ML13301A736
| ML13301A736 | |
| Person / Time | |
|---|---|
| Site: | Summer  |
| Issue date: | 10/23/2013 |
| From: | NRC/RGN-II |
| To: | South Carolina Electric & Gas Co |
| References | |
| Download: ML13301A736 (134) | |
Text
2013 NRC Scenario 1 Scenario Outline Form ES-D-1 Facility: VC SUMMER Scenario No.: 1 Op Test No.: NRC ILO 11-01 Examiners: Operators: CRS:
RO:
BOP:
Initial 100% MOL Conditions: Alternate Seal Injection is OOS B Train workweek Severe thunderstorms have been reported in the area Turnover: Reduce power to < 90% to allow for Turbine valve testing by the next shift.
Critical Task: Isolate B SG PORV prior to B SG Pressure less than 460 psig.
Terminate SI before SG level reaches EOP SG level for steam line
- (87% NR).
Stop RCPs if RCS pressure is < 1418 psig and before WR 33% RVLIS.
Event Malf. No. Event Type* Event No. Description N - BOP, 1 N/A CRS Lower Power IAW GOP-4B for Turbine Valve Testing R - RO I - BOP, CRS 2 PCS003B B SG Level Inst Failure LT-486 Fails HIGH TS - CRS I - RO, BOP, PT-446 (Controlling turbine first stage pressure transmitter) fails to 0 3 TUR012A CRS over 15 seconds TS -CRS EHC Pump trips (BU does not auto-start and must be manually 4 TUR011A C - BOP started)
C-RO, CRS 5 RCS002A SGTL on A SG (12 gpm leak - greater than TS leakage limit)
TS-CRS A SG SGTR (a ramp increase in the SGTL until a SGTR is 6 RCS002A M - ALL apparent and large enough to cause a Safety Injection Actuation)
SG B Pressure Transmitter PT-2010 Fails HIGH resulting in the 7 MS035O opening of a B Steam Generator PORV.
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
- Additional Critical Task:
Maintain "B" SG level following LT-486 failure such that an unnecessary reactor trip is NOT required.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Scenario Outline Form ES-D-1 The following notation is used in the ES-D-2 form Time column:
IOA designates Immediate Operator Action steps
- designates Continuous Action steps The crew will assume the watch having been pre-briefed on the Initial Conditions, the plan for this shift and any related operating procedures.
EVENT 1: Lower Power to Conduct Turbine Valve Testing The crew will lower power from 100% to less than 90% in accordance with GOP-4B, Power Operation MODE 1 - Descending.
EVENT 2: B SG Level Transmitter Fails HIGH On cue from the Examiner, B SG level transmitter will fail HIGH, requiring manual control of the B SG Feedwater Regulating Valve to maintain/restore SG level to between 60% and 65% and prevent a reactor trip.
The crew will enter AOP-401.11, Steam Generator Level Control and Protection Channel Failure, and remove the channel from service.
The CRS will refer to Tech Specs 3.3-1, Item 13 (Action 6) and 3.3-3, Items 5, 6c (Action 24) to determine that the protection bistables for the failed channels must be placed in the TRIPPED condition with 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.
EVENT 3: Turbine 1st Stage Pressure Transmitter Fails LOW On cue from the Examiner, PT-446 (Selected turbine first stage pressure transmitter) will fail LOW. The failure causes a Tave - Tref mismatch resulting in rods inserting at the maximum speed.
The crew will enter AOP-401.7, Turbine First Stage Pressure Channel Failure.
The RO will place rod control in manual and maintain Tave within 1 degree of Tref. The RO will then select the operable 1st stage pressure channel for control. The RO may restore automatic rod control after the operable channel is selected.
The BOP will control B Steam Generator NR level and change the Steam Dump Mode to Steam Pressure.
EVENT 4: Running EHC pump trips on overload (Backup pump does not start in auto)
On cue from the Examiner, the running EHC pump will trip and the backup pump will not start in auto.
The BOP will recognize the condition from annunciator XCP-631 1-4, EHC PP A Motor Ovrld, or determine the cause of the event, and take corrective action by starting the backup EHC pump to prevent turbine stop valves from closing.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Scenario Outline Form ES-D-1 EVENT 5: A SGTL On cue from the Examiner, a steam generator tube leak will begin. The tube leak on the SG A will initiate and stabilize at 12 GPM. The crew will respond to indications of RCS inventory loss/rising secondary-side radiation and enter AOP-112.2, Steam Generator Tube Leak Not Requiring SI. The crew will estimate SGTL as greater than the TS limit and the CRS will enter TS 3.4.6.2.c. The RO will stabilize PZR level by increasing charging and minimizing letdown. The CRS will direct a shutdown to HOT STANDBY in accordance with the requirements of AOP-112.2 since the shutdown rate specified by that procedure is greater than that specified by the TS.
EVENT 6: A SGTR On cue from the Examiner, a steam generator tube rupture will occur. The crew will recognize the increase in tube leakage greater than the capacity of the charging pumps. The crew will trip the reactor/turbine and implement EOP-1.0 (E-0), Reactor Trip/Safety Injection Actuation. The crew will transition to EOP-4.0 (E-3), Steam Generator Tube Rupture. In EOP-4.0 (E-3), isolate the A SG and cool down and depressurize the RCS to terminate break flow.
EVENT 7: B SG Pressure Transmitter PT-2010 Fails HI Event 7 is triggered automatically after the reactor trip. The BOP may identify the PT-2010 indicates 1300 psig and/or the B SG Power Operated Relief Valve (PORV) indicates open. The operator will place the controller to manual and close the PORV.
If the failure is not identified the crew may transition to EOP 3.0 (E-2), Faulted Steam Generator Isolation, to isolate the SG.
CRITICAL TASKS:
It is a critical task to Isolate B SG PORV prior to B SG Pressure less than 460 psig.
It is critical to terminate Safety Injection prior to the A steam generator reaching the level of the steamline to preclude failure of the steam line. This level, including tolerances, is 87% NR in the EOP network.
It is a critical task to stop RCPs if RCS pressure is < 1418 psig and before WR 33% RVLIS.
TERMINATION:
The scenario can be terminated after the crew has closed the SG PORV and Safety Injection has been terminated.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Scenario Outline Form ES-D-1 SIMULATOR SCENARIO SETUP Initial Conditions:
100% power MOL, IC set 320 is main snap.
Prior to the scenario, crew should pre-brief on conditions and expectations for the Shift (maintain power, repairs estimated to be complete well before LCO action time expires.
Rod Position = 230 steps withdrawn Boron = 1000 ppm FCV113 Pot Setting = 4.29 Xe = - 2700 pcm Burnup = 10010 MWD/MTU = 226 EFPD Prior to the scenario, crew should pre-brief on conditions and expectations for the Shift (maintain power, repairs estimated to be complete well before LCO action time expires).
VC Summer 2013 NRC Scenario 1 Simulator Setup (SNAP 320)
Conduct two-minute drill Mark up procedures in use with Circle and slash as applicable Pre-Exercise:
Ensure simulator has been checked for hardware problems (DORT, burnt out light bulbs, switch malfunctions, chart recorders, etc.)
TQP-801 Booth Operator checklist, has been completed Hang Red Tags for equipment out of service PRE-LOAD:
Standard Simulator Setup PMP-LD003P XPP0138 LEAK DETECTION SUMP PMP LOSS OF POWER VLV-FW028W XVG01676-FW FW HDR RECIRC ISOL VLV LOSS OF POWER VLV-FW029W XVG01679-FW FW HTR RECIRC ISO VLV LOSS OF POWER VLV-CS052W XVT08141A-CS RCP A SEAL LEAKOFF VLV LOSS OF POWER VLV-CS054W XVT08141C-CS RCP C SEAL LEAKOFF VLV LOSS OF POWER VLV-CS053W XVT08141B-CS RCP B SEAL LEAKOFF VLV LOSS OF POWER Scenario Related P12 Overrides BST-RC068 LL TA P12 Fail to: INHIBITED Delay=0 Delete=0 BST-RC075 LL TA P12 Fail to: INHIBITED Delay=0 Delete=0 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Scenario Outline Form ES-D-1 EVENT 1: Lower Power IAW GOP-4B for Turbine Valve Testing NO Trigger This is a Normal/Reactivity evolution.
EVENT 2: B SG Level Inst Failure LT-486 Fails HIGH TRIGGER 2 o MAL-PCS003B: STEAM GENERATOR CONTROL FAILURE (CHANNEL 486)
Final=100 It takes about 1 minute without operator action to cause trip without a ramp. Annunciators come in immediately and should not be a problem.
EVENT 3: PT-446 (Controlling Turbine 1st Stage Pressure Transmitter) Fails Low TRIGGER 3 o MAL-TUR012A: TURBINE IMPULSE PRESSURE TRANSMITTER PT-446 FAILURE Ramp=15 sec, Final=0 It takes about 40 seconds to get to LO-LO limit and plant will trip at about 1 min 45 seconds.
Booth Operator: When called as I&C to place AMSAC in bypass. Reply that I&C will place AMSAC in bypass. Wait 5 minutes. Call the control room and report you are ready to BYPASS AMSAC (the control room will receive a trouble alarm when AMSAC is bypassed. Insert TRIGGER 10.
TRIGGER 10 o ANN-MI007 AMSAC GENERAL WARNING Final=ON EVENT 4 : EHC Pump trips (BU does not auto-start and must be manually started)
TRIGGER 4 o MAL-TUR011A: LOSS OF EHC HYDRAULIC FLUID PUMP A Final=Active o PMP-EH002F: XPP0003-PP2 HFM PMP B FAIL TO START Final=Active Trip occurs after 1 min 30 seconds if not mitigated.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Scenario Outline Form ES-D-1 EVENT 5: SGTL on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control)
TRIGGER 5 o MAL-RCS002A: STEAM GENERATOR A TUBE LEAK Final =12 Booth Operator: XCP-646 2-1 will have HP do survey of steam lines; Report elevated readings on A steam line after 10 minutes. Chemistry sample of steam generators will show elevated on A activity after 30 minutes (frisker results if desired will take 10 min).
If asked to put condenser exhaust to AB exhaust report after 5 min that aligned to AB charcoal exhaust.
EVENT 6: A SG SGTR (a ramp increase in the SGTL until a SGTR is apparent and large enough to cause a Safety Injection Actuation)
TRIGGER 6 o MAL-RCS002A: STEAM GENERATOR A TUBE LEAK Ramp=2 min, Initial=12 Final=600 EVENT 7: SG B Pressure Transmitter PT-2010 Fails HIGH resulting in the opening of a Steam Generator PORV.
EVENT 7: Power Indication N-42 < 10% FNISPR(2)<10 TRIGGER 7 o XMT-MS036O: IPT02010 MS LINE B PRESS PI-2010 FAIL TO POSN Final=1300 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 1 Page 7 of 48 Event
Description:
Lower Power IAW GOP-4B for Turbine Valve Testing Time Position Applicants Actions or Behavior BOOTH OPERATOR:
No triggers are required for Event 1 Indications Available: N/A EVALUATOR NOTE:
This is a Normal evolution - After it has been determined that the operators have demonstrated their competencies the next event can be triggered Implement GOP-4B, POWER OPERATION (MODE 1 - GOP-4B CRS DESCENDING) to reduce power to 90% for Turbine Valve Testing.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 1 Page 8 of 48 Event
Description:
Lower Power IAW GOP-4B for Turbine Valve Testing Time Position Applicants Actions or Behavior GOP-4B Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 1 Page 9 of 48 Event
Description:
Lower Power IAW GOP-4B for Turbine Valve Testing Time Position Applicants Actions or Behavior CAUTION 3.1 through 3.12 GOP-4B
- a. Thermal Power changes of greater than 15% in any one-hour period requires completion of GTP-702 Attachment III.H.
- b. VCS PID Report, POWER CHANGE SEARCH, should be periodically performed to ensure a thermal power change of greater than 15% in any one-hour period is detected.
NOTE 3.1 through 3.12 GOP-4B
- a. Step 3.1 lowers Reactor Power from 100% to 90%.
- b. If the RCS will be opened for maintenance during the shutdown, degassing of the RCS should be initiated per SOP-102, Chemical And Volume Control System.
- c. The setpoint for IFK3136, FLOW TO DEAERATOR, should be adjusted during power changes to maintain LI-3136, DEAER STOR TK NR LVL, between 2.5 and 5.0 feet.
CREW Reduce Reactor Power to 90% as follows: GOP-4B EVALUATOR NOTE: Applicable portions of SOP-214, MAIN TURBINE AND CONTROLS, are attached (Page 45).
Using the EHC HMI, Control/Load screen, reduce load per SOP- GOP-4B BOP 214 at a rate of 1% per minute or less.
NOTE 3.1.b GOP-4B The System Controller should be notified prior to manually changing MVARs by more than 50 MVARs in a five minute period, unless the change is needed to prevent equipment damage.
As load decreases, adjust Megavars using GEN FIELD VOLT ADJ GOP-4B BOP as requested by the System Controller and within the Estimated Generator Capability Curve (Enclosure A).
Maintain Tavg within the control band by Control Rod motion or GOP-4B RO boron concentration changes.
EVALUATOR NOTE: Applicable portions of SOP-106, DILUTION OPERATIONS, are attached (Page 43).
Borate or dilute per SOP-106, Reactor Makeup Water System, to GOP-4B maintain the following parameters:
- 1) I within limits.
- 2) Control Rods above the Rod Insertion Limit.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 1 Page 10 of 48 Event
Description:
Lower Power IAW GOP-4B for Turbine Valve Testing Time Position Applicants Actions or Behavior Monitor Steam Generator Blowdown Condensate return GOP-4B BOP temperature for proper operation as DA temperature is lowered.
BOP Ensure MSRs are in Temp Ramp mode. GOP-4B Monitor MSR temperatures and Main Turbine vibration levels GOP-4B BOP closely as Main Turbine load is reduced.
CAUTION 3.1.h GOP-4B To minimize stress in the Low Pressure Turbines, Hot Reheat Steam temperature changes must be limited to 125°F/hr.
If necessary, manually control MSRs per SOP-204, Extraction GOP-4B BOP Steam, Reheat Steam, Heater Vents And Drains, maintaining MSR temperatures on program If desired, stabilize at 90% Reactor Power, otherwise proceed to GOP-4B CREW Step 3.2.
EVALUATOR NOTE:
The next event may be triggered after a significant power change has been observed.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 2 Page 11 of 48 Event
Description:
B SG Level Inst Failure LT-486 Fails HIGH Time Position Applicants Actions or Behavior BOOTH OPERATOR: Initiate Event 2 (TRIGGER 2) when directed.
Indications Available:
XCP-624 2-5, SG B LVL DEV XCP-624 2-1, SG B LVL HI-HI BOP Enters ARP-001-XCP-624 2-5 SG B LVL DEV XCP-624 2-5 CORRECTIVE ACTIONS: XCP-624 2-5 BOP If required, restore Steam Generator B level to between 60% and XCP-624 2-5 65% by performing either or both of the following:
- a. Manually control PVT-488, SG B FWF, as required.
- b. Manually control Feedwater Pump speed as follows:
- 1) Place the Feedwater Pump MASTER SPEED CNTRL in MAN.
- 2) Adjust the differential pressure between Feedwater Pump discharge header pressure and Main Steam header pressure, as required, to restore Steam Generator water level.
BOP Evaluate SG B Narrow Range level indicators LI-484, LI-485, and XCP-624 2-5 LI-486:
For decreasing level: XCP-624 2-5
- 1) At 45% Narrow Range level:
(a) Manually control PVT-488, SG B FWF, as required.
(b) Ensure feed flow is greater than steam flow by 200 kbh BOP to 400 kbh.
- 2) At 40% Narrow Range level:
(a) Trip the reactor.
(b) Ensure both Motor Driven Emergency Feed pumps are in service to deliver full system flow.
BOP If FCV-488, B FCV, malfunctioned go to AOP-210.1, Feedwater XCP-624 2-5 Flow Control Valve Failure. [NO]
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 2 Page 12 of 48 Event
Description:
B SG Level Inst Failure LT-486 Fails HIGH Time Position Applicants Actions or Behavior BOP If a Main Feedwater Pump has tripped or is malfunctioning go to XCP-624 2-5 AOP-210.3, Feedwater Pump Malfunction. [NO]
CRS If an instrument channel has failed, go to AOP-401.11, Steam XCP-624 2-5 Generator Level Control And Protection Channel Failure.
Implement AOP-401.11, STEAM GENERATOR LEVEL CONTROL AOP-401.11 CRS AND PROTECTION CHANNEL FAILURE Adjust the Feedwater Flow Control Valve as necessary to restore AOP-401.11 IOA BOP Narrow Range level in the AFFECTED SG to between 60% and 65%.
CRS Within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, place the failed channel protection bistables in a AOP-401.11 tripped condition:
CRS a. Identify the associated bistables for the failed channel. REFER AOP-401.11 TO Attachment 1.
Excerpt from AOP-401.11 Attachment 1 AOP-401.11 EVALUATOR NOTE: Attachment excerpt from Table 3.3-1 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 2 Page 13 of 48 Event
Description:
B SG Level Inst Failure LT-486 Fails HIGH Time Position Applicants Actions or Behavior EVALUATOR NOTE: Attachment excerpt from Table 3.3-3 Refers to Technical Specification Table 3.3-1 and Table 3.3-3. TECH SPEC CRS Determines that the inoperable channel must be placed in a 3.3.1 and 3.3.2 tripped condition within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 2 Page 14 of 48 Event
Description:
B SG Level Inst Failure LT-486 Fails HIGH Time Position Applicants Actions or Behavior
- b. Record the following for each associated bistable on SOP-401, SOP-401 REACTOR PROTECTION AND CONTROL SYSTEM, Attachment I:
CRS Instrument.
Associated Bistable Bistable Location STPs CRS Complete SOP-401 Attachment I. SOP-401 BOOTH OPERATOR:
Acknowledge requests for assistance and inform the crew that support personnel will be assigned.
EVALUATOR NOTE:
The next event may be initiated after Technical Specifications have been addressed.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 3 Page 15 of 48 Event
Description:
PT-446 (Controlling turbine first stage pressure transmitter) fails to 0 over 15 second period Time Position Applicants Actions or Behavior BOOTH OPERATOR: Initiate Event 3 (TRIGGER 3) when directed.
Indications available:
Uncontrolled Rod Motion XCP-615, 2-5, RCS TAVG-TREF HI/LO; XCP-624-4-2, 5-2, 6-2; SG A, B, C STM FLO HI EVALUATORS NOTE:
The crew could enter the ARP but it is likely that they will recognize the entry condition for AOP-401.7, TURBINE FIRST STAGE PRESSURE CHANNEL FAILURE. The BOP will control steam generator level during this event as a result of the previous failure.
AOP-401.7 CRS Enters AOP-401.7, Turbine First Stage Pressure Channel Failure EVALUATORS NOTE: If XCP-621 1-1 CRB INSERT LMT LO-LO is received the RO will immediately Emergency Borate per AOP-106.1, Emergency Boration until Shutdown Margin is restored.
AOP-401.7 IOA RO Place Rod Control Bank Select Switch to MANUAL AOP-401.7 Ensure TREF 1ST STG PRESS switch is positioned to the operable channel:
OR PT-447, CH IV AOP-401.7 RO Adjust Control Rods until Tavg is within 1.0° F of Tref.
AOP-401.7 BOP Check if Main Turbine load is greater than 10%
AOP-401.7 Within one hour, verify the following permissives are dim:
CRS P-13, 1st STG PRESS P-7, REACTOR TRIP BLOCKED EVALUATOR NOTE: Due to the windup (integral) characteristic of the Rod Control function, the crew may not immediately place rods back in automatic.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 3 Page 16 of 48 Event
Description:
PT-446 (Controlling turbine first stage pressure transmitter) fails to 0 over 15 second period Time Position Applicants Actions or Behavior AOP-401.7 RO Restore automatic rod control.
AOP-401.7 BOP Place Steam Dump Mode Select Switch in STM PRESS.
BOOTH OPERATOR:
Acknowledge requests for support.
Wait 3 minutes Call for permission to proceed.
Use TRIGGER 10 to place AMSAC in BYPASS Report completion.
AOP-401.7 CRS Notify I&C to place AMSAC in BYPASS.
Within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, place the failed channel protection bistables in a AOP-401.7 CRS tripped condition:
AOP-401.7 Identify the associated bistables for the failed channel. REFER TO CRS Attachment 1.
EVALUATOR NOTE: Attachment excerpt for reference Record the following for each associated bistable on SOP-401, AOP-401.7 REACTOR PROTECTION AND CONTROL SYSTEM, Attachment I:
CRS Instrument Associated Bistable.
Bistable Location.
STPs.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 3 Page 17 of 48 Event
Description:
PT-446 (Controlling turbine first stage pressure transmitter) fails to 0 over 15 second period Time Position Applicants Actions or Behavior EVALUATOR NOTE: Attachment excerpt from TS Table 3.3-1 EVALUATOR NOTE: Attachment excerpt from TS Table 3.3-3 Tech Spec Table 3.3-1 Action 7 3.3.1 Refers to Technical Specification Table 3.3-1 and within one hour CRS determines by observation of the associated permissive annunciator window(s) that the interlock is in its required state for the existing plant condition.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 3 Page 18 of 48 Event
Description:
PT-446 (Controlling turbine first stage pressure transmitter) fails to 0 over 15 second period Time Position Applicants Actions or Behavior Tech Spec Table 3.3-3 Action 24 3.3.2 CRS Refers to Technical Specification Table 3.3-3 and determines that the inoperable channel must be placed in a tripped condition within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.
BOOTH OPERATOR:
Acknowledge requests for assistance and inform the crew that support personnel will be assigned.
AOP-401.7 Notify I&C to place the failed channel protection bistables in a tripped condition within 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />s:
CRS FB-474A FB-484A FB-494A EVALUATOR NOTE:
The next event may be initiated after I&C is called to trip the bistables.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 4 Page 19 of 48 Event
Description:
EHC Pump trips (BU does not auto-start and must be manually started)
Time Position Applicants Actions or Behavior BOOTH OPERATOR: Initiate Event 4 (TRIGGER 4) when directed.
Indications available:
Control Switch Red and Green lights XCP-631, 1-4, EHC PP A MOTOR OVRLD XCP-631, 1-2, EHC FLUID PRESS LO BOP Enters ARP-001-XCP-631 1-4 XCP-631 1-4 AUTOMATIC ACTIONS: XCP-631 1-4 BOP 1. The pump may trip if the condition is not corrected.
- 2. If the pump trips, the standby pump starts at 1300 psig.
CORRECTIVE ACTIONS: XCP-631 1-4 If EHC PUMP A is still running, verify high amps. [NO] (EHC Pump XCP-631 1-4 BOP A has tripped)
BOP Start EHC PUMP B and observe motor amps. XCP-631 1-4 If EHC PUMP A is still running with higher amps than EHC PUMP XCP-631 1-4 BOP B, secure EHC PUMP A and continue to monitor EHC PUMP B
[NO] (N/A A Pump tripped)
BOOTH OPERATOR:
If called to investigate the EHC pump failure - report no fault is apparent.
If called to investigate the EHC system for leaks - report no EHC leaks.
BOP Dispatch an operator to check for EHC System leaks. XCP-631 1-4 EVALUATOR NOTE: The failure of the backup EHC pump to auto-start results in EHC pressure continuing to decrease. The Low Pressure alarm will alert operators to the failure - if not previously discovered - however this alarm provides no additional operator actions BOP Respond to alarm EHC FLUID PRESS LO (XCP-631, 1-2) XCP-631 1-4 EVALUATOR NOTE: The next event may be initiated after the B EHC pump is started.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 5 Page 20 of 48 Event
Description:
SGTL on A SG (12 gpm leak - greater than TS leakage limit)
Time Position Applicants Actions or Behavior BOOTH OPERATOR: Initiate Event 5 (TRIGGER 5) when directed.
Indications available:
XCP-646, 2-1, MN STM LINE RM-G19 HI RAD BOP Respond to alarm XCP-646, 2-1, MN STM LINE RM-G19 HI RAD XCP-646 2-1 CORRECTIVE ACTIONS: XCP-646 2-1 Verify the alarm is valid and identify the Main Steam line affected by XCP-646 2-1 BOP observing RM-G19A, B, and C and R/R-8.
Request Health Physics perform radiological surveys around the XCP-646 2-1 CRS Main Steam lines.
CRS Direct Chemistry to sample all Steam Generators for activity. XCP-646 2-1 Align the condenser exhaust to the Auxiliary Building Charcoal XCP-646 2-1 Exhaust as follows:
- b. Close XVB00109-AR, MN&AUX COND VAC PUMP ATMOS DISCH VALVE (TB-436).
BOP Reduce all Steam Generator blowdown flows to minimum. XCP-646 2-1 BOP If in service, secure the Condensate Polishing System per SOP-203. XCP-646 2-1 SUPPLEMENTAL ACTIONS: XCP-646 2-1
- 1. If the alarm is valid, refer to AOP-112.2. (YES)
- 2. If the alarm is invalid, remove RM-G19A, B or C from service per SOP-124. [NO]
- 3. Refer to Technical Specification 3.3.3.1.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 5 Page 21 of 48 Event
Description:
SGTL on A SG (12 gpm leak - greater than TS leakage limit)
Time Position Applicants Actions or Behavior BOOTH OPERATOR:
Acknowledge request for HP to perform surveys around the Main Steam lines.
o Wait 10 min and then report elevated background activity on A SG.
Acknowledge request for Chemistry to sample all SGs for activity.
o Wait 30 min and then report elevated activity on A SG.
Report in 10 minutes if requested to use a frisker.
Acknowledge request to put condenser exhaust to AB exhaust.
o Wait 5 min to report that the condenser exhaust is aligned to Auxiliary Building Charcoal Exhaust Implement AOP-112.2, Steam Generator Tube Leak Not Requiring AOP-112.2 CRS SI
- 1. Check if PZR level can be maintained: AOP-112.2
- a. Open FCV-122, CHG FLOW, as necessary to maintain PZR
- RO level.
- b. Verify PZR level is at or trending to program level Check if SI is required: AOP-112.2 Check if any of the following criteria are met: (NO)
PZR level is decreasing with Charging maximized and Letdown isolated.
- CRS/RO PZR level is approaching 8%.
OR PZR pressure is approaching 1870 psig.
ALTERNATIVE ACTION GO TO step 3 AOP-112.2
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 5 Page 22 of 48 Event
Description:
SGTL on A SG (12 gpm leak - greater than TS leakage limit)
Time Position Applicants Actions or Behavior IF Steam Generator primary to secondary tube leakage has not AOP-112.2 been determined, THEN perform the following:
- b. Calculate the RCS leak rate. REFER TO STP-114.002, OPERATIONAL LEAK TEST.
- c. Comply with the applicable Tech Spec 3.4.6.2 action statement.
Excerpt from TS 3.4.6.2 Refers to Technical Specification 3.4.6.2 and determines that Tech Spec leakage exceeding 150 gallons per day primary-to-secondary 3.4.6.2 CRS leakage through any one steam generator requires the unit be in at least HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
BOOTH OPERATOR: Acknowledge request to sample all SG secondary sides for activity.
CRS Notify Chemistry to sample all SG secondary sides for activity. AOP-112.2 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 5 Page 23 of 48 Event
Description:
SGTL on A SG (12 gpm leak - greater than TS leakage limit)
Time Position Applicants Actions or Behavior NOTE - Step 6 AOP-112.2 Rate of plant shutdown must be evaluated based on magnitude of RCS leak rate (Steam Generator primary to secondary tube leakage).
Steam Generator primary to secondary tube leakage rate, and rate of increase, is represented by the following IPCS Computer points:
- a. UR1019, S/G LEAKAGE FROM RMA9 (in gpd).
- b. UR1019-R, S/G LEAKAGE FROM RMA9-RATE (in gpd/hr).
Conditions for implementing Emergency Plan Procedures should be evaluated using EPP-001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN.
Due to N-16 gamma radiation effects, RM-G19A(B)(C), STMLN HI RNG GAMMA, will display elevated readings and should not be used for classification of EAL while the Reactor is critical.
IF RCS leak rate (Steam Generator primary to secondary tube AOP-112.2 leakage) is GREATER THAN OR EQUAL TO 75 gpd (YES) (.05 gpm), THEN initiate a plant shutdown per the following table using GOP-4B, POWER OPERATION (MODE 1 DESCENDING).
CRS Determines that leakage is 150 gpd and directs actions to be in AOP-112.2 CRS Mode 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> at 1/2% or 1% per minute.
Initiate a Reactor shutdown: REFER TO GOP-4B POWER AOP-112.2 CRS OPERATION (MODE 1 - DESCENDING) while continuing with this procedure.
EVALUATOR NOTE: The next event may be initiated after the decision is made to shut down the unit IAW GOP-4B POWER OPERATION (MODE 1 - DESCENDING)
Appendix D NUREG 1021 Revision 9
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Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior BOOTH OPERATOR: Initiate Event 6 (TRIGGER 6) when directed.
Indications available:
XCP-616 1-5, PZR LS Hl/LO EVALUATOR NOTE: The SG Tube Leak will increase to a 600 gpm Tube Rupture over 2 minutes.
EVALUATOR NOTE: TS 3.2.5, DNB Parameters, requires PZR Pressure > 2206 psig in Mode 1.
XCP-616 RO Responds to annunciator XCP-616 1-5, PZR LS Hl/LO 1-5 EVALUATOR NOTE: The CRS will recognize the change in plant conditions and direct action IAW the continuous action step in AOP-112.2 to check if SI is required.
BOOTH OPERATOR: If called to check the CCW Pump after start report; Good start RML-2B flow is greater than 5 gpm.
Appendix D NUREG 1021 Revision 9
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Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior
- 1 Check if PZR level can be maintained:
- a. Open FCV-122, CHG FLOW, as necessary to maintain PZR level.
- b. Verify PZR level is at or trending to program level.
ALTERNATIVE ACTION
- b. Perform the following:
- 1) Reduce Letdown to one 45 gpm orifice:
a) Place PCV-145, LO PRESS LTDN, in MANUAL.
b) Ensure PVT-8149A, LTDN ORIFICE A ISOL, is open.
c) Close both PVT-8149B(C), LTDN ORIFICE B(C) ISOL.
- RO d) Adjust PCV-145, LO PRESS LTDN, to maintain PI-145, LO PRESS LTDN PRESS PSIG, between 300 psig and 400 psig.
e) Place PCV-145, LO PRESS LTDN, in AUTO.
- 2) IF PZR level continues to decrease, THEN perform the following:
a) Close PVT-8149A, LTDN ORIFICE A ISOL.
- 3) IF PZR level continues to decrease, THEN perform the following:
a) Start a second CCW pump.
b) Start a second Charging Pump.
- 2 Check if SI is required:
- a. Check if any of the following criteria are met:
PZR level is decreasing with Charging maximized and Letdown isolated.
OR PZR level is approaching 8%.
- b. Perform the following:
- 1) Trip the Reactor.
- 2) GO TO EOP-1.0, REACTOR TRIP/SAFETY INJECTION ACTUATION. WHEN EOP-1.0 Immediate Actions are complete, THEN actuate SI.
Appendix D NUREG 1021 Revision 9
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Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior CRS directs the RO to: AOP-112.2 Trip the Reactor.
CRS GO to EOP-1.0 REACTOR TRIP/SAFETY INJECTION o When EOP-1.0 Immediate Actions are completed THEN actuate SI.
REFERENCE PAGE FOR EOP-1.0 EOP-1.0 RCP TRIP CRITERIA
- a. IF Phase B Containment Isolation has actuated (XCP-612 4-2), THEN trip all RCPs.
- b. IF both of the following conditions occur, THEN trip all RCPs:
SI flow is indicated on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM.
AND RCS Wide Range pressure is LESS THAN 1418 psig.
REDUCING CONTROL ROOM EMERGENCY VENTILATION Reduce Control Room Emergency Ventilation to one train in operation within 30 minutes of actuation. REFER TO SOP-505, CONTROL BUILDING VENTILATION SYSTEM.
MONITOR SPENT FUEL COOLING Periodically check status of Spent Fuel Cooling by monitoring the following throughout event recovery:
Spent Fuel Pool level.
Spent Fuel Pool temperature.
NOTE EOP-1.0 Steps 1 through 5 are Immediate Operator Actions.
The EOP REFERENCE PAGE should be monitored throughout the use of this procedure.
Conditions for implementing Emergency Plan Procedures should be evaluated using EPP-001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN.
- 1. Verify Reactor Trip: EOP-1.0 Trip the Reactor using either Reactor Trip Switch.
IOA RO Verify all Reactor Trip and Bypass Breakers are open (YES)
Verify all Rod Bottom Lights are lit. (YES)
Verify Reactor Power level is decreasing. (YES)
Appendix D NUREG 1021 Revision 9
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Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior
- 2. Verify Turbine/Generator Trip: EOP-1.0
IOA BOP b. Ensure Generator Trip (after 30 second delay):
- 1) Ensure the GEN BKR is open.
- 2) Ensure the GEN FIELD BKR is open.
- 3) Ensure the EXC FIELD CNTRL is tripped.
IOA BOP 3. Verify both ESF buses are energized. EOP-1.0
- a. Check if either:
IOA RO SI ACT status light is bright on XCP-6107 1-1.
OR Any red first-out SI annunciator is lit on XCP-626 top row.
- a. Check if any of the following conditions exist:
PZR pressure LESS THAN 1850 psig.
OR IOA RO RB pressure GREATER THAN 3.6 psig.
OR Steamline pressure LESS THAN 675 psig.
OR Steamline differential pressure GREATER THAN 97 psid.
EVALUATOR NOTE:
There are no failures associated with the Attachment 3 which is attached as page 46.
CRS 6. Initiate ATTACHMENT 3, SI EQUIPMENT VERIFICATION. EOP-1.0 CREW 7. Announce plant conditions over the page system. EOP-1.0 RO 8. Verify RB pressure has remained LESS THAN 12 psig on PR- EOP-1.0
Appendix D NUREG 1021 Revision 9
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Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior
- a. PZR PORVs are closed.
- b. PZR Spray Valves are closed.
RO c. Verify power is available to at least one PZR PORV Block Valve:
MVG-8000A, RELIEF 445 A ISOL.
MVG-8000B, RELIEF 444 B ISOL.
MVG-8000C, RELIEF 445 B ISOL.
- d. Verify at least one PZR PORV Block Valve is open.
NOTE - Step 11 EOP-1.0 Seal Injection flow should be maintained to all RCPs.EOP-1.0 EVALUATOR NOTE: The Critical Step of stopping RCPs is an EOP-1.0 Reference Page item and is repeated in EOP-4.0 at which time the criteria should be met.
- a. Check if either of the following criteria is met:
CRITICAL Annunciator XCP-612 4-2 is lit (PHASE B ISOL).
RO STEP OR RCS pressure is LESS THAN 1418 psig AND SI flow is indicated on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM.
EVALUATOR NOTE: If the SG PORV failure has not been previously detected, the crew may determine that a faulted generator exists and transition to EOP-3.0 first.
EVALUATOR NOTE: It is a critical Task to Isolate B SG PORV prior to SG Pressure less than 460 psig.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 6&7 Page 29 of 48 Event
Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior
No S/G is completely depressurized.
EVALUATOR NOTE: The crew will determine that a SGTR is in progress based on secondary plant radiation monitor readings and will go to EOP-4.0 SGTR If radiation levels are not high enough to indicate a SGTR is in progress the candidates may continue with EOP-1.0 until Step 21 when SG increasing NR level will direct them to EOP-4.0 SGTR.
RM-G19A(B)(C), STMLN HI RNG GAMMA.
RM-A9, CNDSR EXHAUST GAS ATMOS MONITOR RM-L3, STEAM GENERATOR BLOWDOWN LIQUID RO MONITOR.
RM-L10, SG BLOWDOWN CW DISCHARGE LIQUID MONITOR.
ALTERNATIVE ACTION
- 13. GO TO EOP-4.0, STEAM GENERATOR TUBE RUPTURE, Step 1.
CRS Direct transition to EOP-4.0, STEAM GENERATOR TUBE RUPTURE, Step 1.
Appendix D NUREG 1021 Revision 9
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Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior REFERENCE PAGE FOR EOP-4.0 EOP-4.0 1 SI REINITIATION CRITERIA IF either of the following conditions occurs, THEN start Charging Pumps and operate valves as necessary:
RCS subcooling on TI-499A(B), A(B) TEMP °F, can NOT be maintained GREATER THAN 52.5°F [67.5°F].
OR PZR level can NOT be maintained GREATER THAN 10% [28%].
IF SI Reinitiation occurs after Step 27, THEN GO TO EOP-4.2, SGTR WITH LOSS OF REACTOR COOLANT: SUBCOOLED RECOVERY DESIRED, Step 1.
2 SECONDARY INTEGRITY TRANSITION CRITERIA IF any unisolated SG pressure is decreasing in an uncontrolled manner OR is completely depressurized, THEN GO TO EOP-3.0, FAULTED STEAM GENERATOR ISOLATION, Step 1, unless it is needed for RCS cooldown.
3 COLD LEG RECIRCULATION TRANSITION CRITERION IF RWST level decreases to LESS THAN 18%, THEN GO TO EOP-2.2, TRANSFER TO COLD LEG RECIRCULATION, Step 1.
4 MULTIPLE TUBE RUPTURE CRITERIA IF any INTACT SG level increases in an uncontrolled manner OR any INTACT SG has abnormal radiation, THEN stop any cooldown or depressurization in progress and RETURN TO EOP-4.0, STEAM GENERATOR TUBE RUPTURE, Step 1.
5 REDUCING CONTROL ROOM EMERGENCY VENTILATION Reduce Control Room Emergency Ventilation to one train in operation within 30 minutes of actuation. REFER TO SOP-505, CONTROL BUILDING VENTILATION SYSTEM NOTE:
The EOP REFERENCE PAGE should be monitored throughout the use of this procedure.
Seal Injection flow should be maintained to all RCPs.
Conditions for implementing Emergency Plan Procedures should be evaluated using EPP-001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 6&7 Page 31 of 48 Event
Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior
- a. Check if either of the following criteria is met:
- Annunciator XCP-612 4-2 is lit (PHASE B ISOL).
CRITICAL RO OR TASK RCS pressure is LESS THAN 1418 psig AND SI flow is indicated on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM.
- b. Stop all RCPs.
CAUTION - Step 2 EOP-4.0 Radiation levels may have increased in steamlines. Proper radiological precautions must be taken when obtaining samples to minimize personnel exposure
- 2. Identify the RUPTURED SG(s): EOP-4.0 Narrow Range level in any SG increasing in an uncontrolled manner.
OR High Radiation on any of the following:
- a. RM-G19A(B)(C), STMLN HI RNG GAMMA.
CREW
- b. Local hand held radiation monitor readings taken by Health Physics on the blowdown lines at the following penetrations:
XRP0326, SG A Blowdown Line (AB-412 West Pen).
XRP0224, SG B Blowdown Line (IB-412 East Pen).
XRP0219, SG C Blowdown Line (IB-412 East Pen).
OR As determined by Chemistry sample analysis for abnormal activity using a frisker.
EVALUATOR NOTE: If the Ruptured SG cannot be identified at this time the ALTERNATE ACTIONS will be performed.
BOOTH OPERATOR: If called to screen sample for activity wait 5 minutes and report elevated activity on the sample from the A SG.
Appendix D NUREG 1021 Revision 9
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Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior
a) Reset both SI RESET TRAIN A(B) Switches.
IF either train of SI does NOT reset, THEN REFER TO SOP-112, SAFETY INJECTION SYSTEM, OFF NORMAL Section, to manually reset relays.
b) Reset Containment Isolation:
RESET PHASE A - TRAIN A(B) CNTMT ISOL.
RESET PHASE B - TRAIN A(B) CNTMT ISOL.
BOP IF either train of Phase A or Phase B does NOT reset, THEN REFER TO SOP-112, SAFETY INJECTION SYSTEM, OFF NORMAL Section, to manually reset relays.
c) Place SVX-9398A(B)(C), SG A(B)(C) SMPL ISOL, in AUTO.
d) Notify Chemistry to sample all SG secondary sides, and screen samples for abnormal activity using a frisker.
WHEN the RUPTURED SG(s) is identified, THEN COMPLETE Steps 3 through 10. Observe the CAUTION prior to Step 3.
CONTINUE WITH Steps 11 through 17.
Appendix D NUREG 1021 Revision 9
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Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior
- 3. Isolate flow from each RUPTURED SG: EOP-4.0
- a. Place the Steamline PWR RELIEF 'A(B)(C) SETPT Controller(s) in MAN and closed.
- b. Adjust the PWR RELIEF A(B)(C) SETPT Controller(s) to 8.85 (1150 psig).
- c. Place the Steamline Power 'Relief A(B)(C) Mode Switch(s)
- d. Place the PWR RELIEF A(B)(C) 'SETPT Controller(s) in AUTO.
- e. WHEN RCS Tavg is LESS THAN P-12 (552°F), THEN place both STM DUMP INTERLOCK Switches to BYP INTLK.
- f. Verify the Steamline PORV closed.
Appendix D NUREG 1021 Revision 9
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Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior CAUTION - Step 3.g EOP-4.0 If the TD EFW Pump is the only available source of feed flow, the steam supply to the TD EFW Pump must be maintained from at least one SG, to maintain a secondary heat sink.
NOTE - Step 3.g If the TD EFW Pump is tripped, it should be reset as time permits.
3.g. IF SG B OR SG C is RUPTURED, THEN perform the following: EOP-4.0 BOP (NO) 3.h. Close the following for each RUPTURED SG:
BOP SG Blowdown, PVG-503A(B)(C).
MS Drain Isolation, PVT-2843A(B)(C).
MS Drain Isolation, PVT-2877A for SG A, PVT-2877B for SG C.
- i. Close the following for each RUPTURED SG:
BOP MS Isolation Valve, PVM-2801A(B)(C).
MS Isolation Bypass Valve, PVM-2869A(B)(C).
- 4. Check level in each RUPTURED SG: EOP-4.0
- a. Verify Narrow Range level in each RUPTURED SG is GREATER THAN 40%.
- b. Stop EFW flow to A SG:
- 3) Maintain Narrow Range level in each RUPTURED SG GREATER THAN 40%.
CAUTION - Step 5 E1OP-4.0 The major flowpaths from each RUPTURED SG (MSIV, TD EFW Pump, and PORV) must be isolated before performing Step 5, to minimize radiological releases and ensure RCS subcooling is maintained.
BOP 5. Verify each RUPTURED SG pressure is GREATER THAN 460 EOP-4.0 psig.
Appendix D NUREG 1021 Revision 9
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Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior
CRS RO 7. Check if any RCP is running. (NO) EOP-4.0
- 7. ALTERNATE ACTION: EOP-4.0 With no RCP running, RCS cooldown and depressurization may CRS cause RUPTURED loop Tcold to falsely indicate a transition to EOP-16.0, RESPONSE TO IMMINENT PRESSURIZED THERMAL SHOCK, is required. Disregard the RUPTURED loop Tcold indication prior to performing Step 34.
NOTE - Step 8 EOP-4.0 The RCP trip criteria does NOT apply after a controlled cooldown is initiated.
Before the Low Steamline Pressure SI signal is blocked, Main Steam Isolation will occur if the Low Steam Pressure rate setpoint is exceeded.
Appendix D NUREG 1021 Revision 9
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Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior
- 8. Dump steam from each INTACT SG: EOP-4.0
- a. WHEN RCS Tavg is LESS THAN P-12 (552°F), THEN:
Place both STM DUMP INTERLOCK Switches to BYP INTLK.
Place both STMLN SI TRAIN A(B) Switches to BLOCK.
- b. Dump steam from each INTACT SG to the Condenser:
- 1) Verify PERMISV C-9 status light is bright on XCP-6114 1-3.
- 2) Perform the following:
Verify the MS Isolation Valves, PVM-2801A(B)(C), are open for the INTACT SGs.
BOP OR Open MS Isolation Bypass Valves:
a) Depress both MAIN STEAM ISOL VALVES RESET TRAIN A(B).
b) Open MS Isolation Bypass Valves, PVM-2869A(B)(C),
for only the INTACT SGs.
- 3) Place the STM DUMP CNTRL Controller in MAN and closed.
- 5) Adjust the STM DUMP CNTRL Controller to fully open the Bank 1 Steam Dump Valves.
EVALUATOR NOTE: P-12 cannot be blocked due to a P-12 failure so the MSIVs will close requiring the alternate actions of step 8b.
Appendix D NUREG 1021 Revision 9
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Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior ALTERNATIVE ACTION 8 b. Dump steam from each INTACT SG using the Steamline PORVs:
- 1) Place the Steamline Power Relief A(B)(C) Mode Switch(s) in PWR RLF.
- 2) Adjust the PWR RELIEF A(B)(C) SETPT Controller(s) to 100% open.
NOTE - Step 9 EOP-4.0 Steps 11 through 18 should be performed as time permits, while the cooldown is in progress.
RO 9. Verify core exit TC temperature is LESS THAN the value EOP-4.0 determined in Step 6.
NOTE - Step 10 EOP-4.0 With no RCPs running, it may be necessary to manually open steam dumps to maintain desired TC temperature.
Appendix D NUREG 1021 Revision 9
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Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior
- 10. Stop the RCS cooldown to the Condenser:
ALTERNATIVE ACTIONS 10 Stop the RCS cooldown using the Steamline PORVs:
BOP a) Adjust the PWR RELIEF A(B)(C) SETPT Controller(s) to closed.
b) Adjust the setpoints to maintain core exit TC temperature per Step 6.
c) Place the PWR RELIEF A(B)(C) SETPT Controller(s) in AUTO
- a. Verify power is available to the PZR PORV Block Valves:
RO 1) MVG-8000A, RELIEF 445 A ISOL.
- 2) MVG-8000B, RELIEF 444 B ISOL.
- 3) MVG-8000C, RELIEF 445 B ISOL.
CAUTION - Step 12.b EOP-4.0 If any PZR PORV opens because of high PZR pressure, Step 12.b should be repeated after pressure decreases to LESS THAN 2330 psig, to ensure the PORV recloses.
RO b. Verify all PZR PORVs are closed. EOP-4.0 RO c. Verify at least one PZR PORV Block Valve is open. EOP-4.0 BOP 13. Reset both SI RESET TRAIN A(B) Switches. EOP-4.0 Appendix D NUREG 1021 Revision 9
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Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior
RESET PHASE B - TRAIN A(B) CNTMT ISOL.
- b. AUTO-START BLOCKS.
- 16. Establish Instrument Air to the RB: EOP-4.0
- a. Start one Instrument Air Compressor and place the other in BOP Standby.
- b. Open PVA-2659, INST AIR TO RB AIR SERV.
- c. Open PVT-2660, AIR SPLY TO RB.
CAUTION - Step 17 EOP-4.0 RCS pressure should be monitored. If RCS pressure decreases in an uncontrolled manner to LESS THAN 325 psig, the RHR Pumps must be manually restarted to supply water to the RCS
- b. Verify RCS pressure is GREATER THAN 325 psig.
BOP 18. Verify core exit TC temperature is LESS THAN the value EOP-4.0 determined in Step 6.
- b. Adjust steam dump setpoints as necessary to maintain desired core exit TC temperature.
Appendix D NUREG 1021 Revision 9
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Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior BOP 20. Verify each RUPTURED SG pressure is stable OR increasing. EOP-4.0 NOTE - Step 21 EOP-4.0 Subcooling may have been temporarily lost during the RCS cooldown, but should quickly increase when the cooldown is complete. If subcooling increases sufficiently after stopping the cooldown, the transition to EOP-4.2, SGTR WITH LOSS OF REACTOR COOLANT:
SUBCOOLED RECOVERY DESIRED, is NOT required.
RO 21. Verify RCS subcooling on TI-499A(B), A(B) TEMP !F, is EOP-4.0 GREATER THAN 72.5°F [87.5°F].
EVALUATOR NOTE:
Step 22 depressurizes the RCS with Normal PZR Spray if RCPs are running.
Step 23 depressurizes the RCS with one PZR PORV.
22.Depressurize the RCS using Normal PZR Spray at the maximum EOP-4.0 rate:
- a. Establish Normal PZR Spray:
Using RCP A:
- 1) Open PCV-444D, PZR SPRAY.
- 2) Close PCV-444C, PZR SPRAY, if RCP C is NOT running.
Using RCPs B and C:
- 1) Open PCV-444C, PZR SPRAY.
- 2) Close PCV-444D, PZR SPRAY, if RCP A is NOT running ALTERNATIVE ACTION:
- a. GO TO Step 23. Observe the CAUTION and NOTE prior to Step 23.
- b. Use maximum available spray until any one of the following criteria is met:
PZR level is GREATER THAN 76% [69%].
OR RCS subcooling on TI-499A(B), A(B) TEMP °F, is LESS THAN 52.5°F [67.5°F].
OR RCS pressure is LESS THAN RUPTURED SG(s) pressure AND PZR level is GREATER THAN 10% [28%].
- c. Stop RCS depressurization:
- 1) Close both PCV-444C(D), PZR SPRAY.
- 2) Close PVT-8145, PZR SPRAY FR CVCS.
- d. GO TO Step 25. Observe the CAUTION prior to Step 25.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 6&7 Page 41 of 48 Event
Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior CAUTION - Step 23 EOP-4.0 When using a PZR PORV to depressurize the RCS, the PRT Rupture Disc may rupture resulting in Adverse Containment Conditions.
Cycling of the PZR PORV should be minimized to reduce the discharge to the PRT and to minimize the potential for PORV failure.
NOTE - Step 23 EOP-4.0 If no RCP is running, the Reactor Vessel Head Upper Plenum may void during depressurization resulting in a rapidly increasing PZR level.
- a. Verify at least one PZR PORV is available.
- b. Open one PZR PORV until any one of the following criteria is met:
PZR level is GREATER THAN 76% [69%].
OR RO RCS subcooling on TI-499A(B), A(B) TEMP °F, is LESS THAN 52.5°F [67.5°F].
OR RCS pressure is LESS THAN RUPTURED SG(s) pressure AND PZR level is GREATER THAN 10% [28%].
- c. Close the PZR PORV.
RO 24. Verify RCS pressure is increasing. EOP-4.0 CAUTION - Step 25 EOP-4.0 When SI termination criteria are met, SI must be terminated to prevent overfilling the RUPTURED SG(s).
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 6&7 Page 42 of 48 Event
Description:
SGTR on A SG (Leak is initially greater than TS leakage limits increasing until operator action is required to maintain Pressurizer level control) with PT-2010 Failed HIGH.
Time Position Applicants Actions or Behavior
- a. RCS subcooling on TI-499A(B), A(B) TEMP °F, is GREATER THAN 52.5°F [67.5°F].
- b. Secondary Heat Sink is adequate:
Total EFW flow available to INTACT SGs is GREATER THAN RO 450 gpm.
OR Narrow Range SG level is GREATER THAN 26% [41%] in at least one INTACT SG.
- d. PZR level is GREATER THAN 10% [28%].
EVALUATOR NOTE:
The caution for step 25 requires that SI be terminated prior to overfilling the SG. The critical tack is to terminate SI before SG level reaches EOP SG level for steam line (87% NR).
EOP-4.0 CRITICAL RO 26. Stop all but one Charging Pump and place in Standby.
TASK EVALUATOR NOTE: The scenario may be terminated after SI flow is terminated.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 1 Page 43 of 48 Event
Description:
SOP-106, DILUTION OPERATIONS Time Position Applicants Actions or Behavior EVALUATOR NOTE: This procedure section is to perform BORATE OPERATIONS.
NOTE 2.0 SOP-106
- 1. Energizing additional Pressurizer Heaters will enhance mixing.
- 2. LCV-115A, LTDN DIVERT TO HU-TK, will begin to modulate to the HU-TK position at 70%
level on LI-115, VCT LEVEL %.
RO 2.1 Ensure at least one Reactor Coolant Pump is running. SOP-106 RO 2.2 Place RX COOL SYS MU switch to STOP. SOP-106 RO 2.3 Place RX COOL SYS MU MODE SELECT switch to BOR. SOP-106 (Peer )
RO 2.4 Set FIS-113, BA TO BLNDR FLOW, batch integrator to the SOP-106 desired volume. (Peer )
RO 2.5 Place RX COOL SYS MU switch to START. SOP-106 NOTE 2.6 Step 2.6 may be omitted when borating less than 10 gallons.
RO 2.6 Place FCV-113 A&B, BA FLOW, controller in AUTO. SOP-106 NOTE 2.7 SOP-106 The AUTO setpoint dial for FCV-113A&B, BA FLOW, controller may be adjusted slowly to obtain the desired flow rate.
RO 2.7 Verify the desired Boric Acid flow rate on FR-113, BA TO BLNDR SOP-106 GPM (F-113).
RO 2.8 When the preset volume of boric acid has been reached, perform SOP-106 the following:
- a. Place FCV-113A&B, BA flow controller in MAN.
- b. Verify boration stops.
RO 2.9 Place RX COOL SYS MU switch to STOP. SOP-106 NOTE 2.10 SOP-106
- a. If plant conditions require repeated borations, Step 2.10 may be omitted.
- b. The volume in the piping between the blender and the VCT outlet is approximately 3.8 gallons.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 1 Page 44 of 48 Event
Description:
SOP-106, DILUTION OPERATIONS Time Position Applicants Actions or Behavior 2.10 Alternate Dilute 4 to 6 gallons of Reactor Makeup Water to flush SOP-106 the line down stream of the blender by performing the following:
- a. Place RX COOL SYS MU MODE SELECT switch to ALT DIL.
(Peer )
- b. Adjust FCV-168, TOTAL MU FLOW SET PT, to desired flow rate.
- c. Set FIS-168, TOTAL MU FLOW, batch integrator to desired volume. (Peer )
- d. Place RX COOL SYS MU switch to START.
- e. Verify desired flow rate on FR-113, TOTAL MU GPM (F-168).
- f. Verify alternate dilution stops when preset volume is reached on FIS-168, TOTAL MU FLOW, batch integrator.
- g. Place RX COOL SYS MU switch to STOP.
2.11 Place RX COOL SYS MU MODE SELECT switch to AUTO. SOP-106 (Peer )
2.12 Adjust FCV-168, TOTAL MU FLOW SET PT, to 7.5 (120 gpm). SOP-106 2.13 In MAN, adjust FCV-113 A&B, BA FLOW OUTPUT, to the SOP-106 required position which will ensure proper Boric Acid addition for subsequent Automatic Makeup operations.
2.14Adjust FCV-113A&B, BA FLOW SET PT, to the desired position SOP-106 to ensure proper boric acid addition for subsequent Automatic Makeup operations.
2.15 Place RX COOL SYS MU switch to START. SOP-106 2.16 Perform the following: SOP-106
- a. Start XPP-13A(B), BA XFER PP A(B), for the in-service Boric Acid Tank.
- b. If necessary, start XPP-13A(B), BA XFER PP A(B), for the Boric Acid Tank on recirculation.
EVALUATOR NOTE: END OF SOP-106 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 1 Page 45 of 48 Event
Description:
SOP-214, MAIN TURBINE AND CONTROLS Time Position Applicants Actions or Behavior EVALUATOR NOTE:
This procedure section is to perform a normal Turbine Load Reduction/Shutdown.
BOP 2.1 Ensure the Control/Load screen is selected. SOP-214 NOTE 2.2 SOP-214 The turbine will come off the limiter and turbine load will lower once Load Set Reference is less than Load Limit Reference.
Acknowledging dialog boxes is skill of the Craft.
BOP 2.2 To lower Turbine Load using Load Set, perform the following: SOP-214 BOP a. If directed by Operations Management, disable the Turbine SOP-214 Vibration Trips per Section III.
BOP b. Select (or enter) the desired Rate %/min on Load Set. SOP-214 BOP c. Select Load on Load Set (a dialog box will open). SOP-214 BOP d. Enter the desired load and confirm. SOP-214 BOP e. Verify proper system response. SOP-214 BOP f. If during a load reduction, it is desired to stop the load reduction, SOP-214 perform the following:
- 1) Select Hold on Load Set.
- 2) Select the desired Rate %/min to resume load reduction.
- 3) If desired, place LOAD LIMIT in service per Section III.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 1 Page 46 of 48 Event
Description:
EOP-1.0 Attachment 3 Time Position Applicants Actions or Behavior EVALUATOR NOTE: This attachment is to verify equipment status after Safety Injection has been initiated and is run concurrently with the main body of EOP-1.0.
Ensure EFW Pumps are running: EOP-1.0 Attachment 3
Ensure the following EFW valves are open: EOP-1.0 Attachment 3 BOP FCV-3531(3541)(3551), MD EFP TO SG A(B)(C).
FCV-3536(3546)(3556), TD EFP TO SG A(B)(C).
MVG-2802A(B), MS LOOP B(C) TO TD EFP.
BOP Verify total EFW flow is GREATER THAN 450 gpm. EOP-1.0 Attachment 3 Ensure FW Isolation: EOP-1.0 Attachment 3
- a. Ensure the following are closed:
FW Flow Control, FCV-478(488)(498).
BOP FW Isolation, PVG-1611A(B)(C).
FW Flow Control Bypass, FCV-3321(3331)(3341).
SG Blowdown, PVG-503A(B)(C).
SG Sample, SVX-9398A(B)(C).
- b. Ensure all Main FW Pumps are tripped.
Ensure SI Pumps are running: EOP-1.0 Attachment 3 BOP Two Charging Pumps are running.
Both RHR Pumps are running.
EOP-1.0 BOP Ensure two RBCU Fans are running in slow speed (one per train). Attachment 3 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 1 Page 47 of 48 Event
Description:
EOP-1.0 Attachment 3 Time Position Applicants Actions or Behavior Verify Service Water to the RBCUs: EOP-1.0 Attachment 3
- a. Ensure two Service Water Pumps are running.
- b. Verify both Service Water Booster Pumps A(B) are running.
- c. Verify GREATER THAN 2000 gpm flow for each train on:
FI-4466, SWBP A DISCH FLOW GPM.
FI-4496, SWBP B DISCH FLOW GPM.
BOP Verify two CCW Pumps are running. EOP-1.0 Attachment 3 BOP Ensure two Chilled Water Pumps and Chillers are running. EOP-1.0 Attachment 3 Verify both trains of Control Room Ventilation are running in EOP-1.0 BOP Attachment 3 Emergency Mode.
Check if Main Steamlines should be isolated: EOP-1.0 Attachment 3
- a. Check if any of the following conditions are met:
RB pressure GREATER THAN 6.35 psig.
OR Steamline pressure LESS THAN 675 psig.
BOP OR Steamline flow GREATER THAN 1.6 MPPH AND Tavg LESS THAN 552°F.
- b. Ensure all the following are closed:
MS Isolation Valves, PVM-2801A(B)(C).
MS Isolation Bypass Valves, PVM-2869A(B)(C).
Ensure Excess Letdown Isolation Valves are closed: EOP-1.0 Attachment 3 BOP PVT-8153, XS LTDN ISOL.
PVT-8154, XS LTDN ISOL.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 1 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 1 Event # 1 Page 48 of 48 Event
Description:
EOP-1.0 Attachment 3 Time Position Applicants Actions or Behavior Verify ESF monitor lights indicate Phase A AND Containment EOP-1.0 Ventilation Isolation on XCP-6103, 6104, and 6106. REFER TO Attachment 3 BOP ATTACHMENT 4, CONTAINMENT ISOLATION VALVE MCB STATUS LIGHT LOCATIONS, as needed.
Verify proper SI alignment: EOP-1.0 Attachment 3 BOP a. Verify SI valve alignment by verifying SAFETY INJECTION/PHASE A ISOL monitor lights are bright on XCP-6104.
BOP Verify proper SI alignment: EOP-1.0 Attachment 3 ALTERNATIVE ACTION
- a. Ensure proper SI valve alignment:
- 1) Open MVG-8801A(B), HI HEAD TO COLD LEG INJ.
- 2) Close MVG-8107 and MVG-8108, CHG LINE ISOL.
- 3) Open LCV-115B(D), RWST TO CHG PP SUCT.
- 4) Close LCV-115C(E), VCT OUTLET ISOL.
BOP b. Verify all SAFETY INJECTION monitor lights are dim on XCP- EOP-1.0 6106. Attachment 3 BOP c. Verify SI flow on FI-943, CHG LOOP B CLD/HOT LG FLOW EOP-1.0 GPM Attachment 3 BOP d. Check if RCS pressure is LESS THAN 325 psig. EOP-1.0 Attachment 3 BOP e. Verify RHR flow on: EOP-1.0 Attachment 3 FI-605A, RHR DISCHARGE PUMP A FLOW GPM.
AND FI-605B, RHR DISCHARGE PUMP B FLOW GPM.
EVALUATOR NOTE:
END OF EOP-1.0 ATTACHMENT 3 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Scenario Outline Form ES-D-1 Facility: VC SUMMER Scenario No.: 2 Op Test No.: NRC ILO 11-01 Examiners: Operators: CRS:
RO:
BOP Initial 40% MOL.
Conditions: Alternate Seal Injection is OOS.
B Train workweek.
Severe thunderstorms have been reported in the area.
Turnover: 40% MOL - Increase power to 48% at 0.5%/minute.
Chemistry is in spec for power accession.
The A and B MFP are running - B MFP was recently started.
Critical Task: Trip the 2 remaining RCPs <1418 WR RCS Pressure with SI Flow and before 33% WR RVLIS.
Establish SI by opening MVG-8801 (A or B) prior to NR RVLIS <
34% or CETs > 725°F.
Event Malf. No. Event Type Event Description No.
N - BOP, 1 N/A CRS Increase power IAW GOP-4A (Step 3.13b).
R - RO I - RO, 2 NIS003D BOP, CRS PRNIS Channel N-44 Fails HIGH.
TS - CRS Emergency Feedwater Pump suction pressure transmitter 3 EF017O TS- CRS PT-3635 Fails LOW.
C - BOP, 4 FWM14D Feedwater Pump Master Speed Controller Fails LOW.
CRS C - RO, 5 RCS007A A RCP Vibration Ramp to Trip criteria CRS 6 RCS006A M - ALL SBLOCA SI003P 7 MVG -8801A, MVG -8801B fail to open on the SI signal.
SI004P DG load sequencer fails to complete (Train A step 7) 8 PCS015A7 XPP-45A, Service Water Booster Pump fails to start.
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Scenario Outline Form ES-D-1 The following notation is used in the ES-D-2 form Time column:
IOA designates Immediate Operator Action steps
- designates Continuous Action steps The crew will assume the watch having been pre-briefed on the Initial Conditions, the plan for this shift and any related operating procedures.
The turbine startup has been stabilized at 39% and GOP-4A, Power Operation (Mode 1 - Ascending) has been completed to Step 3.12.k.
EVENT 1: Increase Power Power has been stabilized at 40% power and a second Main Feedwater Pump has been placed in service by the off-going crew. The turnover directs the crew to increase power to 48% in accordance with GOP-4A continuing at step 3.13b. (0.5%/minute)
EVENT 2: PRNIS Channel N-44 Fails HIGH On cue from the Examiner, PRNIS Channel N-44 fails High. The RO will respond to alarms and uncontrolled rod motion by performing the immediate actions of AOP-401.10, Power Range Channel Failure; placing rod control in MANUAL. The crew should restore Tave if necessary. The BOP will remove the channel from service and the CRS will enter Technical Specification 3.3.1.
EVENT 3: Emergency Feedwater Pump Suction Pressure Transmitter PT-3635 Fails LOW On cue from the Examiner PT-3635 fails Low. The RO will respond to the alarm. The CRS will diagnose the problem as the failure of PT-3635. He will refer to Tech Specs and determine the failed channel must be placed in Bypass and restored to service within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.
EVENT 4: Feedwater Pump Master Speed Controller Fails LOW On cue from the Examiner, the Feedwater Pump Master Speed Controller will fail low causing main feed pump speed to decrease. The BOP will respond to alarms and lowering SG level by controlling FWP Speed IAW AOP-210.3, Feedwater Pump Malfunction and/or Main Control Board Annunciators, SG A(B)(C) STF>FWF Mismatch (XCP-624 4-3(5-3)(6-3)) or SG A (B) (C) LVL DEV XCP-624 1-5(2-5)(3-5).
EVENT 5: RCP A Vibration On cue from the Examiner, RCP A vibration will begin. The crew will respond to alarms/indication and enter XCP-617 1-3. The Crew will trip the reactor and stop the RCP based on shaft vibration greater than or equal to 20 mils or greater than or equal to 15 mils and increasing at greater than one mil per hour. The Crew will then implement EOP-1.0.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Scenario Outline Form ES-D-1 EVENT 6: Small-Break LOCA After EOP-1.0 (E-0) the crew will enter EOP 1.1 (ES-0.1), Reactor Trip Recovery. A LOCA will be initiated from the RCP seal package. When SI actuates automatically or manually (PZR level cant be maintained > 8% or loss of adequate subcooling) the crew will transition back to EOP-1.0 (E-0).
After the Safety Injection Actuation MVG- 8801A and MVG-8801B will fail to open causing a complete loss of the high head injection function. The A SW Booster Pumps will also fail to start. The crew will perform the alternative actions of manually opening MVG- 8801 A and B and manually starting the A Service Water Booster Pump.
The crew will implement EOP-2.0 (E-1), Loss of Reactor or Secondary Coolant. When RCS pressure is less than 1418 psig and SI flow is indicated on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM then ALL running RCPs will be stopped.
CRITICAL TASKS:
It is critical that the two remaining RCPs be secured after RCS pressure lowers to less than 1418 psig and high head injection is established to lower the rate of inventory loss. They must be tripped before WR RVLIS level indicates 33% (50% void fraction for 2 RCPs). At this level significant core uncover would occur upon tripping the RCPs.
It is critical that high head Safety Injection be established by opening MVG-8801 (A or B) prior to NR RVLIS < 34% or CETs > 725°F.
TERMINATION:
The scenario will terminate when EOP-2.0 (E-1) is complete and the crew transitions to EOP-2.1 (ES-1.2), Post-LOCA Cooldown and Depressurization or at the discretion of the Examiner.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Scenario Outline Form ES-D-1 VC Summer 2013 NRC Scenario 2 Simulator Setup Initial Conditions:
IC-13, 40% (IC-322 for 2013)
Reactivity Management Plan/Turnover sheet for IC Set Boron Concentration = 1298 ppm FCV 113 Pot setting = 5.56 Xe = -1409 pcm Burnup = 10008 MWD/MTU = 226 EFPD Prior to the scenario, crew should pre-brief on conditions and expectations for the Shift (maintain power, repairs estimated to be complete well before LCO action time expires).
VC Summer 2013 NRC Scenario 2 Simulator Setup (SNAP 322)
Conduct two-minute drill Mark up procedures in use with Circle and slash as applicable Pre-Exercise:
Ensure simulator has been checked for hardware problems (DORT, burnt out light bulbs, switch malfunctions, chart recorders, etc.)
TQP-801 Booth Operator checklist, has been completed Hang Red Tags for equipment out of service PRE-LOAD:
Standard Simulator Setup PMP-LD003P XPP0138 LEAK DETECTION SUMP PMP LOSS OF POWER VLV-FW028W XVG01676-FW FW HDR RECIRC ISOL VLV LOSS OF POWER VLV-FW029W XVG01679-FW FW HTR RECIRC ISO VLV LOSS OF POWER VLV-CS052W XVT08141A-CS RCP A SEAL LEAKOFF VLV LOSS OF POWER VLV-CS054W XVT08141C-CS RCP C SEAL LEAKOFF VLV LOSS OF POWER VLV-CS053W XVT08141B-CS RCP B SEAL LEAKOFF VLV LOSS OF POWER Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Scenario Outline Form ES-D-1 Scenario Related VLV-SI003P XVG08801A-SI HI HEAD INJ FAIL POSITION Delay=0, Ramp=0, Final=0 VLV-SI004P XVG08801B-SI HI HEAD INJ FAIL POSITION Delay=0, Ramp=0, Final=0 MAL-PCS015A7 DG LOAD SEQUENCER FAILS TO COMPLETE (TRAIN A STEP 7) Delay=0, Ramp=0, Final=0 EVENT 1: Increase power IAW GOP-4A NORMAL - No malfunctions EVENT 2: PRNIS Channel N-44 fails HIGH TRIGGER 2 o MAL-NIS003D, POWER RANGE CHANNEL 44 FAILURE Delay=0, Ramp=0, Final=200.
o XCP-620 1:1 immediate leads to AOP.
o Booth Operator: When called as I&C to record detector currents wait 5 min and report that currents have been recorded.
EVENT 3: Emergency Feedwater Pump suction pressure transmitter PT-3635 fails LOW TRIGGER 3 o XMT-EF017O IPT03635 EFP SUC PRESS CH IV FAIL TO POSN Delay=0, Delete=0, Ramp=00:01:00, FINAL=0 EVENT 4: Feedwater Pump Master Speed Controller fails LOW TRIGGER 4 o FWM014D, FWP MASTER (SC-509A) AUTO CONTROL FAILURE Delay=0, Ramp=00:00:45, Final =20.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Scenario Outline Form ES-D-1 EVENT 5: Increasing RCP A vibration requires tripping the unit, stopping the A RCP TRIGGER 5 o MAL-RCP007A, RCP VIBRATION INITIAL =11 FINAL=21 RAMP=03:00 LOA TRIGGER 10:
Energizes RCP A Seal Leakoff Valve o VLV-CS052W XVT08141A-CS RCP A SEAL LEAKOFF VLV LOSS OF POWER LOA TRIGGER 11:
Locally adjust ITV-3062A(B)(C) BD COOLER A(B)(C) CDSTEOUT TEMP TO 90%
o LOA CND047 COND TO S/G BD TV-3062A MANUAL POSITION Delay = 0 Ramp = 20 Sec Final = 0.9 o LOA CND048 COND TO S/G BD TV-3062B MANUAL POSITION Delay = 01:00 Ramp = 20 Sec Final = 0.9 o LOA CND049 COND TO S/G BD TV-3062C MANUAL POSITION Delay = 02:00 Ramp = 20 Sec Final = 0.9 EVENT 6: SBLOCA TRIGGER 6 o MAL-CVC004A, RCP 1 NUMBER 1 SEAL FAILURE Delay=0, Ramp=00:00:00, Final=100.
o MAL-RCS006A REAC TOR COOLANT SYSTEM LEAK COLD LEG (LOOP 1)
Delay=0, Ramp=0, Final=600.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Scenario Outline Form ES-D-1 EVENT 7: MVG -8801A and MVG-8801 fail to open on the SI signal EVENT 7 X031085O==1 Triggered when MVG08801A Control Switch is taken to OPEN o TRIGGER 7 VLV-SI003P XVG08801A-SI HI HEAD INJ FAIL POSITION Delay=0, Ramp=0, Final=0, Delete in : 00:00:01 EVENT 8 X031086O==1 Triggered when MVG08801 Control Switch is taken to OPEN o TRIGGER 8 VLV-SI004P XVG08801B-SI HI HEAD INJ FAIL POSITION Delay=0, Ramp=0, Final=0, Delete in : 00:00:01 EVENT 8: DG Load Sequencer Fails To Complete (Train A Step 7) XPP-45A,Service Water Booster Pump Fails To Start.
No action necessary - Failure is installed in the scenario pre-load.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 1 Page 8 of 44 Event
Description:
Increase Power to 48%
Time Position Applicants Actions or Behavior BOOTH OPERATOR: No trigger is required.
Indications available: N/A EVALUATOR NOTE:
The turnover instructs the crew in raise power to 48% IAW GOP-4A Step 3.13.b GOP- 4A REFERENCE PAGE GOP-4A Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 1 Page 9 of 44 Event
Description:
Increase Power to 48%
Time Position Applicants Actions or Behavior NOTE 3.10 through 3.18 GOP-4A IFK3136, FLOW TO DEAERATOR, AUTO setpoint should be adjusted during power changes to maintain LI-3136, DEAER STOR TK NR LVL, between 2.5 feet and 5.0 feet as LCV 3235, DEAR START UP DRAIN CNTRL, is closed.
BOP Raise Turbine load to attain 48% Reactor Power as follows: GOP-4A BOP 1) Select Ramp Rate and enter the recommended Load Ramp GOP-4A Rate.
- 2) Raise Turbine Load by one of the following methods: GOP-4A
- a. Slowly Raise Turbine load automatically as follows preferred method):
(1) Select the Load pushbutton (a dialog box opens).
(2) Enter 39.5.%
(3) Confirm setpoint.
(4) Verify proper plant response.
- b. Manually by pushing and holding the Raise Pushbutton on the MCB to increase Turbine load in increments of less than or equal to 2% (20 MWe) (utilizes previously selected ramp rate)
- c. Under Manual Adj momentarily select Raise to increase Turbine load in increments of 0.1-0.2% to a total of 2% (20 MWe). (one cycle utilizes 10%/min ramp rate and returns to previously selected ramp rate.)
BOP When Turbine Load is greater than 40% (385 MWe), verify C20, 1st GOP-4A STG PRESS, de-energizes to dim.
BOP Monitor the following for proper operation: GOP-4A
- 2) Hydrogen Seal Oil.
BOOTH OPERATOR: Acknowledge requests to align the 2A and 2B FW Heater Drains.
This valve is not modeled.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 1 Page 10 of 44 Event
Description:
Increase Power to 48%
Time Position Applicants Actions or Behavior BOP Between 400 MWe and 450 MWe, open the following valves to GOP-4A align the 2A and 2B Heaters to the DA (TB-412):
BOP Secure the Condensate Polishing per SOP-203, Condensate GOP-4A Polishing System.
EVALUATOR NOTE:
Applicable portions of SOP-106 are attached (Page 39) for performing Alternate Dilution.
BOP Borate or dilute per SOP-106, Reactor Makeup Water System, to GOP-4A maintain the following parameters (Refer to SOP-401):
- 1) I within limits.
- 2) Control Rods above the Rod Insertion Limit.
NOTE 3.13.h GOP-4A Above 40% Turbine load MSR 4th pass drains to the Condenser close and the MSR 4th pass drains to the #1 Feedwater Heaters open.
BOP Using the DCS Computer Graphic Screens 101 and 102, verify GOP-4A MSR 4th pass drain valves have repositioned:
- 1) XVT-2071A indicates closed.
- 2) XVT-2071B indicates closed.
- 3) XVT-02068A indicates open.
- 4) XVT-02068B indicates open.
EVALUATOR NOTE:
The next event may be triggered after a significant power change (5%) has been observed.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 2 Page 11 of 44 Event
Description:
PRNIS Channel N-44 Fails HIGH Time Position Applicants Actions or Behavior BOOTH OPERATOR: Initiate Event 2 (TRIGGER 2) when directed.
Indications Available:
XCP-620-1-1, PR HI SETPT FLUX HI XCP-620-1-4, PR CHAN DEV XCP-620-2-2, PR FLUX HI RATE SINGLE CHAN ALERT XCP-621-1-1, CRB INSRT LMT LO-LO XCP-621-1-2, CRB INSRT LMT LO XCP-621-1-4, PR FLUX HI ROD STP RO Responds to multiple Annunciators EVALUATOR NOTE:
The crew may directly implement AOP-401.10, POWER RANGE CHANNEL FAILURE RO Enters ARP-001- XCP-620-1-1, PR HI SETPT FLUX HI XCP-620 1-1 CORRECTIVE ACTIONS: XCP-620 1-1
- 1. Check for a failed instrument on the Main Control Board Power XCP-620 1-1 RO Range channels.
- 2. If the reactor trips, implement EOP-1.0, Reactor Trip/Safety XCP-620 1-1 Injection Actuation.
- 3. Verify that Control Rods are not being withdrawn by observing the XCP-620 1-1 RODS OUT light on the Main Control Board.
SUPPLEMENTAL ACTIONS: XCP-620 1-1 RO Refer to AOP-401.10, Power Range Failure. XCP-620 1-1 CRS Enters AOP-401.10, POWER RANGE CHANNEL FAILURE AOP-401.10 IOA RO Verify normal indication on Power Range Channel N-44. (NO) AOP-401.10 Place the ROD CNTRL BANK SEL Switch in MAN.
IOA RO Stabilize any plant transients in progress. AOP-401.10
- CREW Maintain stable plant conditions. AOP-401.10 CRS Verify no testing is in progress on the operable Power Range AOP-401.10 channels.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 2 Page 12 of 44 Event
Description:
PRNIS Channel N-44 Fails HIGH Time Position Applicants Actions or Behavior BOP Place ROD STOP BYPASS Switch (on the MISCELLANEOUS AOP-401.10 CONTROL AND INDICATION PANEL) for the failed Power Range channel in BYPASS.
RO Verify the appropriate Rod Stop Bypass status light is bright: AOP-401.10 For N-44, B2 OP ROD STOP BYP (XCP-6111 4-4).
RO Adjust Control Rods to maintain Tavg within 1.0 F of Tref. AOP-401.10 BOOTH OPERATOR:
Acknowledge request to record detector information.
Wait one minute THEN go to the floor to record the detector information.
Notify the CRS when detector collection has been completed.
CRS Notify the I&C Department to record detector currents and status AOP-401.10 lights on POWER RANGE A and POWER RANGE B drawers.
AOP-401.10 CAUTION - Step 9 The empty fuse holders should NOT be reinstalled as this will allow a small amount of current flow through the blown fuse indicator.
EVALUATOR NOTE:
The following are expected alarms when the fuses are pulled in the next step:
XCP-620-1-1, PR HI SETPT FLUX HI XCP-620-1-2, PR LO SETPT FLUX HI XCP-620-1-5, PR UP DET FLUX HI DEV AUTO DEFEAT XCP-620-1-6, PR LOW DET FLUX HI DEV AUTO DEFEAT XCP-620-2-1, PR DET VOLT LOSS XCP-620-2-2, PR FLUX HI RATE SINGLE CHAN ALERT AOP-401.10 Deenergize the failed Power Range channel:
- a. Remove the CONTROL POWER fuses from the POWER RANGE BOP A drawer.
- b. Remove the INSTR POWER fuses from the POWER RANGE B drawer.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 2 Page 13 of 44 Event
Description:
PRNIS Channel N-44 Fails HIGH Time Position Applicants Actions or Behavior EVALUATOR NOTE:
The following alarms should clear during the next step:
XCP-620-1-4, PR CHAN DEV XCP-620-1-5, PR UP DET FLUX HI DEV AUTO DEFEAT XCP-620-1-6, PR LOW DET FLUX HI DEV AUTO DEFEAT AOP-401.10 Align the Power Range channel comparator circuits:
- a. Place the following switches to the failed Power Range channel position:
BOP 1) COMPARATOR CHANNEL DEFEAT Switch (on the COMPARATOR AND RATE drawer).
- 2) UPPER SECTION Switch (on the DETECTOR CURRENT COMPARATOR drawer).
- 3) LOWER SECTION Switch (on the DETECTOR CURRENT COMPARATOR drawer).
RO Ensure NR-45 is selected to the appropriate operable channels. AOP-401.10 AOP-401.10 RO Check if Reactor power is LESS THAN 75%.
AOP-401.10 RO Check if Reactor power is LESS THAN 50%.
AOP-401.10 Within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, place the failed channel protection bistables in a CRS tripped condition:
- a. Identify the associated bistables for the failed channel. REFER CRS TO Attachment 1.
- b. Record the following for each associated bistable on SOP-401, REACTOR PROTECTION AND CONTROL SYSTEM, Attachment I:
CRS Instrument Associated Bistable.
Bistable Location.
STPs.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 2 Page 14 of 44 Event
Description:
PRNIS Channel N-44 Fails HIGH Time Position Applicants Actions or Behavior BOOTH OPERATOR:
Acknowledge requests for support.
Report that I&C will assign a crew to place the bistables in trip.
AOP-401.10 CRS c. Notify the I&C Department to place the identified bistables in trip.
AOP-401.10 Refer to Tech Spec 3.3.1, REACTOR TRIP SYSTEM CRS INSTRUMENTATION EVALUATOR NOTE: The CRS will determine that the failed channel must be placed in the tripped condition within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. The following Tech Spec excerpts are for reference.
TECH SPEC 3.3.1 CRS Excerpt from TECH SPEC Table 3.3-1 TECH SPEC 3.3.1 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 2 Page 15 of 44 Event
Description:
PRNIS Channel N-44 Fails HIGH Time Position Applicants Actions or Behavior TECH SPEC 3.3.1 CRS Determine and correct the cause of the Power Range channel AOP-401.10 CRS failure.
EVALUATOR NOTE:
The next event may be initiated after the Technical Specifications and required actions have been addressed.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 3 Page 16 of 44 Event
Description:
Emergency Feedwater Pump suction pressure transmitter PT-3635 Fails LOW Time Position Applicants Actions or Behavior BOOTH OPERATOR: Initiate Event 3 (TRIGGER 3) when directed.
Indications Available:
ARP-001-XCP-621, 3-5 EFP SUCT HDR PRESS LO XFER TO SW Responds to annunciator XCP-621, 3-5 EFP SUCT HDR PRESS XCP-621 3-5 RO LO XFER TO SW.
CORRECTIVE ACTIONS: XCP-621 3-5 Verify the low suction pressure condition exists by checking level on LI-3621A (3631A), CST LEVEL FEET. (NO)
RO Refer to SOP-211 for operation using Service Water for Emergency Feedwater.
Ensure Emergency Feedwater supply transfers to Service Water when required by decreasing level. (NO)
SUPPLEMENTAL ACTIONS: XCP-621 3-5 Determine the cause of the low suction pressure and correct as soon as possible.
CRS If the alarm is due to an instrument failure, bypass the associated bistable per SOP-401 Attachment I.
BOOTH OPERATOR: Acknowledge requests for support.
CRS Request support for I&C to place the associated bistable in bypass. XCP-621 3-5 EVALUATOR NOTE:
The following excerpts are for reference. The failed channel must be placed in Bypass and must be restored to service with 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 3 Page 17 of 44 Event
Description:
Emergency Feedwater Pump suction pressure transmitter PT-3635 Fails LOW Time Position Applicants Actions or Behavior Excerpt from SOP-401 Attachment 1 SOP-401 Excerpt from SOP-401 Enclosure B Tech Spec Excerpt from Technical Specification Table 3.3-3 Table 3.3-3 EVALUATOR NOTE: The next event may be initiated after the CRS has referenced the Technical Specifications.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 4 Page 18 of 44 Event
Description:
Feedwater Pump Master Speed Controller Fails LOW Time Position Applicants Actions or Behavior Booth Operator: Initiate Event 4 (TRIGGER 4) when directed.
Indications Available:
624-1-5, SG A LVL DEV 624-2-5, SG B LVL DEV 624-3-5, SG C LVL DEV RO Responds to multiple annunciators EVALUATOR NOTE: Annunciator XCP624 1-5 actions are detailed below for SG A but they are similar to the actions for SG B and C.
CORRECTIVE ACTIONS: XCP 624 1-5
- 1. If required, restore Steam Generator A level to between 60% and XCP 624 1-5 65% by performing either or both of the following:
- a. Manually control PVT-478, SG A FWF, as required.
- b. Manually control Feedwater Pump speed as follows:
- 1) Place the Feedwater Pump MASTER SPEED CNTRL in MAN.
- 2) Adjust the differential pressure between Feedwater Pump discharge header pressure and Main Steam header pressure, as required, to restore Steam Generator water level.
- b. For decreasing level:
- 1) At 45% Narrow Range level:
(a) Manually control PVT-478, SG A FWF, as required.
(b) Ensure feed flow is greater than steam flow by 200 kbh to 400 kbh.
- 2) At 40% Narrow Range level:
(a) Trip the reactor.
(b) Ensure both Motor Driven Emergency Feed pumps are in service to deliver full system flow.
- 3. Determines if FCV-478, A FCV, malfunctioned go to AOP-210.1, XCP 624 1-5 BOP Feedwater Flow Control Valve Failure.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 4 Page 19 of 44 Event
Description:
Feedwater Pump Master Speed Controller Fails LOW Time Position Applicants Actions or Behavior
- 4. If a Main Feedwater Pump has tripped or is malfunctioning go to XCP 624 1-5 BOP AOP-210.3, Feedwater Pump Malfunction.
- 5. If an instrument channel has failed, go to AOP-401.11, Steam XCP 624 1-5 BOP Generator Level Control And Protection Channel Failure.
CRS Implement AOP-210.3, Feedwater Pump Malfunction. AOP-210.3 IOA BOP 1. Verify at least one Feedwater Pump is running. AOP-210.3 BOP 2. Check if a Feedwater Pump trip occurred. (NO) AOP-210.3 IOA ALTERNATE ACTION:
GO TO Step 13.
- a. Place the Feedwater Pump MASTER SPEED CNTRL in MAN.
- b. Adjust Feedwater Pump speed to maintain pump discharge header pressure 150 to 250 psi GREATER THAN Main Steam BOP header pressure on:
PI-508, FW PP DISCH HDR PRESS PSIG.
- c. Adjust PUMP A(B)(C) SPEED CNTRL (MCB M/A Stations) setpoint potentiometers, as necessary to balance all operating Feedwater Pumps speed to within 120 rpm of each other.
BOP 15. Check if MCB MASTER SPEED CONTROL is in AUTO. AOP-210.3
- 16. Ensure all operating Feedwater Pump speed controller(s) AOP-210.3 BOP (MCB M/A Stations) are in AUTO. REFER TO SOP-210, FEEDWATER SYSTEM.
CRS 18. RETURN TO the Procedure and Step in effect. AOP-210.3 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 4 Page 20 of 44 Event
Description:
Feedwater Pump Master Speed Controller Fails LOW Time Position Applicants Actions or Behavior BOOTH OPERATOR: Acknowledge all requests for support.
EVALUATOR NOTE:
When the BOP has restored control of SG levels the CRS will exit this procedure. The CRS may elect to maintain power pending repairs or continue with the power increase.
The next event may be triggered when the plant has been stabilized following the failure.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 5 Page 21 of 44 Event
Description:
A RCP Vibration Ramp to Trip criteria Time Position Applicants Actions or Behavior BOOTH OPERATOR: Initiate Event 5 (TRIGGER 5) when directed.
Indications available:
XCP-617 1-3, RCP A VIBRATION HI RO Responds to alarm XCP-617 1-3, RCP A VIBRATION HI.
CAUTION XCP-617 1-3 Reactor Coolant Pump shaft and frame vibrations should increase simultaneously on actual Reactor Coolant Pump high vibration. Channel failure is indicated by the associated shaft or frame bar graph going to zero on the Yokogowa DX 1000 recorder.
NOTE XCP-617 1-3
- a. This alarm has reflash capabilities.
- b. This alarm causes XCP-606 3-5, REACTOR BUILDING FANS VIBRATION MON FLT/WARN to annunciate.
CORRECTIVE ACTIONS: XCP-617 1-3
- 1. Monitor Reactor Coolant Pump A vibration indicators to determine the source and severity of the vibration.
- 2. Monitor RCS temperature and pressure to verify they are within limits for Reactor Coolant Pump operation.
RO 3. Determine if a single phasing event is in progress by diagnosis of any combination of the following symptoms:
- a. Vibration Alarms are received for other equipment.
- b. MCB Potential Lights are not lit.
- c. MCB Amber Overload lights are lit for running equipment or Motor Overload Alarms are received.
- d. MCB Undervoltage Alarms.
- e. Affected bus local 7.2 KV Bus ammeters.
SUPPLEMENTAL ACTIONS: XCP-617 1-3
- 1. With Reactor Coolant Pump A shaft vibration greater than or equal to 20 mils or greater than or equal to 15 mils and increasing at greater than one mil per hour, perform one of the RO following:
- a. If Reactor Power is greater than 38%, trip the Reactor and secure Reactor Coolant Pump A per SOP-101.
Check if Reactor power is GREATER THAN 38% (Reactor XCP-617 1-3 Crew Permissive P-8, REACTOR TRIP BLOCKED, is dim).
RO Trip the Reactor. XCP-617 1-3 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 5 Page 22 of 44 Event
Description:
A RCP Vibration Ramp to Trip criteria Time Position Applicants Actions or Behavior RO Stop the affected Reactor Coolant Pump.
Enters EOP-1.0, REACTOR TRIP/SAFETY INJECTION EOP-1.0 CRS ACTUATION REFERENCE PAGE FOR EOP-1.0 EOP-1.0 NOTE EOP-1.0 Steps 1 through 5 are Immediate Operator Actions.
The EOP REFERENCE PAGE should be monitored throughout the use of this procedure.
Conditions for implementing Emergency Plan Procedures should be evaluated using EPP-001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 5 Page 23 of 44 Event
Description:
A RCP Vibration Ramp to Trip criteria Time Position Applicants Actions or Behavior Verify Reactor Trip: EOP-1.0 Trip the Reactor using either Reactor Trip Switch.
IOA RO Verify all Reactor Trip and Bypass Breakers are open Verify all Rod Bottom Lights are lit.
Verify Reactor Power level is decreasing.
Verify Turbine/Generator Trip: EOP-1.0
IOA BOP b. Ensure Generator Trip (after 30 second delay):
- 1) Ensure the GEN BKR is open.
- 2) Ensure the GEN FIELD BKR is open.
- 3) Ensure the EXC FIELD CNTRL is tripped.
IOA BOP Verify both ESF buses are energized. EOP-1.0 CRS Go to Step 5. EOP-1.0 EOP-1.0 Check if SI is required:
Check if any of the following conditions exist:
PZR pressure LESS THAN 1850 psig.
IOA RO OR RB pressure GREATER THAN 3.6 psig.
OR Steamline pressure LESS THAN 675 psig.
OR Steamline differential pressure GREATER THAN 97 psid.
EVALUATOR NOTE:
It is a Critical Task for the RCPs to be tripped when SI flow is indicated and RCS pressure is less than 1418 psig WR and before 33% WR RVLIS.
EOP-1.0 CRS Go to EOP-1.1, REACTOR TRIP RECOVERY.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 5 Page 24 of 44 Event
Description:
A RCP Vibration Ramp to Trip criteria Time Position Applicants Actions or Behavior REFERENCE PAGE FOR EOP-1.1 EOP-1.1 1 SI ACTUATION CRITERIA IF either of the following conditions occurs, THEN actuate SI and GO TO EOP-1.0, REACTOR TRIP/SAFETY INJECTION ACTUATION, Step 1:
PZR level can NOT be maintained GREATER THAN 8%.
OR RCS subcooling on TI-499A(B), A(B) TEMP "F, is LESS THAN the value listed in the table below:
RCS RCS PRESSURE SUBCOOLING (psig) (°F) 1576-3075 42.5 876-1575 45 576-875 47.5 476-575 50 375-475 52.5 CAUTION: EOP-1.1 If SI actuation occurs during this procedure, EOP-1.0, REACTOR TRIP/SAFETY INJECTION ACTUATION, should be performed to stabilize the plant.
NOTE: EOP-1.1 Main Turbine vibration should be monitored during coastdown.
The EOP REFERENCE PAGE should be monitored throughout the use of this procedure.
CREW Announce plant conditions over the page system. EOP-1.1 EVALUATOR NOTE:
The next event (SBLOCA) may be cued after EOP1.1 is implemented. The following steps are only applicable until the effect of the next event is observed.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 5 Page 25 of 44 Event
Description:
A RCP Vibration Ramp to Trip criteria Time Position Applicants Actions or Behavior CREW Check FW status: EOP-1.1 RO a. Check if RCS Tavg is LESS THAN 564 F. EOP-1.1
are closed.
BOP Ensure the Main FW Isolation Valves, PVG-1611A(B)(C),
are closed.
Ensure the FW Flow Control Bypass Valves, FCV-3321(3331)(3341), are closed.
NOTE - Step 4 EOP-1.1 If a transition is made to AOP-112.2, STEAM GENERATOR TUBE LEAK NOT REQUIRING SI, the steps of EOP-1.1 which do NOT conflict with AOP-112.2 should be completed as time allows.
RO Verify all Control Rods are fully inserted. EOP-1.1 BOOTH OPERATOR: When contacted to adjust ITV-3062A(B)(C), BD COOLER A(B)(C)
CDSTE OUT TEMP to 90%
Insert TRIGGER 11. This will adjust the valves to 90% over 2 min 20 sec.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 5 Page 26 of 44 Event
Description:
A RCP Vibration Ramp to Trip criteria Time Position Applicants Actions or Behavior Check DA level control: EOP-1.1
- a. Open LCV-3235, DEAER START UP DRAIN CNTRL, as necessary to maintain DA level LESS THAN 10.5 ft as indicated BOP on LI-3135, DEAER STOR TK WR LVL FEET.
- b. Locally adjust ITV-3062A(B)(C), BD COOLER A(B)(C) CDSTE OUT TEMP, to 90% (XPN-0029, NUCLEAR BLOWDOWN PROCESSING PANEL, AB-436).
Check PZR level control: EOP-1.1
- a. Verify PZR level is GREATER THAN 17%.
- b. Verify Charging and Letdown are in service.
- c. Verify PZR level is trending to 25%.
Check PZR pressure control: EOP-1.1
- a. Verify PZR pressure is GREATER THAN 1850 psig.
- b. Verify PZR pressure is stable at OR trending to 2230 psig (2220 psig to 2250 psig).
- a. Verify Narrow Range level in all SGs is GREATER THAN 26%.
Verify all AC buses are energized by offsite power: EOP-1.1
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 5 Page 27 of 44 Event
Description:
A RCP Vibration Ramp to Trip criteria Time Position Applicants Actions or Behavior Transfer Condenser Steam Dumps to the Steam Pressure Mode: EOP-1.1
- a. Verify PERMISV C-9 status light is bright on XCP-6114 1-3.
- b. WHEN RCS Tavg is LESS THAN P-12 (552"F), THEN place both STM DUMP INTERLOCK Switches to BYP INTLK.
- c. Perform the following:
Verify the MS Isolation Valves, PVM-2801A(B)(C), are open.
OR Open MS Isolation Bypass Valves:
- 1) Depress both MAIN STEAM ISOL VALVES RESET TRAIN A(B).
- 2) Open MS Isolation Bypass Valves, PVM-2869A(B)(C).
- d. Place the STM DUMP CNTRL Controller in MAN and closed.
- e. Ensure the STM DUMP CNTRL Controller is set to 8.4.
- g. Place the STM DUMP CNTRL Controller in AUTO.
NOTE - Step 12 EOP-1.1 Priority should be given to running RCP A to supply Normal PZR Spray.
Since a time lag is expected after increasing steam flow before natural circulation parameters can be verified, this procedure should be continued concurrently with the establishment of natural circulation.
Verify RCP A is running. EOP-1.1 RO NOTE: Crew determines the RCP A cannot be started.
Shut down and stabilize the Secondary Plant. REFER TO AOP- EOP-1.1 BOP 214.1, TURBINE TRIP.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 5 Page 28 of 44 Event
Description:
A RCP Vibration Ramp to Trip criteria Time Position Applicants Actions or Behavior Maintain stable plant conditions: EOP-1.1
- a. Maintain PZR pressure at 2230 psig (2220 psig to 2250 psig).
- b. Maintain PZR level at 25%.
- c. Maintain Narrow Range SG levels between 40% and 60%.
RO d. Maintain RCS temperature:
With any RCP running, Tavg at 557°F.
OR With no RCP running, Tcold at 557°F.
- e. REFER TO GOP-5, REACTOR SHUTDOWN FROM STARTUP TO HOT STANDBY (MODE 2 TO MODE 3).
COMPLETE Attachment I of SAP-116, PLANT TRIP/SAFETY EOP-1.1 BOP INJECTION PLANT RECOVERY.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 6,7,8 Page 29 of 44 Event
Description:
SBLOCA, MVG -8801A, MVG -8801B fail to open on the SI signal, DG load sequencer fails to complete (train A step 7) XPP-45A, Service Water Booster Pump fails to start.
Time Position Applicants Actions or Behavior BOOTH OPERATOR: Initiate Event 6 (TRIGGER 6) when directed.
Indications:
Rapidly decreasing Pressurizer Pressure and Level EVALUATOR NOTE: When the symptoms of the SBLOCA are observed the crew will initiate SI and implement EOP-1.0.
Crew Respond to alarms and degrading RCS condition. EOP-1.1 CRS Direct SI Actuation. EOP-1.1 Implement EOP-01 REACTOR TRIP/SAFETY INJECTION EOP-1.1 CRS ACTUATION.
REFERENCE PAGE FOR EOP-1.0 EOP-1.0 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 6,7,8 Page 30 of 44 Event
Description:
SBLOCA, MVG -8801A, MVG -8801B fail to open on the SI signal, DG load sequencer fails to complete (train A step 7) XPP-45A, Service Water Booster Pump fails to start.
Time Position Applicants Actions or Behavior Note: EOP-1.0 Steps 1 through 5 are Immediate Operator Actions.
The EOP REFERENCE PAGE should be monitored throughout the use of this procedure.
Conditions for implementing Emergency Plan Procedures should be evaluated using EPP-001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN.
Verify Reactor Trip: EOP-1.0 Trip the Reactor using either Reactor Trip Switch.
IOA RO Verify all Reactor Trip and Bypass Breakers are open Verify all Rod Bottom Lights are lit.
Verify Reactor Power level is decreasing.
Verify Turbine/Generator Trip: EOP-1.0
IOA BOP
- b. Ensure Generator Trip (after 30 second delay):
- 1) Ensure the GEN BKR is open.
- 2) Ensure the GEN FIELD BKR is open.
- 3) Ensure the EXC FIELD CNTRL is tripped.
IOA BOP Verify both ESF buses are energized. EOP-1.0 Check if SI is actuated: EOP-1.0
- a. Check if either:
SI ACT status light is bright on XCP-6107 1-1.
IOA RO OR Any red first out SI annunciator is lit on XCP-626 top row.
- c. GO TO Step 6.
EVALUATOR NOTE:
ATTACHMENT 3, SI EQUIPMENT VERIFICATION is attached (Page 40). Failure of MVG-8801A/B will be addressed in EOP-1.0 Attachment 3.
BOP Initiate ATTACHMENT 3, SI EQUIPMENT VERIFICATION. EOP-1.0 EOP-1.0 Crew Announce plant conditions over the page system.
Appendix D NUREG 1021 Revision 9
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Description:
SBLOCA, MVG -8801A, MVG -8801B fail to open on the SI signal, DG load sequencer fails to complete (train A step 7) XPP-45A, Service Water Booster Pump fails to start.
Time Position Applicants Actions or Behavior Verify RB pressure has remained LESS THAN 12 psig on PR-951, EOP-1.0
Check RCS temperature: EOP-1.0 With any RCP running, RCS Tavg is stable at OR trending to 557°F.
Check PZR PORVs and Spray Valves: EOP-1.0
- a. PZR PORVs are closed.
- b. PZR Spray Valves are closed.
RO c. Verify power is available to at least one PZR PORV Block Valve:
MVG-8000A, RELIEF 445 A ISOL.
MVG-8000B, RELIEF 444 B ISOL.
MVG-8000C, RELIEF 445 B ISOL.
- d. Verify at least one PZR PORV Block Valve is open.
Check if RCPs should be stopped: EOP-1.0
- a. Check if either of the following criteria is met:
Annunciator XCP-612 4-2 is lit (PHASE B ISOL).
RO OR RCS pressure is LESS THAN 1418 psig AND SI flow is indicated on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM.
- b. Stop all RCPs.
Verify no SG is FAULTED: EOP-1.0 BOP No SG pressure is decreasing in an uncontrolled manner.
No SG is completely depressurized.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 6,7,8 Page 32 of 44 Event
Description:
SBLOCA, MVG -8801A, MVG -8801B fail to open on the SI signal, DG load sequencer fails to complete (train A step 7) XPP-45A, Service Water Booster Pump fails to start.
Time Position Applicants Actions or Behavior Verify Secondary radiation levels indicate SG tubes are NOT EOP-1.0 RUPTURED:
RM-G19A(B)(C), STMLN HI RNG GAMMA.
BOP RM-A9, CNDSR EXHAUST GAS ATMOS MONITOR.
RM-L3, STEAM GENERATOR BLOWDOWN LIQUID MONITOR.
RM-L10, SG BLOWDOWN CW DISCHARGE LIQUID MONITOR.
Check if the RCS is INTACT: EOP-1.0
- a. RB radiation levels are normal on:
RM-G7, CNTMT HI RNG GAMMA.
RM-G18, CNTMT HI RNG GAMMA.
- c. RB pressure is LESS THAN 1.5 psig.
- d. The following annunciators are NOT lit:
XCP-606 2-2 (RBCU 1A/2A DRN FLO HI).
XCP-607 2-2 (RBCU 1B/2B DRN FLO HI).
ALTERNATIVE ACTION GO TO EOP-2.0, LOSS OF REACTOR OR SECONDARY COOLANT, Step 1.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 6,7,8 Page 33 of 44 Event
Description:
SBLOCA, MVG -8801A, MVG -8801B fail to open on the SI signal, DG load sequencer fails to complete (train A step 7) XPP-45A, Service Water Booster Pump fails to start.
Time Position Applicants Actions or Behavior REFERENCE PAGE FOR EOP-2.0 EOP-2.0
- 1. SI REINITIATION CRITERIA IF either of the following conditions occurs, THEN start Charging Pumps and operate valves as necessary:
RCS subcooling on TI-499A(B), A(B) TEMP °F, is LESS THAN 52.5°F [67.5°F].
PZR level can NOT be maintained GREATER THAN 10% [28%].
Annunciator XCP-612 4-2 is lit (PHASE B ISOL).
RCS pressure is LESS THAN 1418 psig AND SI flow is indicated on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM.
- 3. SECONDARY INTEGRITY TRANSITION CRITERIA IF any unisolated SG pressure is decreasing in an uncontrolled manner OR is completely depressurized, THEN GO TO EOP-3.0, FAULTED STEAM GENERATOR ISOLATION, Step 1.
- 4. TUBE RUPTURE TRANSITION CRITERIA IF any SG level increases in an uncontrolled manner OR if any SG has abnormal radiation, THEN start Charging Pumps and operate valves as necessary, and GO TO EOP-4.0, STEAM GENERATOR TUBE RUPTURE, Step 1.
- 5. COLD LEG RECIRCULATION TRANSITION CRITERION IF RWST level decreases to LESS THAN 18%, THEN GO TO EOP-2.2, TRANSFER TO COLD LEG RECIRCULATION, Step 1.
- 6. LOSS OF EMERGENCY COOLANT RECIRCULATION TRANSITION CRITERION IF Emergency Coolant Recirculation is established and subsequently lost, THEN GO TO EOP-2.4, LOSS OF EMERGENCY COOLANT RECIRCULATION, Step 1.
- 7. REDUCING CONTROL ROOM EMERGENCY VENTILATION Reduce Control Room Emergency Ventilation to one train in operation within 30 minutes of actuation. REFER TO SOP-505, CONTROL BUILDING VENTILATION SYSTEM Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 6,7,8 Page 34 of 44 Event
Description:
SBLOCA, MVG -8801A, MVG -8801B fail to open on the SI signal, DG load sequencer fails to complete (train A step 7) XPP-45A, Service Water Booster Pump fails to start.
Time Position Applicants Actions or Behavior NOTE EOP-2.0 The EOP REFERENCE PAGE should be monitored throughout the use of this procedure.
Seal Injection flow should be maintained to all RCPs.
Conditions for implementing Emergency Plan Procedures should be evaluated using EPP-001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN RO Check if RCPs should be stopped: EOP-2.0
- a. Check if either of the following criteria is met: EOP-2.0 Annunciator XCP-612 4-2 is lit (PHASE B ISOL).
OR RCS pressure is LESS THAN 1418 psig AND SI flow is indicated on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM.
EVALUATOR NOTE: This is a Critical Task but it may have been performed earlier as a Reference Page requirement.
CRITICAL EOP-2.0 RO b. Stop all RCPs.
TASK Verify no SG is FAULTED: EOP-2.0 BOP No SG pressure is decreasing in an uncontrolled manner.
No SG is completely depressurized.
Check INTACT SG levels: EOP-2.0
- a. Verify Narrow Range level in INTACT SGs is GREATER THAN
- BOP 26% [41%].
BOP Reset both SI RESET TRAIN A(B) Switches. EOP-2.0 Reset Containment Isolation: EOP-2.0 BOP RESET PHASE A - TRAIN A(B) CNTMT ISOL.
RESET PHASE B - TRAIN A(B) CNTMT ISOL.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 6,7,8 Page 35 of 44 Event
Description:
SBLOCA, MVG -8801A, MVG -8801B fail to open on the SI signal, DG load sequencer fails to complete (train A step 7) XPP-45A, Service Water Booster Pump fails to start.
Time Position Applicants Actions or Behavior BOP Check if Secondary radiation levels are normal: EOP-2.0
- a. Check radiation levels normal on: EOP-2.0 RM-G19A(B)(C), STMLN HI RNG GAMMA.
RM-A9, CNDSR EXHAUST GAS ATMOS MONITOR.
BOP RM-L3, STEAM GENERATOR BLOWDOWN LIQUID MONITOR.
RM-L10, SG BLOWDOWN CW DISCHARGE LIQUID MONITOR.
BOP b. Place SVX-9398A(B)(C), SG A(B)(C) SMPL ISOL, in AUTO. EOP-2.0 BOOTH OPERATOR: Acknowledge requests for support. Report no activity after 10 minutes.
- c. Notify Chemistry to sample all SG secondary sides, and EOP-2.0 BOP screen samples for abnormal activity using a frisker.
NOTE - Step 10.d EOP-2.0 If PZR level is LESS THAN 10% [28%], the PZR should refill from SI flow after pressure is stabilized.
- d. PZR level is GREATER THAN 10% [28%]. EOP-2.0
- e. GO TO EOP-1.2, SAFETY INJECTION TERMINATION, Step 1.
Check if RB Spray should be stopped: EOP-2.0
- a. Check if any RB Spray Pumps are running.
- b. Verify RB pressure is LESS THAN 11 psig.
- c. Depress both RESET TRAIN A(B) RB SPRAY.
NOTE - Step 11.d EOP-2.0 RB Spray must run for a minimum of four hours.
Anytime RB Spray Pumps are stopped, MVG-3003A(B), SPRAY HDR ISOL LOOP A(B),
should be closed for containment isolation Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 6,7,8 Page 36 of 44 Event
Description:
SBLOCA, MVG -8801A, MVG -8801B fail to open on the SI signal, DG load sequencer fails to complete (train A step 7) XPP-45A, Service Water Booster Pump fails to start.
Time Position Applicants Actions or Behavior
- CRS operation.
Check if RHR Pumps should be stopped: EOP-2.0
- a. Check RCS pressure:
- 1) RCS pressure is GREATER THAN 325 psig.
RO Check if RCS pressure is stable OR decreasing. EOP-2.0 BOP Check if pressure in all SGs is stable OR increasing. EOP-2.0 CAUTION - Step 15 EOP-2.0 The DGs should NOT be run at a minimum load or unloaded for extended periods of time, to prevent carbon fouling.
Check if DGs should be stopped: EOP-2.0
- a. Verify both ESF buses are energized by offsite power.
- b. Stop any unloaded DG. REFER TO SOP-306, EMERGENCY DIESEL GENERATOR.
Verify equipment is available for Cold Leg Recirculation: EOP-2.0
- a. Verify power is available for at least one RHR Pump:
BOP 1) PUMP A.
- 2) PUMP B.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 6,7,8 Page 37 of 44 Event
Description:
SBLOCA, MVG -8801A, MVG -8801B fail to open on the SI signal, DG load sequencer fails to complete (train A step 7) XPP-45A, Service Water Booster Pump fails to start.
Time Position Applicants Actions or Behavior CAUTION - Step 16.c EOP-2.0 If the swing CCW Pump is NOT available, the running pump should NOT be secured to shift it to fast speed, to prevent damage to the Charging Pump on that train.
If CCW can NOT be shifted to fast speed, this procedure should be continued. CCW alignment will be addressed in EOP-2.2, TRANSFER TO COLD LEG RECIRCULATION.
- c. Shift the CCW Train to fast speed in the Active Loop. REFER EOP-2.0 TO SOP-118, COMPONENT COOLING WATER.
- d. Consult with TSC personnel to determine if equipment required for Cold Leg Recirculation is available.
NOTE - Step 17 EOP-2.0 Presence of abnormally high levels of radioactivity in the AB indicates that a Containment breach may be in progress. Conditions for upgrading the Emergency status should be evaluated using EPP-001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN.
Check the AB for evidence of ECCS leakage: EOP-2.0
- a. Verify AB radiation levels are normal on:
RM-A3, MAIN PLANT VENT EXH ATMOS MONITOR:
PARTICULATE, IODINE, GAS.
RM-A13, PLANT VENT HI RANGE.
BOP RM-A11, AB VENT GAS ATMOS MONITOR.
Local area monitors.
- b. Verify annunciator XCP-631 6-1 is NOT lit (AB SMP LVL HI).
- c. Verify annunciators XCP-606 3-4 and XCP-607 3-4 are NOT lit (LD TRBL AB SMP/FLDRN LVL HI).
Obtain necessary Chemistry samples: EOP-2.0
- a. Ensure all RCS sample valves are in AUTO:
SVX-9364B and SVX-9365B, RCS LP B SMPL ISOL.
BOP SVX-9364C and SVX-9365C, RCS LP C SMPL ISOL.
- b. Notify Chemistry to sample the following:
RCS.
All SGs for isotopic activity.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 6,7,8 Page 38 of 44 Event
Description:
SBLOCA, MVG -8801A, MVG -8801B fail to open on the SI signal, DG load sequencer fails to complete (train A step 7) XPP-45A, Service Water Booster Pump fails to start.
Time Position Applicants Actions or Behavior Shut down and stabilize the Secondary Plant. REFER TO AOP- EOP-2.0 BOP 214.1, TURBINE TRIP.
Check if RCS cooldown and depressurization is required: EOP-2.0
- a. RCS pressure is GREATER THAN 325 psig.
- b. GO TO EOP-2.1, POST-LOCA COOLDOWN AND DEPRESSURIZATION, Step 1.
EVALUATOR NOTE: This scenario may be terminated when the actions of EOP-2.0 are completed and the decision is made to transition to EOP-2.1, POST-LOCA COOLDOWN AND DEPRESSURIZATION Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 1 Page 39 of 44 Event
Description:
SOP-106 DILUTION OPERATIONS Time Position Applicants Actions or Behavior EVALUATOR NOTE: This procedure section is to perform an Alternate RCS dilution.
NOTE 2.0 SOP-106
- 1. Energizing additional Pressurizer Heaters will enhance mixing.
- 2. LCV-115A, LTDN DIVERT TO HU-TK, will begin to modulate to the HU-TK position at 70%
level on LI-115, VCT LEVEL %.
RO Verify at least one Reactor Coolant Pump is running. SOP-106 RO Place RX COOL SYS MU switch to STOP. SOP-106 RO Place RX COOL SYS MU MODE SELECT switch to ALT DIL. SOP-106 (Peer)
RO Adjust FCV-168, TOTAL MU FLOW SET PT, to desired flow rate. SOP-106 RO Set FIS-168, TOTAL MU FLOW, batch integrator to desired SOP-106 volume. (Peer )
RO Place RX COOL SYS MU switch to START. SOP-106 RO Verify desired flow rate on FR-113, TOTAL MU GPM (F-168). SOP-106 RO Verify alternate dilution stops when preset volume is reached on SOP-106 FIS-168, TOTAL MU FLOW, batch integrator.
RO Place RX COOL SYS MU switch to STOP. SOP-106 RO Place RX COOL SYS MU MODE SELECT switch to AUTO. SOP-106 (Peer )
RO Adjust FCV-168, TOTAL MU FLOW SET PT, to 7.5 (120 gpm). SOP-106 RO Place RX COOL SYS MU switch to START. SOP-106 EVALUATOR NOTE: END OF SOP-106 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 6, 7, 8 Page 40 of 44 Event
Description:
EOP-1.0 Attachment 3 Time Position Applicants Actions or Behavior EVALUATOR NOTE: This attachment is to verify equipment status after Safety Injection has been initiated and is run concurrently with the main body of EOP-1.0.
Ensure EFW Pumps are running: EOP-1.0 Attachment 3
Ensure the following EFW valves are open: EOP-1.0 Attachment 3 BOP FCV-3531(3541)(3551), MD EFP TO SG A(B)(C).
FCV-3536(3546)(3556), TD EFP TO SG A(B)(C).
MVG-2802A(B), MS LOOP B(C) TO TD EFP.
BOP Verify total EFW flow is GREATER THAN 450 gpm. EOP-1.0 Attachment 3 Ensure FW Isolation: EOP-1.0 Attachment 3
- a. Ensure the following are closed:
FW Flow Control, FCV-478(488)(498).
BOP FW Isolation, PVG-1611A(B)(C).
FW Flow Control Bypass, FCV-3321(3331)(3341).
SG Blowdown, PVG-503A(B)(C).
SG Sample, SVX-9398A(B)(C).
- b. Ensure all Main FW Pumps are tripped.
Ensure SI Pumps are running: EOP-1.0 Attachment 3 BOP Two Charging Pumps are running.
Both RHR Pumps are running.
EOP-1.0 BOP Ensure two RBCU Fans are running in slow speed (one per train). Attachment 3 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 6, 7, 8 Page 41 of 44 Event
Description:
EOP-1.0 Attachment 3 Time Position Applicants Actions or Behavior Verify Service Water to the RBCUs: EOP-1.0 Attachment 3
- a. Ensure two Service Water Pumps are running.
- b. Verify both Service Water Booster Pumps A(B) are running.
ALTERNATIVE ACTION
- b. Perform the following:
- 1) IF XVB-3107A(B), RBCU 64A(B)/65A(B) RTN TO SW PND, for the non-running pump is closed, THEN start Service Water Booster Pump A(B).
- 2) IF XVB-3107A(B), RBCU 64A(B)/65A(B) RTN TO SW PND, BOP for the non-running pump is NOT closed, THEN perform the following:
a) Place the non-running Service Water Booster Pump A(B) in PULL TO LK NON-A.
b) Close XVB-3107A(B), RBCU 64A(B)/65A(B) RTN TO SW PND, for the non-running pump.
c) WHEN XVB-3107A(B), RBCU 64A(B)/65A(B) RTN TO SW PND, for the non-running pump is closed, THEN refill Train A(B) RBCUs with the Service Water Booster Pump A(B) tripped per SOP-117, SERVICE WATER SYSTEM.
- c. Verify GREATER THAN 2000 gpm flow for each train on:
FI-4466, SWBP A DISCH FLOW GPM.
FI-4496, SWBP B DISCH FLOW GPM.
BOP Verify two CCW Pumps are running. EOP-1.0 Attachment 3 BOP Ensure two Chilled Water Pumps and Chillers are running. EOP-1.0 Attachment 3 Verify both trains of Control Room Ventilation are running in EOP-1.0 BOP Attachment 3 Emergency Mode.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 6, 7, 8 Page 42 of 44 Event
Description:
EOP-1.0 Attachment 3 Time Position Applicants Actions or Behavior Check if Main Steamlines should be isolated: EOP-1.0 Attachment 3
- a. Check if any of the following conditions are met:
RB pressure GREATER THAN 6.35 psig.
OR Steamline pressure LESS THAN 675 psig.
BOP OR Steamline flow GREATER THAN 1.6 MPPH AND Tavg LESS THAN 552°F.
- b. Ensure all the following are closed:
MS Isolation Valves, PVM-2801A(B)(C).
MS Isolation Bypass Valves, PVM-2869A(B)(C).
Ensure Excess Letdown Isolation Valves are closed: EOP-1.0 Attachment 3 BOP PVT-8153, XS LTDN ISOL.
PVT-8154, XS LTDN ISOL.
Verify ESF monitor lights indicate Phase A AND Containment EOP-1.0 Ventilation Isolation on XCP-6103, 6104, and 6106. REFER TO Attachment 3 BOP ATTACHMENT 4, CONTAINMENT ISOLATION VALVE MCB STATUS LIGHT LOCATIONS, as needed.
Verify proper SI alignment: EOP-1.0 Attachment 3 BOP a. Verify SI valve alignment by verifying SAFETY INJECTION/PHASE A ISOL monitor lights are bright on XCP-6104.
EVALUATOR NOTE:
Valves MVG-8801A(B), HI HEAD TO COLD LEG INJ have failed to open on SI.
It is a Critical Task to establish SI by opening MVG-8801 (A or B) prior to NR RVLIS < 34%
or CET > 725°F.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 6, 7, 8 Page 43 of 44 Event
Description:
EOP-1.0 Attachment 3 Time Position Applicants Actions or Behavior BOP Verify proper SI alignment: EOP-1.0 Attachment 3 ALTERNATIVE ACTION
- a. Ensure proper SI valve alignment:
CRITICAL 1) Open MVG-8801A(B), HI HEAD TO COLD LEG INJ.
- 2) Close MVG-8107 and MVG-8108, CHG LINE ISOL.
TASK
- 3) Open LCV-115B(D), RWST TO CHG PP SUCT.
- 4) Close LCV-115C(E), VCT OUTLET ISOL.
BOP b. Verify all SAFETY INJECTION monitor lights are dim on XCP- EOP-1.0 6106. Attachment 3 BOP c. Verify SI flow on FI-943, CHG LOOP B CLD/HOT LG FLOW EOP-1.0 GPM Attachment 3 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 2 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 2 Event # 6, 7, 8 Page 44 of 44 Event
Description:
EOP-1.0 Attachment 3 Time Position Applicants Actions or Behavior BOP d. Check if RCS pressure is LESS THAN 325 psig. EOP-1.0 Attachment 3 BOP e. Verify RHR flow on: EOP-1.0 Attachment 3 FI-605A, RHR DISCHARGE PUMP A FLOW GPM.
AND FI-605B, RHR DISCHARGE PUMP B FLOW GPM.
EVALUATOR NOTE:
END OF EOP-1.0 ATTACHMENT 3.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Scenario Outline Form ES-D-1 Facility: VC SUMMER Scenario No.: 5 Op Test No.: NRC ILO 11-01 Examiners: Operators: CRS:
RO:
BOP:
Initial Reactor Critical at 10-3 % MOL following a short maintenance outage.
Conditions: The fuel has been pre-conditioned during previous operation.
The Main Steam system has being warmed and the MSIVs are open.
GOP-3 is complete to step 3.14.
A and B CWP running, C CWP will be returned to service on next shift.
Turnover: Increase power to approximately 1 - 3%.
Critical Task: Establish high head injection prior to NR RVLIS <34% or CETs >
725°F.
Failure of phase A (Valve 9312A and B do not close) - at least one valve must be closed in that line prior to finishing Attachment III.
Event Malf. No. Event Type* Event Description No.
R - RO, Perform Reactor Start-up IAW GOP-3 Reactor Startup 1 N/A N - BOP, CRS From Hot Standby To Startup (Mode 3 To Mode 2)
C - BOP, CRS 2 EF001T A MDEFW trip, Throttle flow with B MDEFW TS - CRS 3 RCS008H TS - CRS RCS Loop C THOT RTD Fails LOW.
B CWP Bearing Failure (A and B CWP running) 4 TB001T C-BOP Temperatures increase until it is tripped by the crew or it auto trips 5 CS004S C - RO, CRS A Charging Pump sheared shaft.
CRF004D4 2 Dropped Rods - Trip reactor (D4) (K2) 6 C - RO, CRS CRF004K2 Staggered rod drop - 1 minute apart.
7 PRS008 M - ALL PZR Steam Space LOCA (Auto-Trigger on reactor Trip).
SS003P Containment penetration valves PVA-9312 A & B fail to 8
SS004P close on Phase A.
CVC017B The running Charging Pump will trip on the SI and will 9 not restart. The Non-running Charging Pp does not start CVC017C on SI but will start manually
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Scenario Outline Form ES-D-1 The following notation is used in the ES-D-2 form Time column:
IOA designates Immediate Operator Action steps
- designates Continuous Action steps The crew will assume the watch having been pre-briefed on the Initial Conditions, the plan for this shift and any related operating procedures.
The scenario involves a plant startup so GOP-3, Reactor Startup from Hot Standby to Startup (Mode 3 to Mode 2), is being implemented. Step 3.13 has been completed and the reactor is critical in Mode 2. The secondary plant has been warmed with the turbine on turning gear.
The scenario starts on step 3.14. Power will be raised to the Point of Adding Heat.
EVENT 1: Normal Power Increase The RO will increase Reactor Power to the Point of Adding Heat and the crew will transition to GOP-4A, Power Operation (Mode 1 - Ascending). GTP-702 Attachment II G, Operational Mode Change Plant Startup - Entering Mode 1, is complete.
EVENT 2: A MDEFW Pump Trip On cue from the Examiner at approximately 1-3% power the A MDEFW will trip.
In accordance with XCP-622 1-3, MD EFP A Trip EFW flow must be reduced to below 400 gpm. The EFW flow requirement is approximately 180 gpm/percent so power is limited to approximately 2% using the B MDEFW unless the crew decides to use the TDEFW Pump.
The BOP will throttle EFW flow to the S/Gs using the B MDEFW IAW SOP-211, Emergency Feedwater System.
The CRS will evaluate the failure and determine that the A MSEFW Pump is inoperable and Tech Spec 3.7.1.2 applies. The action statement requires that be returned to operable status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.
On cue from the Examiner 2 Loop C THot RTDs will fail Low. The crew will respond in accordance with the ARP(s). The crew will implement AOP-401.2, Protection Channel RCS Loop RTD Failure, to identify the failed RTD and ensuring an operable loop is selected on T TR-412 Input Switch.
The CRS should enter the applicable TS for Reactor Trip Instrumentation and ESF Instrumentation to determine that the failed channel protection bistables must be placed in the tripped condition within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Scenario Outline Form ES-D-1 EVENT 4: B CWP Bearing Failure (A and B CWP running) Temperatures increase until it is tripped by the crew or it auto trips On cue from the Examiner the B CWP bearing will fail. Bearing temperatures will increase until the pump is stopped or an auto trip occurs. The operators will start the C CWP and verify proper operation.
EVENT 5: Charging Pump Sheared Shaft NOTE: The BOP will be called to the HVAC so the RO will perform the required actions.
The A Charging Pump shaft will shear. The RO will align and start the C Charging pump on the A Header. Permission to start the Charging Pump will be granted by a SS role player in the booth.
EVENT 6: Two Dropped Rods On cue from the Examiner, one rod will drop to the fully inserted position. The RO will take immediate actions IAW AOP-403.6, Dropped Control Rod. A second rod will drop 60 seconds after the first. IAW AOP-403.6, Dropped Control Rod, the RO will trip the Reactor and implement EOP-1.0 (E-0) Reactor Trip/Safety Injection Actuation.
EVENT 7: Steam Space LOCA A steam space LOCA will be automatically triggered on the Reactor Trip. Safety Injection will initiate on Low RCS Pressure. The crew will transition from EOP-1.0 (E-0) to EOP-2.0 (E-1).
EVENT 8: Containment penetration valves XVA9312 A & B fail to close on Phase A This event is the result of the Safety Injection Actuation. The BOP must close at least one Phase A isolation valve in the unisolated line (RMA-2 Sample Isolation Valves) during the conduct of EOP-1.0, Attachment 3 - SI Equipment Verification.
EVENT 9: The running Charging Pump will trip on the SI and will not restart This event is the result of the Safety Injection Actuation. One Charging pump was previously faulted. The running charging pump will trip on the SI and cannot be restarted. The sequence to restore charging flow is dependent on previous actions:
If the B Charging pump was running, the C charging pump must be racked-up and started.
If the C Charging pump was running, the B charging pump can be manually started from the MCB.
The crew will transition to EOP-2.0 (E-1), Loss of Reactor or Secondary Coolant, based on containment conditions. The crew will later transition to EOP-2.1 (ES-1.2), Post-LOCA Cooldown and Depressurization.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Scenario Outline Form ES-D-1 CRITICAL TASKS:
Establish high head injection prior to NR RVLIS <34% or CETs > 725°F.
Failure of phase A (Valve 9312A and B do not close) - at least one valve must be closed in that line prior to finishing Attachment III.
TERMINATION:
The scenario can be terminated after EOP-2.1, Post-LOCA Cooldown and Depressurization is implemented or at the discretion of the Examiner.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Scenario Outline Form ES-D-1 VC Summer 2013 NRC Scenario 5 Simulator Setup Initial Conditions:
IC-6, 10-3 % power MOL, (IC-328 for 2013)
Reactivity Management Plan/Turnover sheet for IC Set Rod Position = Bank D at 100 steps Boron Concentration = 1507 ppm FCV113 Pot Setting = 6.46 Xe = 0 pcm Burnup = 10002 MWD/MTU = 226 EFPD Prior to the scenario, crew should pre-brief on conditions and expectations for the Shift (maintain power, repairs estimated to be complete well before LCO action time expires).
VC Summer 2013 NRC Scenario 5 Simulator Setup (SNAP 328)
Conduct two-minute drill Mark up procedures in use with Circle and slash as applicable Pre-Exercise:
Ensure simulator has been checked for hardware problems (DORT, burnt out light bulbs, switch malfunctions, chart recorders, etc.)
TQP-801 Booth Operator checklist, has been completed Hang Red Tags for equipment out of service Complete Critical Data for GOP-3 Step 3.13 using the following data o RCS Pressure 2240 o Bank D at 100 steps o Tavg 558.5 o Time: Current time minus 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> o Stable power 10e-3 Need Copies of procedure because not laminated in simulator (both GOP3 and SOP-201)
Need to have booth operator put NI-45 in fast speed prior to turnover so crew can return it to slow speed (this is not part of the snap).
May need GOP-3 ATTACHMENT I Sign-off Identification List GOP-4A must be signed off through step 3.6.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Scenario Outline Form ES-D-1 PRE-LOAD:
Standard Simulator Setup PMP-LD003P XPP0138 LEAK DETECTION SUMP PMP LOSS OF POWER VLV-FW028W XVG01676-FW FW HDR RECIRC ISOL VLV LOSS OF POWER VLV-FW029W XVG01679-FW FW HTR RECIRC ISO VLV LOSS OF POWER VLV-CS052W XVT08141A-CS RCP A SEAL LEAKOFF VLV LOSS OF POWER VLV-CS054W XVT08141C-CS RCP C SEAL LEAKOFF VLV LOSS OF POWER VLV-CS053W XVT08141B-CS RCP B SEAL LEAKOFF VLV LOSS OF POWER Scenario Related VLV-SS003P XVA09312A-SS RMA2 CNMT ISO VLV FAIL POSITION Delay=0, Ramp=0, Final=100 VLV-SS004P XVA09312B-SS RMA2 CNMT ISO VLV FAIL POSITION Delay=0, Ramp=0, Final=100 EVENT 1: Perform Reactor Start-up IAW GOP-3 Reactor Startup From Hot Standby To Startup (Mode 3 To Mode 2)
No triggers needed Need Copies of procedure because not laminated in simulator (both GOP3 and SOP-201)
Need to have booth operator put NI-45 in fast speed prior to turnover so crew can return it to slow speed (this is not part of the snap).
EVENT 2: A MDEFW trip, Throttle flow with B MDEFW TRIGGER #2 o PMP-EF001T XPP021A MOTOR DRIVEN EFW PMP A TRIP ON COMMAND EVENT 3: RCS Loop 3 T-HOT RTDs Fails LOW.
TRIGGER 3 o MAL-RCS008H o MAL-RCS008G RCS RTD FAILURE (LOOP 3 - HOT LEG) 432B1, 432B2 Delay=0, Ramp=0, Final=530 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Scenario Outline Form ES-D-1 EVENT 4: B CWP Bearing Failure (A and B CWP running) Temperatures increase until it is tripped by the crew or it auto trips TRIGGER 4 o PMP-CW002B XPP0006B CW PMP B BRG FAILURE Initial = 2.25 Final = 3.25 Ramp = 05:00 EVENT 5: A Charging Pump sheared shaft.
TRIGGER 5 o PMP-CS004S XPP0043A CHRG/SI PMP A SHEARED SHAFT Delay=0, Ramp=0, Final=Active TRIGGER 15 o LOA-CVC043 CHARGING PUMP C SUPPLY BRKR TRAIN A POSITION TO: RACKED OUT TRIGGER 16 o LOA-CVC041 CHARGING PUMP A SUPPLY BRKR POSITION TO: RACKED IN EVENT 6: 2 Dropped Rods - Trip reactor (D4) (K2)
TRIGGER 6 o MAL-CRF004D4 DROPPED ROD D4, Delay=0, Ramp=0, Final=STATIONARY o MAL-CRF004K2 DROPPED ROD K2, Delay=00:01:00, Ramp=0, Final=STATIONARY EVENT 7: PZR Steam Space LOCA EVENT 7 TRIGGER o X06O013A == 1 or X06O013D == 1 Either RTB Green Light lit Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Scenario Outline Form ES-D-1 TRIGGER 7 o MAL-PRS008 PRESSURIZER STEAM SPACE LEAK Delay=0, Ramp=0, Final=500 EVENT 8: Containment penetration valves PVA-9312 A & B fail to close on Phase A.
Loaded as pre-event. These triggers cause them to close.
EVENT 17 X02I398C==1 o TRIGGER 17 o VLV-SS003P XVA09312A-SS RMA2 CNMT ISO VLV FAIL POSITION Delay=0, Ramp=00:00:01, Final=0 EVENT 18 X02I399C==1 o TRIGGER 18 o VLV-SS004P XVA09312B-SS RMA2 CNMT ISO VLV FAIL POSITION Delay=0, Ramp=00:00:01, Final=0 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Scenario Outline Form ES-D-1 EVENT 9: The running Charging Pump will trip on the SI and will not restart automatically or manually.
EVENT 9 TRIGGER - Determines Pressure Approaching SI, the B CHG Pump is running and the C CHG Pump has not tripped.
PT_457<1860 X04O058R==1 (CHG PUMP B RED LAMP)
JMLCVC17C!=1 (CHG PUMP C TRIP NOT TRIPPED) o TRIGGER 9 o MAL-CVC017B CHARGING PUMP B TRIP Delay=0, Ramp=0, Final=Active EVENT 10 TRIGGER - Determines Pressure Approaching SI, the C CHG Pump is running and the B CHG Pump has not tripped.
PT_457<1860 X04O056R==1 l X04O057R==1 (CHG PUMP C RED LAMP ON A) (CHG PUMP C RED LAMP ON B)
JMLCVC17B!=1 CHG PUMP B NOT TRIPPED o TRIGGER 10 o MAL-CVC017C CHARGING PUMP C TRIP Delay=0, Ramp=0, Final=Active Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 1 Page 10 of 42 Event
Description:
Perform Reactor Start-up IAW GOP-3 Reactor Startup From Hot Standby To Startup (Mode 3 To Mode 2).
Time Position Applicants Actions or Behavior GOP-3 BOOTH OPERATOR: No trigger necessary EVALUATOR NOTE:
The Unit is stable in Mode 3 at turnover with all surveillances completed for a Mode change to Mode 2. GOP-3 Reactor Startup From Hot Standby To Startup (Mode 3 To Mode 2).
GOP-3 is complete to step 3.14. The RO will bring the Reactor to the POAH and transition to GOP-4A Power Operation (Mode 1 - Ascending).
GOP-4A is complete through step 3.6.
GOP-3 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 1 Page 11 of 42 Event
Description:
Perform Reactor Start-up IAW GOP-3 Reactor Startup From Hot Standby To Startup (Mode 3 To Mode 2).
Time Position Applicants Actions or Behavior NOTE 3.14 GOP-3 Ensure sufficient Emergency Feedwater Flow exists prior to raising power RO Increase Reactor Power to between 1% and 3%. GOP-3 Maintain Narrow Range Steam Generator level between 60% and 65%
BOP using Emergency Feedwater.
At the Point of Adding Heat, if NR-45, NIS RECORDER, had previously GOP-3 RO been selected to HI speed place the recorder in LO speed.
CAUTION 3.16 GOP-3
- a. Adjustment of Tavg with the Rod Control System must not be attempted with the ROD CNTRL BANK SEL Switch in any position other than MAN.
- b. Manual rod control is required to establish equilibrium conditions, since C-5 blocks automatic rod withdrawal.
RO Maintain Tavg between 555°F and 559°F. GOP-3 Complete Attachment II.G, Operational Mode Change / Plant Startup - GOP-3 N/A Entering Mode 1, of GTP-702.
CRS Proceed to GOP-4A, Power Operation (Mode 1 - Ascending). GOP-3 EVALUATOR NOTE:
GOP-4A POWER OPERATION (MODE 1 - ASCENDING) has several line-up verifications.
GOP-4A is complete through step 3.6 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 1 Page 12 of 42 Event
Description:
Perform Reactor Start-up IAW GOP-3 Reactor Startup From Hot Standby To Startup (Mode 3 To Mode 2).
Time Position Applicants Actions or Behavior GOP-4A NOTE 3.1 through 3.11 GOP-4A Steps 3.1 through 3.11 raise Reactor Power from 1% to 25%.
EVALUATOR NOTE: The next event may be initiated after GOP-4A is entered.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 2 Page 13 of 42 Event
Description:
A MDEFW Trip
`
Time Position Applicants Actions or Behavior EVALUATOR NOTE: Event 2 should be initiated on entry into EOP-4A, Power Operation (Mode 1 - Ascending).
Power should be between 2.5 - 3% when this event is triggered. If power is maintained too low direct the Booth Operator to require the CRS to raise power to 2.5 - 3%.
BOOTH OPERATOR: If directed by the Evaluator - contact the CRS and direct power to be raised to between 2.5 and 3%.
BOOTH OPERATOR: Initiate Event 2 (TRIGGER 2) when directed.
Indications Available:
XCP-622 1-3, MD EFP A TRIP XCP-622 1-3 BOP Enters ARP-001-XCP-622, 1-3 EVALUATOR NOTE: The CRS could direct the RO to reduce power to ensure MD EFW Pump B is sufficient and/or for the BOP to start the TD EFW Pump. The TD EFW Pump is not normally used for SG level control during heatup/cooldown.
XCP-622 1-3 CORRECTIVE ACTIONS:
XCP-622 1-3
- 1. Start Motor Driven Emergency Feedwater Pump B if necessary to BOP maintain Steam Generator levels.
XCP-622 1-3 BOP 2. Reduce feedwater demand to less than 400 gpm.
XCP-622 1-3 CRS 3. Refer to SOP-211.
XCP-622 1-3 SUPPLEMENTAL ACTIONS:
XCP-622 1-3
- 1. If Steam Generator levels cannot be maintained with one motor driven BOP pump, start the Turbine Driven Emergency Feedwater Pump.
XCP-622 1-3
- 2. Place PUMP A control switch in NORMAL-AFTER-STOP to clear the BOP alarm.
XCP-622 1-3 CRS 3. Determine the cause of the trip and correct as soon as possible.
XCP-622 1-3 CRS 4. If the pump is inoperable, refer to Tech Spec 3.7.1.2.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 2 Page 14 of 42 Event
Description:
A MDEFW Trip
`
Time Position Applicants Actions or Behavior CREW Dispatches an AO to investigate BOOTH OPERATOR:
Wait 2 minutes then report MD EFW Pump A breaker tripped and the overcurrent relay actuated.
CRS Contacts Work Control and/or Maintenance for assistance.
TECH SPEC CRS Enters TS 3.7.1.2, Action a:
TECH SPEC With one emergency feedwater pump inoperable, restore the required emergency feedwater pumps to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or CRS be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
EVALUATOR NOTE: When SG levels are under control and the TS entry is complete, cue Event 3, RCS Loop C THOT RTD Fails Low.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 3 Page 15 of 42 Event
Description:
RCS Loop C THOT RTDs Fails LOW (432B1, 432B2)
Time Position Applicants Actions or Behavior BOOTH OPERATOR: Initiate Event 3 (TRIGGER 3) when directed.
Indications Available:
XCP-615-1-2, RCS TAVG LO; XCP-615-1-3, RCS TAVG LO-LO; XCP-615-1-5, RCS TAVG DEV HI/LO; XCP-615-3-5, RCS T DEV HI/LO RO Responds to multiple alarms.
RO Enters ARP-001-XCP-615 1-2. XCP-615 1-2 CORRECTIVE ACTIONS: XCP-615 1-2
- 1. Monitor TI-412D, TI-422D and TI-432D to determine if a channel XCP-615 1-2 RO failed.
RO 2. Place Rod Control in MAN and match Tavg to Tref. XCP-615 1-2 SUPPLEMENTAL ACTIONS: XCP-615 1-2
- 1. If a channel has failed, perform the following: XCP-615 1-2 CRS a. Refer to AOP-401.2 to trip all bistables associated with that channel.
- b. Refer to Technical Specification Table 3.3-3 for minimum channel requirements.
- 2. I f the Rod Control System malfunctioned, refer to AOP-403.4, CRS Failure of Control Rods to Move.
Refers to AOP-401.2, PROTECTION CHANNEL RCS LOOP RTD AOP-401.2 CRS FAILURE.
Determine which RCS loop has a failed RTD by comparing loop T AOP-401.2 RO and Tavg indicators.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 3 Page 16 of 42 Event
Description:
RCS Loop C THOT RTDs Fails LOW (432B1, 432B2)
Time Position Applicants Actions or Behavior RO Reports Loop 3C Thot has failed.
Ensure an operable loop is selected on T TR-412 INPUT SEL AOP-401.2 RO Switch.
BOOTH OPERATOR: Acknowledge direction to trip bistables and report that you will get it done before the end of the shift. The bistables need not be tripped during the scenario.
Within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, place the failed channel protection bistables in a AOP-401.2 CRS tripped condition:
- b. Record the following for each associated bistable on SOP-401, AOP-401.2 Reactor Protection And Control System, Attachment I:
CRS Instrument.
Associated Bistable.
Bistable Location.
STPs.
BOOTH OPERATOR: Acknowledge request for assistance.
CRS c. Notify the I&C Department to place the identified bistables in trip. AOP-401.2 CRS Contacts Work Control/I&C for assistance.
CRS Determine and correct the cause of the channel failure. AOP-401.2 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 3 Page 17 of 42 Event
Description:
RCS Loop C THOT RTDs Fails LOW (432B1, 432B2)
Time Position Applicants Actions or Behavior Excerpt from 401.2, PROTECTION CHANNEL RCS LOOP RTD FAILURE Excerpt from Table 3.3-1 TECH SPEC Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 3 Page 18 of 42 Event
Description:
RCS Loop C THOT RTDs Fails LOW (432B1, 432B2)
Time Position Applicants Actions or Behavior Excerpt from Table 3.3-3 TECH SPEC Enters TS Table 3.3-1 (Functional Units 7 and 8), Action 6# and TECH SPEC CRS Table 3.3-3 4d With the number of OPERABLE channels one less than the Total TECH SPEC CRS Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:
The inoperable channel is placed in the tripped condition within TECH SPEC CRS 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />; and The Minimum Channels OPERABLE requirement is met; TECH SPEC however, the inoperable channel may be bypassed for up to 12 CRS hours for surveillance testing of other channels per Specification 4.3.1.1.
EVALUATOR NOTE: The next event may be initiated after all actions are completed and the applicable Tech Spec have been identified.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 4 Page 19 of 42 Event
Description:
B CWP Bearing Failure Time Position Applicants Actions or Behavior BOOTH OPERATOR: Initiate Event 4 (TRIGGER 4) when directed.
Indications Available:
XCP-628-3-2, CWP OVRLD BOP Responds to alarm XCP-628-3-2, CWP OVRLD BOP Enters ARP-001-XCP-628-3-2 XCP-628 3-2 CORRECTIVE ACTIONS: XCP-628 3-2
- 1. Determine which pump is overloaded by monitoring CIRC WTR PUMP AMPS and amber lights.
- 2. If only two Circulating Water Pumps are running, start an additional Circulating Water Pump per SOP-207 if available.
- 3. Determine if a single phasing event is in progress by diagnosis of BOP any combination of the following symptoms: XCP-628 3-1
- a. Vibration Alarms are received for other equipment.
- b. MCB Potential Lights are not lit.
- c. MCB Amber Overload lights are lit for running equipment or Motor Overload Alarms are received.
- d. MCB Undervoltage Alarms.
- e. Affected bus local 7.2 KV Bus ammeters.
EVALUATOR NOTE: The following steps are to start the C CWP BOOTH OPERATOR:
If the CWP trips report the Circulating Water Pump breaker tripped on overload - cause unknown.
If called to be stationed at the CWP Breaker with safety gear; o WAIT 1 MIN.
o Report you are standing by at the supply breaker.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 4 Page 20 of 42 Event
Description:
B CWP Bearing Failure Time Position Applicants Actions or Behavior CAUTION 2.1
- a. An Operator with the required ISP-027 safety gear in place should be stationed at the supply breaker for the Circulating Water Pump to be started should local tripping of the breaker be required.
- b. Circulating Water Pump operation is limited to prevent exceeding the CW Pump House SOP-207 electrical duct bank design current rating when XSW1C2 is aligned to emergency feed as follows:
- 1) Only two Circulating Water Pumps may be in operation for the first 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />.
- 2) Only Circulating Water Pump A or Circulating Water Pump C may be in operation following 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />.
Start one of the following: (PEER )
BOP SOP-207
- c. XPP-0006C, CWP C.
Verify the discharge isolation valve for the started Circulating Water BOP Pump, MVB-802A(B)(C), A(B)(C) DISCH ISOL, is 30% open and the SOP-207 red indicator light is illuminated.
Place MVB-802A(B)(C), A(B)(C) DISCH ISOL, for the started BOP SOP-207 Circulating Water Pump to OPEN.
When MVB-802A(B)(C), A(B)(C) DISCH ISOL, is full open, return BOP SOP-207 MVB-802A(B)(C), A(B)(C) DISCH ISOL, to AUTO.
BOOTH OPERATOR: Acknowledge request to check the Traveling Screen wash supply valves.
Ensure the Traveling Screen wash supply valves are open for the Circulating Water Pump placed in service (CW-436):
BOP SOP-207
- c. XVG00813E(F)-CW, TRAVELING SCREEN 5E(F) SUPPLY VALVE.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 4 Page 21 of 42 Event
Description:
B CWP Bearing Failure Time Position Applicants Actions or Behavior If XPP-0006C, CWP C, is the pump restored to service, close breaker BOP APN4016 01-03-05, XST0012 SCREEN WASH PP DISCH SOP-207 TRAINER, to re-enable screen wash strainer backwash.
BOP Align the Screen Wash System for normal operation per Section III. SOP-207 EVALUATOR NOTE: The next event may be initiated after the C CWP has been started.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 5 Page 22 of 42 Event
Description:
A Charging Pump sheared shaft.
Time Position Applicants Actions or Behavior EVALUATOR NOTE: Direct the Booth Operator to call the CRS.
BOOTH OPERATOR: Call the CRS and direct that the BOP go to the HVAC panel to check the Control Room Emergency Ventilation lineup.
EVALUATOR NOTE: Hold the BOP at the HVAC panel until notified by the Lead Examiner that the BOP may be released.
BOOTH OPERATOR: Initiate Event 5 (TRIGGER 5) when directed.
Indications Available:
XCP-614, 5-1, CHG LINE FLO HI/LO CORRECTIVE ACTIONS: XCP-614, 5-1
- 1. If the running Charging Pump suction flowpath has become XCP-614, 5-1 RO isolated, secure the Charging Pump and go to AOP-102.2, Loss of Charging.
- 2. If the PUMP A(B) or PUMP C TRAIN A(B) ammeter indication is XCP-614, 5-1 RO abnormal for the running Charging Pump and the pump must be tripped, go to AOP-102.2, Loss of Charging. (YES)
CRS Directs entry to AOP-102.2, Loss of Charging.
RO 4. Monitor FI-122A, CHG FLOW GPM. XCP-614, 5-1
- 5. Verify the Charging header valve lineup: XCP-614, 5-1
- a. Verify the following valves are open:
- 1) FCV-122, CHG FLOW.
- 2) MVG-8107, CHG LINE ISOL.
- 3) MVG-8108, CHG LINE ISOL.
RO 4) Either of the following:
a) PVT-8146, NORM CHG TO RCS LP B.
b) PVT-8147, ALT CHG TO RCS LP A.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 5 Page 23 of 42 Event
Description:
A Charging Pump sheared shaft.
Time Position Applicants Actions or Behavior
- 6. If Charging flow has NOT been lost but a loss of automatic control XCP-614, 5-1 of FCV-122, CHG FLOW, is suspected perform the following:
- a. Place FCV-122, CHG FLOW, in MAN and adjust, as required, to maintain TI-140, REGEN HX OUT TEMP °F, between RO 250°F and 350°F while maintaining Pressurizer level.
- b. If FCV-122, CHG FLOW, fails to respond in MAN, perform SOP-102, Off Normal, Response To Malfunction Of FCV-122, to bypass FCV00122-CS, XCP-614, 5-1CHARGING HEADER FLOW CONTROL VALVE (AB-412 West Pen).
CRS Implement AOP-102.2, Loss of Charging.
CAUTION AOP-102.2 Seal water injection should be maintained any time the RCS is pressurized.
NOTE AOP-102.2 The Alternate Seal Injection System should deliver 20 gpm of borated water from the RWST to the RCS.
- FI-122A, CHG FLOW GPM, between 30 gpm and 115 gpm.
- Pump amps between 30 amps and 50 amps.
- PI-121, CHG PRESS PSIG, between 2650 psig and 2850 psig.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 5 Page 24 of 42 Event
Description:
A Charging Pump sheared shaft.
Time Position Applicants Actions or Behavior ALTERNATIVE ACTION AOP-102.2 IF Charging Pump has tripped or flow is abnormal, THEN perform the following:
a) Ensure the Charging Pump is secured.
b) Close all Letdown Isolation Valves:
- 1) PVT-8149A(B)(C), LTDN ORIFICE A(B)(C) ISOL.
- 2) PVT-8152, LTDN LINE ISOL.
- 3) LCV-459, LTDN LINE ISOL.
- 4) LCV-460, LTDN LINE ISOL.
RO c) Close FCV-122, CHG FLOW.
d) Verify CCW flow to the RCP Thermal Barriers is GREATER THAN 90 gpm on FI-7273A(B), THERM BARR FLOW GPM.
e) Display Dedicated Display ZZRCPBRG on the IPCS to monitor RCP temperatures.
f) Determine if Alternate Seal Injection is in service as indicated by both the following annunciators are lit:
BOOTH OPERATOR: Acknowledge requests for support BOOTH OPERATOR: If directed to check the A charging pump while it is running -
report the motor is running with no pump discharge pressure.
g) Contact Electrical and Mechanical Maintenance to investigate. AOP-102.2 CRS h) GO TO Step 3.
- a. IF Charging Pump suction is aligned to the VCT, THEN ensure both LCV-115C(E), VCT OUTLET ISOL, are open.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 5 Page 25 of 42 Event
Description:
A Charging Pump sheared shaft.
Time Position Applicants Actions or Behavior
- b. Ensure the following valves are open: AOP-102.2
- 1) MVG-8106, CHG PP.
- 2) MVT-8109A(B)(C), CHG PP A(B)(C).
- 3) MVG-8130A(B), LP A SUCT TO CHG PP C.
- 4) MVG-8131A(B), LP B SUCT TO CHG PP C.
- 5) MVG-8132A(B), CHG PP C TO LP A DISCH.
- 6) MVG-8133A(B), CHG PP C TO LP B DISCH.
BOOTH OPERATOR:
When dispatched to check pressures, report that all gauges read ~ 57 psig.
BOOTH OPERATOR:
The following triggers will allow operation of the C Charging Pump on the A Header.
Trigger 15 - Racks Up Charging Pump C on the A Header.
Trigger 16 - Racks Down Charging Pump A.
- 1) Ensure MVG-8107, CHG LINE ISOL, is open.
- 2) Ensure MVG-8108, CHG LINE ISOL, is open.
- 3) Ensure FCV-122, CHG FLOW, is in MAN and CLOSE.
- 4) Ensure one of the following valves is open:
- 5) Verify VCT level is GREATER THAN 20%.
- 6) Locally verify Charging Pump suction pressure is between 50 psig and 100 psig as indicated on the following (AB-388):
- PI-151A, SUCTION PRESS, for Charging Pump A.
- PI-152A, SUCTION PRESS, for Charging Pump B.
- PI-153A, SUCTION PRESS, for Charging Pump C.
BOOTH OPERATOR:
NOTE: The CRS may assume authority for making the decision to start a Charging Pump. If the CRS calls the Shift Supervisor for permission to start the pump as stated in the procedure, grant permission.
- 4. With Shift Supervisor's permission, start a Charging Pump, while AOP-102.2 RO monitoring RCP temperatures. Refer To SOP-102, Chemical And Volume Control System.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 5 Page 26 of 42 Event
Description:
A Charging Pump sheared shaft.
Time Position Applicants Actions or Behavior EVALUATOR NOTE: The Operator will ensure the following as per SOP-102, CHEMICAL AND VOLUME CONTROL SYSTEM:
Breaker Racked Up Aux Oil Pump Running CCW Operating Chill water is Operating Suction Pressure > 15 psig (Local)
Miniflow isol open
- 5. When a Charging Pump is operating THEN perform the following. AOP-102.2 Refer To SOP-102, Chemical And Volume Control System.
- Place Charging and Normal Letdown in service.
- Secure Alternate Seal Injection.
CRS 6. RETURN TO the Procedure and Step in effect. AOP-102.2 EVALUATOR NOTE: The next event may be initiated after the a Charging Pump has been started.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 6 Page 27 of 42 Event
Description:
2 Dropped Rods (D4 - K2 Staggered by 1 minute) - Trip Reactor Time Position Applicants Actions or Behavior BOOTH OPERATOR: Initiate Event 6 (TRIGGER 6) when directed.
EVALUATOR NOTE: 1 dropped rod - annunciators and rod drive to manual.
Indication Available:
XCP-621 3-1 ONE ROD ON BOTTOM CORRECTIVE ACTIONS: XCP-621 3-1 RO If a shutdown or control group rod has dropped and the Reactor did XCP-621 3-1 not trip, implement AOP-403.6, Dropped Control Rod.
EVALUATOR NOTE: The second rod drops 1 minute after the first so only the Immediate Operator Actions are detailed.
IOA RO Verify only one Control Rod has dropped. AOP-403.6 IOA RO Place ROD CNTRL BANK SEL Switch in MAN. AOP-403.6 EVALUATOR NOTE: The following steps occur after the 2nd rod drops.
Indications Available:
XCP-621, 3-2 RODS ON BOTTOM CORRECTIVE ACTIONS: XCP-621 3-2 RO 1. If two or more rods have dropped, manually trip the Reactor and XCP-621 3-2 implement EOP-1.0, Reactor Trip/Safety Injection Actuation.
CRS Directs a manual Reactor trip and EOP-1.0 entry.
EVALUATOR NOTE: The next event is automatically inserted on the Reactor Trip.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 7, 8 & 9 Page 28 of 42 Event
Description:
PZR Steam Space LOCA, Running Charging Pump Trips on SI, PVA-9312 A & B fails to close on Phase A Time Position Applicants Actions or Behavior BOOTH OPERATOR: Event 7 (TRIGGER 7) is automatically triggered on the Reactor Trip.
REFERENCE PAGE FOR EOP-1.0 EOP-1.0 1 RCP TRIP CRITERIA
- a. IF Phase B Containment Isolation has actuated (XCP-612 4-2), THEN trip all RCPs.
- b. IF both of the following conditions occur, THEN trip all RCPs:
AND
- RCS Wide Range pressure is LESS THAN 1418 psig.
2 REDUCING CONTROL ROOM EMERGENCY VENTILATION Reduce Control Room Emergency Ventilation to one train in operation within 30 minutes of actuation. REFER TO SOP-505, CONTROL BUILDING VENTILATION SYSTEM.
3 MONITOR SPENT FUEL COOLING Periodically check status of Spent Fuel Cooling by monitoring the following throughout event recovery:
- Spent Fuel Pool level.
- Spent Fuel Pool temperature.
EVALUATOR NOTE: Failures 8 and 9 are preloaded.
The B or C Charging pump started in the previous event will trip and the Backup pump will not auto-start.
Indications Available: Multiple annunciates including:
XCP 616, 2-2 PZR PRESS LO XCP 616, 2-3 PZR PRESS HI/LO First Out - XCP-626 5-3 PZR PRESS LO First Out - XCP-626 5-3 PZR SI AUTOMATIC ACTIONS: XCP-626 5-1
- 1. Reactor Trip. XCP-626 5-3
- 2. Turbine Trip.
- 3. Generator Trip (after 30 second delay).
CORRECTIVE ACTIONS: XCP-626 5-1 CRS 1. Trip the Reactor and go to EOP-1.0, Reactor Trip/Safety Injection XCP-626 5-3 Actuation.
Appendix D NUREG 1021 Revision 9
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Description:
PZR Steam Space LOCA, Running Charging Pump Trips on SI, PVA-9312 A & B fails to close on Phase A Time Position Applicants Actions or Behavior CRS Direct EOP-1.0 entry 1 Verify Reactor Trip: EOP-1.0
- Trip the Reactor using either Reactor Trip Switch.
IOA Crew
- Verify all Reactor Trip and Bypass Breakers are open.
- Verify all Rod Bottom Lights are lit.
- Verify Reactor Power level is decreasing.
2 Verify Turbine/Generator Trip: EOP-1.0 IOA BOP
- 2) Ensure the GEN FIELD BKR is open.
- 3) Ensure the EXC FIELD CNTRL is tripped.
IOA BOP 3 Verify both ESF buses are energized. EOP-1.0 4 Check if SI is actuated: EOP-1.0
- a. Check if either:
- SI ACT status light is bright on XCP-6107 1-1.
- Any red first-out SI annunciator is lit on XCP-626 top row.
- c. GO TO Step 6.
EVALUATOR NOTE: Attachment 3 is included as page 38.
BOP 6 Initiate ATTACHMENT 3, SI EQUIPMENT VERIFICATION. EOP-1.0 BOP 7 Announce plant conditions over the page system. EOP-1.0 8 Verify RB pressure has remained LESS THAN 12 psig on PR- EOP-1.0
Appendix D NUREG 1021 Revision 9
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Description:
PZR Steam Space LOCA, Running Charging Pump Trips on SI, PVA-9312 A & B fails to close on Phase A Time Position Applicants Actions or Behavior 9 Check RCS temperature: EOP-1.0
10 Check PZR PORVs and Spray Valves: EOP-1.0
- a. PZR PORVs are closed.
- b. PZR Spray Valves are closed.
- MVG-8000A, RELIEF 445 A ISOL.
- MVG-8000B, RELIEF 444 B ISOL.
- MVG-8000C, RELIEF 445 B ISOL.
- d. Verify at least one PZR PORV Block Valve is open.
NOTE - Step 11 Seal Injection flow should be maintained to all RCPs.
11 Check if RCPs should be stopped: EOP-1.0
- a. Check if either of the following criteria is met:
- Annunciator XCP-612 4-2 is lit (PHASE B ISOL).
- RCS pressure is LESS THAN 1418 psig AND SI flow is indicated on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM.
- b. Stop all RCPs.
Appendix D NUREG 1021 Revision 9
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Description:
PZR Steam Space LOCA, Running Charging Pump Trips on SI, PVA-9312 A & B fails to close on Phase A Time Position Applicants Actions or Behavior 12 Verify no SG is FAULTED: EOP-1.0 BOP
- No SG pressure is decreasing in an uncontrolled manner.
- No SG is completely depressurized.
13 Verify Secondary radiation levels indicate SG tubes are NOT EOP-1.0 RUPTURED:
- RM-G19A(B)(C), STMLN HI RNG GAMMA.
- RM-A9, CNDSR EXHAUST GAS ATMOS MONITOR.
- RM-L3, STEAM GENERATOR BLOWDOWN LIQUID MONITOR.
- RM-L10, SG BLOWDOWN CW DISCHARGE LIQUID MONITOR.
14 Check if the RCS is INTACT: EOP-1.0
- a. RB radiation levels are normal on:
- RM-G7, CNTMT HI RNG GAMMA.
- RM-G18, CNTMT HI RNG GAMMA.
BOP b. RB Sump levels are normal.
- c. RB pressure is LESS THAN 1.5 psig.
- d. The following annunciators are NOT lit:
- XCP-606 2-2 (RBCU 1A/2A DRN FLO HI).
- XCP-607 2-2 (RBCU 1B/2B DRN FLO HI).
15 GO TO EOP-2.0, LOSS OF REACTOR OR SECONDARY EOP-1.0 CRS COOLANT, Step 1.
Appendix D NUREG 1021 Revision 9
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Description:
PZR Steam Space LOCA, Running Charging Pump Trips on SI, PVA-9312 A & B fails to close on Phase A Time Position Applicants Actions or Behavior 1 SI REINITIATION CRITERIA EOP-2.0 IF either of the following conditions occurs, THEN start Charging Pumps and operate valves as necessary:
- RCS subcooling on TI-499A(B), A(B) TEMP°F, is LESS THAN 52.5°F [67.5°F].
- PZR level can NOT be maintained GREATER THAN 10% [28%].
2 RCP TRIP CRITERIA IF either of the following criteria is met, THEN trip all RCPs:
- Annunciator XCP-612 4-2 is lit (PHASE B ISOL).
- RCS pressure is LESS THAN 1418 psig AND SI flow is indicated on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM.
3 SECONDARY INTEGRITY TRANSITION CRITERIA IF any unisolated SG pressure is decreasing in an uncontrolled manner OR is completely depressurized, THEN GO TO EOP-3.0, FAULTED STEAM GENERATOR ISOLATION, Step 1.
4 TUBE RUPTURE TRANSITION CRITERIA IF any SG level increases in an uncontrolled manner OR if any SG has abnormal radiation, THEN start Charging Pumps and operate valves as necessary, and GO TO EOP-4.0, STEAM GENERATOR TUBE RUPTURE, Step 1.
5 COLD LEG RECIRCULATION TRANSITION CRITERION IF RWST level decreases to LESS THAN 18%, THEN GO TO EOP-2.2, TRANSFER TO COLD LEG RECIRCULATION, Step 1.
6 LOSS OF EMERGENCY COOLANT RECIRCULATION TRANSITION CRITERION IF Emergency Coolant Recirculation is established and subsequently lost, THEN GO TO EOP-2.4, LOSS OF EMERGENCY COOLANT RECIRCULATION, Step 1.
7 REDUCING CONTROL ROOM EMERGENCY VENTILATION Reduce Control Room Emergency Ventilation to one train in operation within 30 minutes of actuation. REFER TO SOP-505, CONTROL BUILDING VENTILATION SYSTEM.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 7, 8 & 9 Page 33 of 42 Event
Description:
PZR Steam Space LOCA, Running Charging Pump Trips on SI, PVA-9312 A & B fails to close on Phase A Time Position Applicants Actions or Behavior NOTE EOP-2.0 The EOP REFERENCE PAGE should be monitored throughout the use of this procedure.
Seal Injection flow should be maintained to all RCPs.
Conditions for implementing Emergency Plan Procedures should be evaluated using EPP-001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN.
Check if RCPs should be stopped: EOP-2.0
- a. Check if either of the following criteria is met:
Annunciator XCP-612 4-2 is lit (PHASE B ISOL).
BOP OR RCS pressure is LESS THAN 1418 psig AND SI flow is indicated on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM.
EVALUATOR NOTE: The RCPs should not be stopped until SI flow is established.
BOP b. Stop all RCPs. EOP-2.0 Verify no SG is FAULTED: EOP-2.0 BOP No SG pressure is decreasing in an uncontrolled manner.
No SG is completely depressurized.
Check INTACT SG levels: EOP-2.0
- a. Verify Narrow Range level in INTACT SGs is GREATER THAN
- BOP 26% [41%].
BOP Reset both SI RESET TRAIN A(B) Switches. EOP-2.0 Reset Containment Isolation: EOP-2.0 BOP RESET PHASE A - TRAIN A(B) CNTMT ISOL.
RESET PHASE B - TRAIN A(B) CNTMT ISOL.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 7, 8 & 9 Page 34 of 42 Event
Description:
PZR Steam Space LOCA, Running Charging Pump Trips on SI, PVA-9312 A & B fails to close on Phase A Time Position Applicants Actions or Behavior Check if Secondary radiation levels are normal: EOP-2.0
- a. Check radiation levels normal on:
- RM-G19A(B)(C), STMLN HI RNG GAMMA.
- RM-A9, CNDSR EXHAUST GAS ATMOS MONITOR.
- RM-L3, STEAM GENERATOR BLOWDOWN LIQUID BOP MONITOR.
- RM-L10, SG BLOWDOWN CW DISCHARGE LIQUID MONITOR.
- b. Place SVX-9398A(B)(C), SG A(B)(C) SMPL ISOL, in AUTO.
- c. Notify Chemistry to sample all SG secondary sides, and screen samples for abnormal activity using a frisker.
Check PZR PORVs and Block Valves: EOP-2.0
- a. Verify power is available to the PZR PORV Block Valves:
- BOP 1) MVG-8000A, RELIEF 445 A ISOL.
- 2) MVG-8000B, RELIEF 444 B ISOL.
- 3) MVG-8000C, RELIEF 445 B ISOL.
CAUTION - Step 7.b EOP-2.0 If any PZR PORV opens because of high PZR pressure, Step 7.b should be repeated after pressure decreases to LESS THAN 2330 psig, to ensure the PORV recloses.
BOP b. Verify all PZR PORVs are closed. EOP-2.0 BOP c. Verify at least one PZR PORV Block Valve is open. EOP-2.0 Place both ESF LOADING SEQ A(B) RESETS to: EOP-2.0 BOP a. NON-ESF LCKOUTS.
- b. AUTO-START BLOCKS.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 7, 8 & 9 Page 35 of 42 Event
Description:
PZR Steam Space LOCA, Running Charging Pump Trips on SI, PVA-9312 A & B fails to close on Phase A Time Position Applicants Actions or Behavior Establish Instrument Air to the RB: EOP-2.0
- a. Start one Instrument Air Compressor and place the other in Standby.
- b. Open PVA-2659, INST AIR TO RB AIR SERV.
- c. Open PVT-2660, AIR SPLY TO RB.
Check if SI flow should be reduced: EOP-2.0
- a. RCS subcooling on TI-499A(B), A(B) TEMP °F, is GREATER THAN 52.5°F [67.5°F].
- b. Secondary Heat Sink is adequate:
OR Narrow Range level is GREATER THAN 26% [41%] in at least one INTACT SG.
ALTERNATIVE ACTION EOP-2.0 BOP GO TO Step 11 Check if RB Spray should be stopped: EOP-2.0
- a. Check if any RB Spray Pumps are running.
- b. Verify RB pressure is LESS THAN 11 psig.
- c. Depress both RESET TRAIN A(B) RB SPRAY.
NOTE - Step 11.d EOP-2.0 RB Spray must run for a minimum of four hours.
Anytime RB Spray Pumps are stopped, MVG-3003A(B), A(B), should be closed for containment isolation.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 7, 8 & 9 Page 36 of 42 Event
Description:
PZR Steam Space LOCA, Running Charging Pump Trips on SI, PVA-9312 A & B fails to close on Phase A Time Position Applicants Actions or Behavior CAUTION - Step 12 EOP-2.0 RCS pressure should be monitored. If RCS pressure decreases in an uncontrolled manner to LESS THAN 325 psig, the RHR Pumps must be manually restarted to supply water to the RCS.
Check if RHR Pumps should be stopped: EOP-2.0
- a. Check RCS pressure:
- 1) RCS pressure is GREATER THAN 325 psig.
BOP Check if RCS pressure is stable OR decreasing. EOP-2.0 BOP Check if pressure in all SGs is stable OR increasing. EOP-2.0 Check if DGs should be stopped: EOP-2.0
- a. Verify both ESF buses are energized by offsite power.
- b. Stop any unloaded DG. REFER TO SOP-306, EMERGENCY DIESEL GENERATOR.
Verify equipment is available for Cold Leg Recirculation: EOP-2.0
- a. Verify power is available for at least one RHR Pump:
- 1) PUMP A.
- 2) PUMP B.
CAUTION - Step 16.c EOP-2.0
- If the swing CCW Pump is NOT available, the running pump should NOT be secured to shift it to fast speed, to prevent damage to the Charging Pump on that train.
- If CCW can NOT be shifted to fast speed, this procedure should be continued. CCW alignment will be addressed in EOP-2.2, TRANSFER TO COLD LEG RECIRCULATION.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 7, 8 & 9 Page 37 of 42 Event
Description:
PZR Steam Space LOCA, Running Charging Pump Trips on SI, PVA-9312 A & B fails to close on Phase A Time Position Applicants Actions or Behavior
- c. Shift the CCW Train to fast speed in the Active Loop. REFER TO EOP-2.0 SOP-118, COMPONENT COOLING WATER.
- d. Consult with TSC personnel to determine if equipment required for Cold Leg Recirculation is available.
Check the AB for evidence of ECCS leakage: EOP-2.0
- a. Verify AB radiation levels are normal on:
- RM-A3, MAIN PLANT VENT EXH ATMOS MONITOR:
PARTICULATE, IODINE, GAS.
- RM-A13, PLANT VENT HI RANGE.
- RM-A11, AB VENT GAS ATMOS MONITOR.
- Local area monitors.
- b. Verify annunciator XCP-631 6-1 is NOT lit (AB SMP LVL HI).
- c. Verify annunciators XCP-606 3-4 and XCP-607 3-4 are NOT lit (LD TRBL AB SMP/FLDRN LVL HI).
Obtain necessary Chemistry samples: EOP-2.0
- a. Ensure all RCS sample valves are in AUTO:
- b. Notify Chemistry to sample the following:
- RCS.
- All SGs for isotopic activity.
Shut down and stabilize the Secondary Plant. REFER TO EOP-2.0 BOP AOP-214.1, TURBINE TRIP.
Check if RCS cooldown and depressurization is required: EOP-2.0 CRS a. RCS pressure is GREATER THAN 325 psig.
- b. GO TO EOP-2.1, POST-LOCA COOLDOWN AND DEPRESSURIZATION, Step 1.
EVALUATOR NOTE:
The scenario may be terminated after the crew transitions to EOP-2.1 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 7, 8 & 9 Page 38 of 42 Event
Description:
PZR Steam Space LOCA, Running Charging Pump Trips on SI, PVA-9312 A & B fails to close on Phase A Time Position Applicants Actions or Behavior EVALATORS NOTE: This attachment is to verify equipment status after Safety Injection has been initiated and is run concurrently with the main body of EOP-1.0.
Ensure EFW Pumps are running: EOP-1.0 Attachment 3
Ensure the following EFW valves are open: EOP-1.0 Attachment 3 BOP FCV-3531(3541)(3551), MD EFP TO SG A(B)(C).
FCV-3536(3546)(3556), TD EFP TO SG A(B)(C).
MVG-2802A(B), MS LOOP B(C) TO TD EFP.
BOP Verify total EFW flow is GREATER THAN 450 gpm. EOP-1.0 Attachment 3 Ensure FW Isolation: EOP-1.0 Attachment 3
- a. Ensure the following are closed:
FW Flow Control, FCV-478(488)(498).
BOP FW Isolation, PVG-1611A(B)(C).
FW Flow Control Bypass, FCV-3321(3331)(3341).
SG Blowdown, PVG-503A(B)(C).
SG Sample, SVX-9398A(B)(C).
- b. Ensure all Main FW Pumps are tripped.
EVALUATOR NOTE: The failure of the Back-up Charging Pump to Auto-Start may have been addressed earlier.
It is a Critical Task to start a Charging Pump prior to NR RVLIS <34% or CETs > 725°F.
BOOTH OPERATOR:
The following triggers will allow operation of the C Charging Pump on the A Header .
Trigger 15 - Racks Up Charging Pump C on the A Header.
Trigger 16 - Racks Down Charging Pump A.
Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 7, 8 & 9 Page 39 of 42 Event
Description:
PZR Steam Space LOCA, Running Charging Pump Trips on SI, PVA-9312 A & B fails to close on Phase A Time Position Applicants Actions or Behavior Ensure SI Pumps are running: EOP-1.0 CRITICAL Attachment 3 BOP Two Charging Pumps are running.
TASK Both RHR Pumps are running.
BOP Ensure two RBCU Fans are running in slow speed (one per train). EOP-1.0 Attachment 3 Verify Service Water to the RBCUs: EOP-1.0 Attachment 3
- a. Ensure two Service Water Pumps are running.
- b. Verify both Service Water Booster Pumps A(B) are running.
- c. Verify GREATER THAN 2000 gpm flow for each train on:
FI-4466, SWBP A DISCH FLOW GPM.
FI-4496, SWBP B DISCH FLOW GPM.
BOP Verify two CCW Pumps are running. EOP-1.0 Attachment 3 BOP Ensure two Chilled Water Pumps and Chillers are running. EOP-1.0 Attachment 3 BOP Verify both trains of Control Room Ventilation are running in EOP-1.0 Emergency Mode. Attachment 3 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 7, 8 & 9 Page 40 of 42 Event
Description:
PZR Steam Space LOCA, Running Charging Pump Trips on SI, PVA-9312 A & B fails to close on Phase A Time Position Applicants Actions or Behavior BOP Check if Main Steamlines should be isolated: EOP-1.0 Attachment 3
- a. Check if any of the following conditions are met:
RB pressure GREATER THAN 6.35 psig.
OR Steamline pressure LESS THAN 675 psig.
OR Steamline flow GREATER THAN 1.6 MPPH AND Tavg LESS THAN 552°F.
- b. Ensure all the following are closed:
MS Isolation Valves, PVM-2801A(B)(C).
MS Isolation Bypass Valves, PVM-2869A(B)(C).
BOP Ensure Excess Letdown Isolation Valves are closed: EOP-1.0 Attachment 3 PVT-8153, XS LTDN ISOL.
PVT-8154, XS LTDN ISOL.
EVALUATOR NOTE:
The Safety Injection Phase A Isol panel will indicate the 9312A and B are open.
It is a Critical Task for an operator to close at least 1 of the valves prior to completing .
BOP Verify ESF monitor lights indicate Phase A and Containment EOP-1.0 CRITICAL Ventilation Isolation on XCP-6103, 6104, and 6106. REFER TO Attachment 3 ATTACHMENT 4, CONTAINMENT ISOLATION VALVE MCB STATUS LIGHT LOCATIONS, as needed.
TASK Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 7, 8 & 9 Page 41 of 42 Event
Description:
PZR Steam Space LOCA, Running Charging Pump Trips on SI, PVA-9312 A & B fails to close on Phase A Time Position Applicants Actions or Behavior Excerpt from Attachment 4 showing relative positions of the affected windows. EOP-1.0 Attachment 4 BOP Verify proper SI alignment: EOP-1.0
- a. Verify SI valve alignment by verifying SAFETY Attachment 3 INJECTION/PHASE A ISOL monitor lights are bright on XCP-6104.
BOP Verify proper SI alignment: EOP-1.0 Attachment 3 ALTERNATIVE ACTION
- a. Ensure proper SI valve alignment:
- 1) Open MVG-8801A(B), HI HEAD TO COLD LEG INJ.
- 2) Close MVG-8107 and MVG-8108, CHG LINE ISOL.
- 3) Open LCV-115B(D), RWST TO CHG PP SUCT.
- 4) Close LCV-115C(E), VCT OUTLET ISOL.
BOP b. Verify all SAFETY INJECTION monitor lights are dim on XCP- EOP-1.0 6106. Attachment 3 Appendix D NUREG 1021 Revision 9
2013 NRC Scenario 5 Operator Actions Form ES-D-2 Op Test No.: NRC ILO 11-01 Scenario # 5 Event # 7, 8 & 9 Page 42 of 42 Event
Description:
PZR Steam Space LOCA, Running Charging Pump Trips on SI, PVA-9312 A & B fails to close on Phase A Time Position Applicants Actions or Behavior BOP c. Verify SI flow on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM EOP-1.0 Attachment 3 BOP d. Check if RCS pressure is LESS THAN 325 psig. EOP-1.0 Attachment 3 BOP e. Verify RHR flow on: EOP-1.0 Attachment 3 FI-605A, RHR DISCHARGE PUMP A FLOW GPM.
AND FI-605B, RHR DISCHARGE PUMP B FLOW GPM.
BOP Reports completion of EOP-1.0 Attachment 3 to the CRS EVALUATOR NOTE:
END OF EOP-1.0 ATTACHMENT 3 Appendix D NUREG 1021 Revision 9