,7, 8 1, 2, 3, 4, 5, 6, 7, 8, 9, 10 1, 2, 3, 4, 5, 6, 7, 8 1, 2, 3, 4, 5, 6,
,7, 8 N/A Supervisory Ability (3)
Comply With and 3, 4, 8 N/A N/A N/A 1, 2, 7, 8 4, 6, 8, 10 3, 4, 8 1, 2, 7, 8 N/A Use Tech. Specs. (3)
Notes:
(1) Includes Technical Specification compliance for an RO.
(2) Optional for an SRO-U.
(3) Only applicable to SROs.
Instructions:
Check the applicants license type and enter one or more event numbers that will allow the examiners to evaluate every applicable competency for every applicant.