ML052980323
| ML052980323 | |
| Person / Time | |
|---|---|
| Site: | Davis Besse  |
| Issue date: | 07/18/2005 |
| From: | Beilby M NRC/RGN-III/DRS/OLB |
| To: | FirstEnergy Nuclear Operating Co |
| References | |
| 50-346/05-301 | |
| Download: ML052980323 (48) | |
Text
Appendix D Scenario Outline Form ES-D-1 Facility:
Davis-Besse Scenario No.:
1 Op Test No.:
NRC 2005 Examiners:
Operators:
Initial Conditions:
80% power, MOL AFPT #1 tagged OOS.
Containment Air cooler (CAC) #1 tagged OOS CAC-3 is aligned for Train 1 Turnover:
Hold at 80% power while the Reactor Engineer reviews the calorimetric calculation completed at the end of the last shift.
Event No.
Malf.
No.
Event Type*
Event Description 1
N/A TS-SRO AO reports oil leak on Train 1 Containment Spray Pump.
2 RCP-07 C-RO, SRO RCP 1st Stage Seal failure on RCP 1-1.
R-RO Power reduction prior to stopping RCP 1-1.
N-SRO 3
TS-SRO 4
RCS-10 I-RO, BOP, SRO RCS Hot Leg RTD slowly drifts HI.
5 RCP-01 M-ALL RCP 1-2 Breaker trips. Reactor Trip required.
6 RPS-01 C-RO AUTO and MANUAL Reactor trip fails.
7 PZR-01 M-ALL PZR Safety Valve fails OPEN, initiating SFAS.
HPIP 1 trips.
8 HPI-02, 03 C-RO HPIP 2 fails to automatically start.
(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
Scenario Event Description NRC Scenario 1 DAVIS-BESSE 2005 NRC EXAM SIMULATOR SCENARIO 1 GENERAL DESCRIPTION The crew will take the watch with power holding at 80% power while the Reactor Engineer reviews the calorimetric calculation completed at the end of the last shift.
On cue from the Lead Evaluator, an AO will call the control room to report an oil leak on Containment Spray (CS) Pump #1. The SRO should request assistance from maintenance and/or enter the applicable TS. If necessary, a maintenance supervisor will report that the pump must be tagged OOS in order to make the repairs.
After the SRO has declared the TS for the CS Pump, the Lead Evaluator can cue the RCP 1-1 seal failure. The crew should respond to alarm 6-3-A in accordance with DB-OP-02006, REACTOR COOLANT PUMP ALARM PANEL 6 ANNUNCIATORS, and then enter DB-OP-02515, REACTOR COOLANT PUMP AND MOTOR ABNORMAL OPERATION.
DB-OP-02515 will require the crew to reduce power to 72% in accordance with DB-OP-02504, RAPID SHUTDOWN, and stop the affected RCP. The SRO should enter the proper TS after the RCP is stopped.
On cue from the Lead Evaluator, the RCS Thot selected on HIS3A and for Tave or UNIT will begin to drift HI. The crew should respond to alarm 4-2-B or indications in accordance with DB-OP-02004, REACTOR COOLANT ALARM PANEL 4 ANNUNCIATORS. The affected controls should be shifted to an alternate channel and the channel should be removed from service. The channel does not have to be removed from service to proceed with the scenario.
The Lead Evaluator can cue RCP 1-2 breaker trip when evaluation on the Thot failure is complete. The crew should recognize that an AUTO reactor trip should have occurred and attempt to initiate a MANUAL reactor trip. This will fail and the RO should initiate a reactor trip by momentarily de-energizing Busses E2 and F2. Coincident with the reactor trip a PZR Safety Valve will fail sufficiently open to cause an SFAS actuation. HPIP #1 will trip and HPIP #2 will fail to automatically start. The crew should enter DB-OP-02000 - RPS, SFAS, SFRCS TRIP, OR S/G TUBE RUPTURE, and, among other actions, perform the following high level activities:
verify the reactor is tripped, start HPIP #2, complete the actions for lack of adequate subcooling margin.
The Lead Evaluator can terminate the scenario when all high level activities have been completed and the evaluators agree the crew can be properly evaluated.
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
1 Event #
1 Page 3
of 16 Event
Description:
AO Reports Oil Leak On Train 1 Containment Spray Pump Time Position Applicants Actions or Behavior Booth Operator Instructions:
Call the control room to report an oil leak on Containment Spray Pump #1 due to a broken sight glass, and there is no oil level indicated for the pump.
SRO Refers to Tech Spec LCO 3.6.2.1.
RO/BOP Manually energize CS pump 1 blue light.
SRO May Call Field Supervisor.
SRO May Call Work Week Manager.
SRO May refer to Risk Matrix (Yellow 5.2).
At Lead Evaluators discretion, proceed to Event 2
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
1 Event #
2 & 3 Page 4
of 16 Event
Description:
RCP 1st Stage Seal Failure on RCP 1-1; Power Reduction Prior to Stopping RCP 1-1 Time Position Applicants Actions or Behavior Booth Operator Instructions:
When directed, insert command for Event 2 Indications Available:
(6-3-A) 1-1 SEAL RET FLOW HI.
High controlled bleedoff flow of RCP 1-1 seal water.
Computer alarm, CAVITY SEAL PRESSURE HIGH Crew Respond to Annunciator Alarm (6-3-A) 1-1 SEAL RET FLOW HI.
RO Observe High controlled bleedoff flow of RCP 1-1.
SRO Enter DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation.
CREW Determine IF any of the following RCP conditions exist:
Seal Return Temp 200°F Total seal leakage for the affected RCP 2.0 gpm.
Seal stage pressure drop greater than 1440 PSIG.
CREW Determines total seal leakage is > 2.0 gpm.
CREW IF a Reactor Shutdown to take the Unit off line is NOT desired, THEN, perform those steps necessary to reduce reactor power to the desired power level, AND REFER TO Attachment 1, Plant Stabilization at a Lower Power Level.
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
1 Event #
2 & 3 Page 5
of 16 Event
Description:
RCP 1st Stage Seal Failure on RCP 1-1; Power Reduction Prior to Stopping RCP 1-1 Time Position Applicants Actions or Behavior IF four RCPs are in operation, THEN perform the following:
RO Reduce reactor power to 72 percent.
SRO Notify the System Control Center (SCC) Load dispatcher of the unit load reduction.
As determined by the Unit Supervisor, reduce unit load by any of the following methods:
At the LOAD CONTROL panel:
- 1.
Set the RATE OF CHANGE to a rate specified by the Unit Supervisor.
- 2.
Set the MIN LIMIT - MW to 180 Mwe.
- 3.
Depress the DEC pushbutton to lower the unit load to the target determined by the Unit Supervisor.
RO IF the APSRs are available, THEN attempt to maintain Axial Power Imbalance between 0 and negative 10 percent.
RO When power is below 70%, reset minimum demand BOP Prior to tripping RCP, ensure load ratio in auto RO When power is at approximately 70%, stop the affected RCP.
BOP Verify proper Feedwater flow ratios of 2.4 to 1.
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
1 Event #
2 & 3 Page 6
of 16 Event
Description:
RCP 1st Stage Seal Failure on RCP 1-1; Power Reduction Prior to Stopping RCP 1-1 Time Position Applicants Actions or Behavior RO/BOP Verify Tave control transferred to the RC loop with two RCPs.
SRO Verify RCS flow is greater than the flow required by T.S. 3.2.5.
Enter TS 3.2.5 if low is less than required RO During power reduction, may perform NI to heat balance check SRO Within four hours verify the Ø/Ø/Flow AND High Flux Trips setpoints have been reduced in accordance with TS 3.4.1.1.
SRO Request Chemistry to perform the following:
Monitor Condensate Polisher operation.
Sample the RCS for an isotopic analysis of Iodine.
At Lead Evaluators discretion, proceed to Event 4
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
1 Event #
4 Page 7
of 16 Event
Description:
RCS Hot Leg RTD Slowly Drifts HI Time Position Applicants Actions or Behavior Booth Operator Instructions:
When directed, insert command for Event 4 Indications Available:
4-2-B, HOT LEG TEMP HIGH 14-4-D, ICS FW LIMITED BY RX POWER 14-4-E, ICS INPUT MISMATCH 14-6-D, ICS IN TRACK 4-2-E, PZR LVL LO Loop 2 Thot indication rising RO Check the alarm by observing Loop 1 and Loop 2 Hot Leg Tis.
RO Verify the ICS is reducing Rx power to lower Tave to 582°F RO Compare Hot Leg Temperature Indicators TI RC3A1 and T1 RC3B1 on RC Panel C5718.
RO IF the selected Hot Leg Temperature Transmitter failed, THEN verify SASS has transferred to unfaulted instrument.
Crew Respond to Annunciator Alarm (4-2-E) PZR LVL LO RO Observes Low Pressurizer level as indicated on LRS RC14 on Control Room Panel C5706.
RO Check Pressurizer level low on LRS RC14 on Control Room Panel C5705.
RO IF Pressurizer Level is due to a Tave transient, THEN perform the following:
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
1 Event #
4 Page 8
of 16 Event
Description:
RCS Hot Leg RTD Slowly Drifts HI Time Position Applicants Actions or Behavior
- a. Reduce MU-32 Setpoint to ~ 180.
- b. WHEN Tave is restored to ~ 582°F, AND Pressurizer Level is stable, THEN restore MU-32 to 220 inches as directed by the CTRM SRO.
CREW Determine which instrument pair has caused the alarm. (Thot)
BOP Place SP6A, FEEDWATER MAIN VALVE, HVA Station in HAND.
RO Place Diamond Control in MANUAL BOP Place BOTH FEEDWATER DEMAND H\\A Stations in HAND.
BOP Verify FW601, S/G 2 MAIN FEEDWATER STOP VALVE, is open.
BOP Lower Feedwater flow to match Plant power using SP6A and SP7A AND LOOP 1 FEEDWATER DEMAND H\\A Station.
BOP Verify Main Feedwater Pump(s) OR the Motor Driven Feed Pump is in service.
RO/BOP Check for ICS module, component, or instrument failures.
At Lead Evaluators discretion, proceed to Event 5
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
All Event #
5, 6, 7, & 8 Page 9 of 16 Event
Description:
RCP 1-2 Breaker Trips; Reactor Trip Required; AUTO and MANUAL Reactor Trip Fails; PZR Safety Valve Fails OPEN, Initiating SFAS; HPIP 1 Trips; HPIP 2 Fails to Automatically Start Time Position Applicants Actions or Behavior Booth Operator Instructions:
When directed, insert command for Event 5 Indications Available:
5-3-H, RPS POWER - PUMPS TRIPPED 5-1-G, H, I, J, RPS CH 1, 2, 3, 4 TRIPPED ZL4265A and ZL 4265A red lights lit - Safety Valve Open indication RCP 1-2 TRIPPED indication CREW Determine that RCP 1-2 has tripped without a reactor trip RO Manually Trip the Reactor.
Reactor Trip Pushbutton has been depressed; AND Power is decreasing on the Intermediate Range Nuclear Instrumentation (NO).
IF the reactor is NOT shutdown, THEN perform the following actions until the reactor is shutdown.
Manually deenergize the CRDs in the order listed below:
CRITICAL TASK RO
- 1.
Momentarily deenergize 480-Volt Unit Substations E2 AND F2 simultaneously.
Maintain balanced primary to secondary heat transfer:
- 1.
IF MFW is less than Reactor power, THEN manually
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
All Event #
5, 6, 7, & 8 Page 10 of 16 Event
Description:
RCP 1-2 Breaker Trips; Reactor Trip Required; AUTO and MANUAL Reactor Trip Fails; PZR Safety Valve Fails OPEN, Initiating SFAS; HPIP 1 Trips; HPIP 2 Fails to Automatically Start Time Position Applicants Actions or Behavior control MFW flow to match Reactor power.
RO Manually trip the Turbine.
Turbine Trip Pushbutton has been depressed.
AND Turbine Stop Valves 1, 2, 3 AND 4 are closed.
OR Turbine Control Valves 1, 2, 3, AND 4 are closed.
SRO CHECK FOR SPECIFIC RULE OR SYMPTOM DIRECTION Implement any necessary Specific Rules.
ACTIONS FOR LOSS OF SUBCOOLING MARGIN Applies Specific Rule 2 MU\\HPI\\LPI FLOW INITIATION, THROTTLING, AND TERMINATION Applies Specific Rule 3 OTSG LEVEL CONTROL Specific Rule 4 SRO Implement any necessary Symptom Mitigation Sections
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
All Event #
5, 6, 7, & 8 Page 11 of 16 Event
Description:
RCP 1-2 Breaker Trips; Reactor Trip Required; AUTO and MANUAL Reactor Trip Fails; PZR Safety Valve Fails OPEN, Initiating SFAS; HPIP 1 Trips; HPIP 2 Fails to Automatically Start Time Position Applicants Actions or Behavior LACK OF ADEQUATE SUBCOOLING MARGIN Applies SRO Directs tripping remaining RCPs IAW specific Rule 2 when subcooling is lost.
CRITICAL TASK RO Trips all remaining RCPs SRO Directs starting MDFW pump to feed OTSG #1 BOP Unblock MDFW Valves and start MDFW Pump to feed OTSG 1 MU\\HPI Initiation RO Start the standby CCW Pump.
HPI Pump 1 (Tripped)
HPI Pump 2 RO Open HPI Injection Valves.
HP 2A HP 2B HP 2C HP 2D RO/SRO IF only one HPI train is available, THEN REFER TO 1, HPI Flow Balancing.
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
All Event #
5, 6, 7, & 8 Page 12 of 16 Event
Description:
RCP 1-2 Breaker Trips; Reactor Trip Required; AUTO and MANUAL Reactor Trip Fails; PZR Safety Valve Fails OPEN, Initiating SFAS; HPIP 1 Trips; HPIP 2 Fails to Automatically Start Time Position Applicants Actions or Behavior RO Stop Makeup flow through HPI Train 2 by closing MU 6422, MU CTMT ISOLATION.
RO Verify HPI Train 2 Injection Valves are fully open.
HP2A, HIGH PRESSURE INJECTION LINE 2-1 ISOLATION HP2B, HIGH PRESSURE INJECTION LINE 2-2 ISOLATION RO Determine which injection line has the lower flow and REFER TO Figure 3, HPI Balancing.
FYI HP3A FYI HP3B RO IF only the lower flow is NOT in the acceptable region, THEN throttle the higher flow line until:
The lower flow line is in the acceptable region OR The high flow line reaches the lower limit of the acceptable region REFER TO Figure 3, HPI Balancing.
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
All Event #
5, 6, 7, & 8 Page 13 of 16 Event
Description:
RCP 1-2 Breaker Trips; Reactor Trip Required; AUTO and MANUAL Reactor Trip Fails; PZR Safety Valve Fails OPEN, Initiating SFAS; HPIP 1 Trips; HPIP 2 Fails to Automatically Start Time Position Applicants Actions or Behavior RO IF MU 6422 was closed in Step 2.a above, THEN open MU 6422, MU CTMT ISOLATION.
SRO Routes to DB-OP-02000, section for LACK OF ADEQUATE SUBCOOLING MARGIN RO Trip all RCPs. (Already performed.)
RO Verify BOTH HPI Trains are in service as follows:
RO Verify BOTH CCW Trains are in service to supply essential cooling:
CCW Train 1 CCW Train 2 RO Verify BOTH HPI Pumps are running.
HPI Pump 1 - tripped HPI Pump 2 RO Verify HPI Injection Valves fully open.
HP 2A HP 2B HP 2C HP 2D RO Lineup Makeup System as follows:
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
All Event #
5, 6, 7, & 8 Page 14 of 16 Event
Description:
RCP 1-2 Breaker Trips; Reactor Trip Required; AUTO and MANUAL Reactor Trip Fails; PZR Safety Valve Fails OPEN, Initiating SFAS; HPIP 1 Trips; HPIP 2 Fails to Automatically Start Time Position Applicants Actions or Behavior Lock MU Pump Suctions in the BWST position.
MU 3971 MU 6405 RO Start the second MU Pump.
RO Start BOTH LPI Pumps LPI Pump 1 LPI Pump 2 RO Open MU 6420, MU 32 BYPASS.
RO Verify MU 6422, MU CTMT ISOLATION is open.
IF LPI Flow into the RCS does not exist, THEN perform the following:
- a.
Open BOTH piggyback valves DH 63 DH 64 RO
- b.
IF two MU Pumps are running, THEN perform the following:
Open MU 6421, CTMT ISOLATION FOR ALTERNATE MU INJECTION LINE
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
All Event #
5, 6, 7, & 8 Page 15 of 16 Event
Description:
RCP 1-2 Breaker Trips; Reactor Trip Required; AUTO and MANUAL Reactor Trip Fails; PZR Safety Valve Fails OPEN, Initiating SFAS; HPIP 1 Trips; HPIP 2 Fails to Automatically Start Time Position Applicants Actions or Behavior Open MU 6419, ALTERNATE MU INJECTION LINE.
CREW Verify proper SFAS response. (HPIP #1 Tripped)
BOP Verify proper SFRCS actuation for the trip parameters present using Table 1.
BOP Verify proper SG level control by AFW using Specific Rule 4.
Isolate Possible RCS Leaks as follows: (May not be a priority if crew realizes that a Pressurizer Safety Valve failure is the cause)
RO IF MU/HPI PORV Cooling is NOT in progress, THEN perform the following:
- a.
Verify RC 2A, PORV, control switch in AUTO.
- b.
Close RC 11, PORV BLOCK Valve.
RO Verify MU 2B, LETDOWN ISO is closed.
RO Verify RC 2, PZR SPRAY Valve is closed.
RO Close RC 10, PZR SPRAY BLOCK Valve.
RO Close Pressurizer Sample Isolations RC 239A RC 239B
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
All Event #
5, 6, 7, & 8 Page 16 of 16 Event
Description:
RCP 1-2 Breaker Trips; Reactor Trip Required; AUTO and MANUAL Reactor Trip Fails; PZR Safety Valve Fails OPEN, Initiating SFAS; HPIP 1 Trips; HPIP 2 Fails to Automatically Start Time Position Applicants Actions or Behavior RO Verify Loop 1 High Point Vents are closed.
RC 4608A RC 4608B RO Verify Loop 2 High Point Vents are closed.
RC 4610A RC 4610B RO Verify CFT Isolation Valves are open.
CF 1A CF 1B SRO If adequate subcooling margin exists, THEN GO TO Step 5.18.
ADEQUATE SUBCOOLING MARGIN (20 degrees F) HAS BEEN ESTABLISHED CREW Throttle MU and HPI as necessary to maintain adequate subcooling margin. REFER TO Specific Rule 5, PTS Requirements.
Scenario may be terminated when crew reaches Step 5.18.
Appendix D Scenario Outline Form ES-D-1 Facility:
DAVIS-BESSE Scenario No.:
2 Op Test No.:
NRC 2005 Examiners:
Operators:
Initial Conditions:
100% power, EOL AFPT #1 tagged OOS Containment Air Cooler #1 tagged OOS CAC #3 is aligned for Train 1 Turnover:
Maintain 100% power.
Event No.
Malf.
No.
Event Type*
Event Description 1
F3B2B TS-SRO SFRCS Power Supply Failure Channel 2.
2 FAK4I R-RO, SRO Condensate Pump Trip.
3 L1T2N I-ALL Steam Pressure Transmitter Failure.
CCW-01 C-RO, SRO 4
CCW-02 TS-SRO CCW Pump trip/failure of AUTO start on standby pump.
5 AC-05 M-ALL Loss of one 13.8KV Bus.
6 MS-06 C-ALL One Atmospheric Vent Valve fails OPEN.
7 SFRCS-02 C-BOP Failure of AUTO SFRCS actuation.
(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
Scenario Event Description NRC Scenario 2 DAVIS-BESSE 2005 NRC EXAM SIMULATOR SCENARIO 2 GENERAL DESCRIPTION The crew will take the watch with directions to maintain 100% power.
On cue from the Lead Evaluator, an SFRCS power supply failure will occur. The crew will respond to multiple annunciators, check the SFRCS cabinets, and determine that channel 2 28 VDC power supply has failed. The SRO will refer to DB-OP-06406 and Technical Specifications to determine required action.
The Lead Evaluator can cue the Condensate Pump failure any time after the declaration of the SFRCS TS. The crew will respond to annunciators and the BOP will manually throttle CD-420 and 421 to maintain Deaerator level in accordance with DB-OP-02013.
When the plant is stable following the Condensate Pump trip, a Steam header Pressure transmitter will fail, requiring the crew to place the turbine in MANUAL and raise SG pressure, and to place the SG/RX Demand in HAND to stabilize the plant. The crew will refer to DB-OP-06407 for the NNI failure, and DB-OP-06401 to restore ICS to full automatic operation.
Anytime after the plant is stabilized, the Lead Evaluator can cue the trip of a running Component Cooling Water (CCW) Pump. The crew should respond to alarm 11-4-B in accordance with DB-OP-02011, HEAT SINK ALARM PANEL 11 ANNUNCIATORS, and then implement DB-OP-02523, COMPONENT COOLING WATER SYSTEM MALFUNCTIONS. The RO should manually start the standby pump before RCP/reactor trip criteria is met.
After the standby CCW Pump has been started and the non-essential CCW Header isolation valves are closed on the failed pump, the Lead Evaluator can cue the loss of one 13.8KV Bus.
This results in a reactor trip and entry into DB-OP-02000. One Atmospheric Vent Valve will fail partially open and SFRCS will fail to actuate in AUTO. Among other actions, the crew will perform the following high level activities: actuate SFRCS and perform overcooling actions.
The Lead Evaluator can terminate the scenario when all high level activities have been completed and the evaluators agree the crew can be properly evaluated.
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
2 Event #
1 Page 3
of 14 Event
Description:
SFRCS Channel 2 Power Supply Failure Time Position Applicants Actions or Behavior Booth Operator Instructions:
When directed, insert command for Event 1 Indications Available:
Multiple SFRCS alarms.
CREW Responds to alarms.
CREW Determines cause is loss of 28 VDC channel 2 power supply.
SRO Refers to DB-OP-06406.
SRO Determines T.S. 3.3.2.2 applies.
When Tech Specs have been addressed or at Lead Evaluators discretion, proceed to Event 2
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
2 Event #
2 Page 4
of 14 Event
Description:
Condensate Pump Trip Time Position Applicants Actions or Behavior Booth Operator Instructions:
When directed, insert command for Event 2 Indications Available:
13-2-B CNDS PMP DISCH HDR PRESS Low Condensate Pump discharge header pressure as indicated at PI 569, CONDENSATE PUMP DISCHARGE.
13-4-C DEAR STRG TK 1 LVL 13-4-D DEAR STRG TK 2 LVL Lowering Deaerator Storage Tank 1 and 2 water levels Crew Refer to Annunciator Response DB-OP-02013 BOP Verify the proper number of condensate pumps are on for the unit load. REFER TO DB-OP-06221, Condensate System.
Determines one (1) pump tripped.
BOP Observes condensate header flow rate as indicated at FI 578, CONDENSATE PUMPS DISCHARGE.
SRO Direct power reduction to within capacity of 2 Condensate Pumps SRO Notify the System Control Center (SCC) Load dispatcher of the unit load reduction.
As determined by the Unit Supervisor, reduce unit load by any of the following methods:
At the LOAD CONTROL panel:
- 1.
Set the RATE OF CHANGE to a rate specified by the Unit Supervisor.
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
2 Event #
2 Page 5
of 14 Event
Description:
Condensate Pump Trip Time Position Applicants Actions or Behavior RO
- 2.
Set the MIN LIMIT - MW to 180 Mwe.
- 3.
Depress the DEC pushbutton to lower the unit load to the target determined by the Unit Supervisor.
RO May perform NI and Heat Balance checks BOP IF NECESSARY, control CD 421 and 420, DEAER STORAGE TANK 1 and 2 CONTROL VALVES, to maintain Deaerator levels.
At Lead Evaluators discretion, proceed to Event 3
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
2 Event #
3 Page 6
of 14 Event
Description:
Steam Pressure Transmitter Failure Time Position Applicants Actions or Behavior Booth Operator Instructions:
When directed, insert command to initiate Event 3 Indications Available:
14-4-E, ICS INPUT MISMATCH BOP Transfer turbine to MANUAL.
RO Depress and release HAND on HIC ICS13, SG/RX DEMAND.
BOP Lower on Turbine Control to maintain Main Steam Header Pressure Check Main Steam Header Pressure:
PI SP16A, Turbine Header Pressure 2 - Dropping (Inst.
Failure).
PI SP16B, Turbine Header Pressure 1.
BOP Determine the cause of the abnormal Main Steam Line header pressure. (Instrument Fail)
When plant is stable; BOP Reset ICS Mismatch annunciator BOP Select PI SP16B, Turbine Header Pressure 1 BPO Verify FIC ICS32B(A), FEEDWATER DEMAND is in AUTO.
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
2 Event #
3 Page 7
of 14 Event
Description:
Steam Pressure Transmitter Failure Time Position Applicants Actions or Behavior RO Verify HC ICS20, REACTOR DEMAND is in AUTO.
RO Verify the error between the POS and MV positions on HIC ICS13, SG/RX DEMAND is as small as possible for the current plant conditions.
RO Depress and release AUTO on HIC ICS13, SG/RX DEMAND.
BOP Verify the Turbine is synchronized to the grid.
BOP Verify PIC ICS 10, HDR PRESSURE CONTROL Setpoint is 45%.
BOP Adjust Turbine load using increase/decrease pushbuttons on HIC 2540, EHC PANEL 1, until PRS SP16, TURBINE THROTTLE PRESS indicates 870 psig.
BOP Depress and release LOAD CONTROL SELECTOR ICS IN.
BOP Check the ICS IN AND ICS READY lights are lit.
CREW IF ICS is returned to its normal alignment, THEN verify annunciator (14-6-D) ICS IN TRACK is EXTINGUISHED.
CREW May be operating in Rod Insertion Limit Zone. (2 Hours before power reduction is required)
When the plant is stable with ICS stations returned to AUTO and at Lead Evaluators discretion, proceed to Event 4
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
2 Event #
4 Page 8
of 14 Event
Description:
CCW Pump Trip/Failure of AUTO Start on Standby Pump Time Position Applicants Actions or Behavior Booth Operator Instructions:
When directed, insert command to initiate Event 4 Indications Available:
6-5-B, SEAL CCW FLOW LOW 2-3-A, LETDOWN TEMP HIGH Letdown Isolation RO Verify the standby CCW Pump starts. (FAILS)
RO IF the standby CCW Pump fails to start, THEN perform the following:
RO IF high temperature computer alarms are received on the RCPs, THEN GO TO Step 4.6.11, OTHERWISE monitor RCP Temperatures.
RO Monitor RCS Letdown Temperatures.
RO Reduce Seal Injection flow IAW DB-OP-02523 (ARP)
CRITICAL TASK RO Start the standby CCW pump.
(Prior to reaching RCP Trip Criteria)
CREW Send an Operator to investigate relay targets on any tripped CCW Pump breakers.
RO Verify the Non-Essential CCW Isolation valves open for the running CCW Pump, AND close for the non-running CCW Pump.
LOOP 1 (CLOSED)
CC 5095
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
2 Event #
4 Page 9
of 14 Event
Description:
CCW Pump Trip/Failure of AUTO Start on Standby Pump Time Position Applicants Actions or Behavior CC 5097 CC 2645 LOOP 2 CC 5096 CC 5098 CC 2649 RO Return the Letdown System to service, REFER TO DB-OP-06006, Makeup and Purification.
(Letdown is isolated.)
RO Open MU104, PURIFICATION DEMINERALIZER BYPASS.
RO Isolate Purification Demineralizers 1, 2, and 3 by closing the following valves:
MU10A, MIXED BED 1 LETDOWN INLET, using HISMU10A.
MU10B, mixed bed 2 LETDOWN INLET, using HISMU10B MU1903, PURIFICATION DEMIN 3 LETDOWN FLOW INLET, using HISMU1903.
RO Manually override the high temperature signal by holding the following valves in the OPEN position, until the trip clears:
RO MU2B, LETDOWN COOLERS INLET ISOLATION, using HISMU2B
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
2 Event #
4 Page 10 of 14 Event
Description:
CCW Pump Trip/Failure of AUTO Start on Standby Pump Time Position Applicants Actions or Behavior RO MU1A, RC LETDOWN COOLER 1 INLET ISOLATION, using HISMU1B.
RO MU1B, RC LETDOWN COOLER 2 INLET ISOLATION, using HISMU1B RO Restore the Makeup system to the normal valve lineup by opening the following valves as directed by the Shift Manager:
RO MU10A, MIXED BED 1 LETDOWN INLET, using HISMU10A.
RO MU10B, MIXED BED 2 LETDOWN INLET, using HISMU10B.
RO MU1903, PURIFICATIONS DEMIN 3 LETDOWN FLOW INLET, using HISMU1903.
RO Close MU104, PURIFICATION DEMINERALIZER BYPASS.
SRO Refer to Technical Specifications TS 3.7.3.1, CCW Train inoperable TS 3.4.4, PZR level high inoperable (>228 inches)
When the standby CCW Pump is running and Letdown has been restored, proceed to Event 5
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
2 Event #
5, 6, & 7 Page 11 of 14 Event
Description:
Loss of One 13.8KV Bus; One Atmospheric Vent Valve Fails OPEN; Failure of AUTO SFRCS Actuation Time Position Applicants Actions or Behavior Booth Operator Instructions:
When directed, insert command to initiate Event 5 Indications Available:
Reactor Trip Alarms related to Loss of 13.8 KV Bus A RO Manually trip the Reactor.
Reactor Trip Pushbutton has been depressed.
RO Manually trip the Turbine.
Turbine Trip Pushbutton has been depressed AND Turbine Stop Valves 1, 2, 3 AND 4 are closed.
OR Turbine Control Valves 1, 2, 3 AND 4 are closed.
Check for Specific Rule or Symptom Direction SRO Implement any necessary Specific Rules (NONE Apply At This Time)
RO Perform Emergency Shutdown of EDG 1 due to loss of cooling (IF Running)
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
2 Event #
5, 6, & 7 Page 12 of 14 Event
Description:
Loss of One 13.8KV Bus; One Atmospheric Vent Valve Fails OPEN; Failure of AUTO SFRCS Actuation Time Position Applicants Actions or Behavior SRO Implement any necessary Symptom Mitigation Sections SRO Determines Section 7 applies (Overcooling).
CREW Maintain RCS Inventory as follows:
RO Set the PZR level controller to 100 inches.
RO Transfer MU Pump suctions to the BWST position AND press OFF for each switch.
MU 3971 MU 6405 RO Start MU Pumps (#1 may only run for 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> due to loss of CCW)
RO Isolate Letdown RO Ensure pressurizer heaters off CRITICAL TASK BOP Check for SFRCS Actuation.
MUST Manually actuate SFRCS due to failure of auto actuation SRO Determines a failed AVV causing overcooling.
BOP Initiate AFW flow AND isolation of BOTH SGs by depressing SFRCS MANUAL ACTUATION switches HIS 6403 AND HIS 6404.
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
2 Event #
5, 6, & 7 Page 13 of 14 Event
Description:
Loss of One 13.8KV Bus; One Atmospheric Vent Valve Fails OPEN; Failure of AUTO SFRCS Actuation Time Position Applicants Actions or Behavior BOP Verify proper SFRCS actuation for the trip parameters present.
CREW IF an SFRCS Low MS Line Pressure Trip is present OR occurs while performing Steps 7.24 through 7.28, THEN verify proper SFRCS actuation AND GO TO Step 7.29.
SRO IF it is apparent which SG is causing the overcooling, THEN GO TO Step 7.28.
CREW Determines OTSG-1 is causing the overcooling condition BOP Take manual control of BOTH AFW level control valves and close BOTH valves.
BOP Manually isolate AFW to the steam leak SG by performing one of the following:
BOP IF SG 1 has the steam leak, THEN close AF 608.
BOP Verify proper operation of AFW trains feeding the non-isolated SG.
BOP Maintain proper SG level in the non-isolated SG with AFW using Specific Rule 4.
CREW Check for continued Overcooling with one SG isolated.
BOP WHEN the steam leak side SG boils dry (terminating the overcooling), THEN control the AVV on the non-isolated SG to maintain RCS temperature constant or slightly decreasing.
BOP AVV H/A Station Operation for the Non-Isolated SG
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
2 Event #
5, 6, & 7 Page 14 of 14 Event
Description:
Loss of One 13.8KV Bus; One Atmospheric Vent Valve Fails OPEN; Failure of AUTO SFRCS Actuation Time Position Applicants Actions or Behavior BOP Place the AVV H/A Station in HAND.
BOP Reduce the demand to zero.
BOP Press the AVV BLOCK pushbutton (HIS-ICS-11C).
BOP Press AUTO on HIS-ICS-11B or HIS-ICS-11A.
BOP Control SG pressure as necessary from the H/A Station.
SRO Route to Specific Rule 3 when criteria is met.
BOP Place Main Steam RIM 600/609 is GROSS RO When SCM is adequate, throttle MU flow as necessary to observe the following limits:
IF MU is piggybacked from LPI, limit MU flow to 275 gpm (motor limitation).
RO MU/HPI shall be throttled to prevent exceeding the maximum P/T for cooldown limit line on Figure 1, curve 1.
Terminate scenario when RCS temperature is stable using AFW and OTSG #2 AVV
Appendix D Scenario Outline Form ES-D-1 Facility:
Davis-Besse Scenario No.:
3 Op Test No.:
NRC 2005 Examiners:
Operators:
Initial Conditions:
70% power, BOL AFPT #1 tagged OOS Containment Air Cooler (CAC) #1 tagged OOS CAC #3 is aligned for Train 1 Turnover:
MFPT #1 has a leak on the inboard bearing supply line. The previous shift initiated a power reduction to take MFPT #1 out of service for repairs. Continue the power reduction at 5 MW/minute and remove MFPT #1 from service.
Event No.
Malf.
No.
Event Type*
Event Description N-SRO Controlled power reduction 1
R-RO 2
MFW-11 C-BOP, SRO Increasing vibration on MFPT #1 requiring manual trip 3
ICS-02 C-RO, SRO ICS AUTO Runback fails I-RO, SRO RCS Pressure instrument selected for NNI input fails LO 4
RCS-13 TS-SRO 5
TS-SRO 120VAC Inverter alarm actuates in the control room 6
SG-01 C-BOP, SRO; R-RO OTSG Tube Leak 7
MFW-01 M-ALL MFPT #2 trips 8
SG-01 C-ALL OTSG tube leak rises to rupture following the reactor trip 9
PZR-02 C-RO PZR Spray Valve fails CLOSED during depressurization (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
Scenario Event Description NRC Scenario 3 DAVIS-BESSE 2005 NRC EXAM SIMULATOR SCENARIO 3 GENERAL DESCRIPTION The crew will take the watch with power holding between 70%. The previous shift initiated a power reduction to take MFPT #1 out of service for repairs. Directions will be to continue the power reduction and remove MFPT #1 from service for repair of an oil leak.
Any time after the power reduction is initiated the Lead Evaluator can cue initiation of rising vibration levels on MFPT #1. The crew should respond to alarm 10-3-A in accordance with DB-OP-02010, FEEDWATER ALARM PANEL 10 ANNUNCIATORS. The Auxiliary Operator (AO) will report a vibration level exceeding the threshold for tripping the pump. The crew should trip MFPT #1, recognize that an AUTO runback did not initiate and then manually runback power to within the capacity of one MFWP.
The Lead Evaluator can cue initiation of failure of the RCS pressure channel selected for NNI input after the plant is stabilized. The crew should respond to alarm 4-4-C in accordance with DB-OP-02004, REACTOR COOLANT ALARM PANEL 4 ANNUNCIATORS. The operator should return the heaters to the correct alignment for the conditions, the channel should be removed from service and the SRO should enter the correct TS. The channel does not have to be removed from service to proceed with the scenario.
Any time after the RCS pressure channel actions are complete, the Lead Evaluator can cue actuation of alarm 1-6-A, INV YV1-YV-3 TRBL. The crew should respond in accordance with DB-OP-02001, ELECTRICAL DISTRIBUTION ALARM PANEL 1 ANNUNCIATORS, and dispatch an AO to investigate. The AO will report that one of the inverters has shifted to the alternate source. The SRO should request maintenance assistance and/or enter the correct TS.
If necessary, the maintenance supervisor will report an electrical problem that indicates the normal supply cannot be restored until corrective actions are completed.
Any time after the SRO has entered the TS for the 120VAC problem, the Lead Evaluator can cue initiation of the OTSG tube leak. The crew should respond to alarm 9-4-A in accordance with DB-OP-02009, PLANT SERVICES ALARM PANEL 9 ANNUNCIATORS, which will direct them to DB-OP-02531, STEAM GENERATOR TUBE LEAK, for actions. The simulator operator will maintain leak rate greater than the TS limit but less than DB-OP-02000 entry. After the crew has recognized the tube leak and/or the SRO is evaluating the tube leak TS, the Lead Evaluator can cue the MFPT #2 trip. This results in a reactor trip and entry into DB-OP-02000. After the crew has entered DB-OP-02000, the OTSG tube leak will ramp to a size below SFAS actuation.
Among other actions, the crew will perform the following high level activities: establish HPI piggyback operation, depressurize the RCS using pressurizer PORV when the spray valve fails closed.
The Lead Evaluator can terminate the scenario when all high level activities have been completed and the evaluators agree the crew can be properly evaluated.
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
3 Event #
1 Page 3
of 18 Event
Description:
Controlled Power Reduction Time Position Applicants Actions or Behavior SRO Direct Load Reduction at 5 MWE/minute RO Set ULD for 5 MWe/min RO Press DEC pushbutton CREW Monitor plant parameters On Lead Evaluators discretion, proceed to Event 2
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
3 Event #
2 Page 4
of 18 Event
Description:
Increasing Vibration on MFPT #1 Requiring Manual Trip Time Position Applicants Actions or Behavior Booth Operator Instructions:
When directed, insert command for Event 2 Indications Available:
10-3-A, MFP 1 or BFP 1 BEARING VIB HI Excessive vibration of MFP 1 Bearings Excessive vibration of MFPT 1 Bearings Excessive vibration of MFPT 1 Gear Reducer Bearings CREW Refer to Annunciator Response DB-OP-02010 BOP Send EO to locally monitor the MAIN FD PUMPS 1 AND 2 VIBRATION PANEL for Gear Reducer, Booster Pump, and Feed Pump vibration.
BOP Obtain vibration reading from ZJR 2538, MAIN TURBINE &
MFP TURBINES - BEARING VIBRATION & ECCENTRICITY, points 11 and 12 for MFPT 1.
SRO/BOP IF vibration amplitude increases and remains above the second setpoint AND Maintenance personnel are NOT immediately available to take vibration readings, THEN trip MFPT 1 using HS 797, TURBINE TRIP.
BOOTH INSTRUCTOR:
Report that Maintenance personnel are NOT available.
BOP TRIP MFPT #1 Indications Available:
8-4-A, MFPT 1 TRIP 4-3-E, PZR LEVEL HI 14-3-D, ICS MFP LOSS OR LOW DEAR RUNBACK 14-4-C, ICS RX PWR LIMITED BY FEEDWATER
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
3 Event #
2 Page 5
of 18 Event
Description:
Increasing Vibration on MFPT #1 Requiring Manual Trip Time Position Applicants Actions or Behavior IF an ICS Runback occurs THEN REFER to DB-OP-06401, Integrated Control System Operating Procedure. Runback should occur but does NOT.
RO Places SG/RX DEMAND H/A Station in HAND and initiates runback at 20% power per minute (See Event next page)
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
3 Event #
3 Page 6
of 18 Event
Description:
ICS AUTO Runback Fails Time Position Applicants Actions or Behavior Crew may refer to OP-06401 for runback.
RO/BOP IF the runback was caused by a feed pump trip, THEN perform the following:
RO IF ICS was NOT in TRACK, THEN verify ICS is or has runback at 20%/minute to 55% power. OTHERWISE place HIC ICS13, SG/RX DEMAND station in HAND AND perform the runback at 20%/minute to 55% power. (ULD DEMAND as read on DAAS=514 Mwe)
RO IF the pressurizer spray valve was operated, THEN verify RC2, PRESSURIZER SPRAY VALVE is in AUTO AND closed.
RO/BOP Perform a NIP/HBP comparison for the current power level.
SRO REFER to DB-OP-06902, Power Operations, for guidance to operate plant equipment for the current power level.
On Lead Evaluators discretion, proceed to Event 4
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
3 Event #
4 Page 7
of 18 Event
Description:
RCS Pressure Instrument Selected for NNI Input Fails LO Time Position Applicants Actions or Behavior Booth Operator Instructions:
When directed, insert command for Event 4 Indications Available:
5-1-G, RPS CH 1 TRIP 5-3-G, RPS RC LO PRESS TRIP SRO Refer to Technical Specifications 3.3.1.1, and take action as required.
CREW Refer to DB-OP-02513, Section 4.6.
RO Manually control Pressurizer Heaters as required to maintain normal RCS Pressure.
RO Manually control Pressurizer Spray RC 2 to maintain normal RCS pressure.
BOP Exchange RCS pressure input to NNI from RPS, REFER to DB-OP-06403, Reactor Protection System (RPS) and Nuclear Instrumentation (NI) Operating Procedure, Section 4.3.
BOP IF exchanging the RCS PRESSURE NNI input, THEN perform the following:
- 1.
Place the following Pressurizer Heaters in OFF OR as directed by the Control Room SRO.
HIS RC2-2, Bank 2 HIS RC2-3, Bank 3 HIS RC2-4, Bank 4 IS RC2A, Essen Bank 1 HIS RC2B, Essen Bank 2
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
3 Event #
4 Page 8
of 18 Event
Description:
RCS Pressure Instrument Selected for NNI Input Fails LO Time Position Applicants Actions or Behavior RO
- 2.
IF available, THEN place PIC RC2 Bank 1 in MANUAL and maintain RCS pressure by adjusting the output.
RO IF RC 11 PORV BLOCK, is closed, THEN open RC 11, PORV BLOCK.
RO Return to normal operation.
BOP Remove the cap on the selection panel for the alternate RC PRESSURE NNI receptacle in RPS Channel 2.
BOP Disconnect the amphenol connector from the RC PRESSURE NNI subassembly and reconnect the amphenol connector to the alternate RC PRESSURE NNI Receptacle.
BOP Cap the open RC PRESSURE NNI receptacle.
RO IF desired, THEN place the following Pressurizer Heaters in the designated position:
RO HIS RC2-2 Bank 2, in AUTO + BASE HIS RC2-3, Bank 3, in AUTO HIS RC2-4, Bank 4, in AUTO HIS RC2A, Essen Bank 1, in AUTO HIS RC2B, Essen Bank 2, in AUTO RO If desired, THEN place PIC RC2 Bank 1 in AUTO.
CREW Circle the RPS Channel now supplying the input signal to the NNI and record the exchange of the RCS Pressure signal in the Unit Log.
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
3 Event #
4 Page 9
of 18 Event
Description:
RCS Pressure Instrument Selected for NNI Input Fails LO Time Position Applicants Actions or Behavior On Lead Evaluators discretion, proceed to Event 5
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
3 Event #
5 Page 10 of 18 Event
Description:
120VAC Inverter Alarm Actuates in the Control Room Time Position Applicants Actions or Behavior Booth Operator Instructions:
When directed, insert command for Event 5 Indications Available:
Annunciator Alarm (1-6-A) INV YVI-YV3 TRBL CREW Refer to Annunciator Response DB-OP-02001 SRO Dispatch EO to inspect Essential Inverters YV1 or YV3 to determine which channel(s) caused the alarm.
SRO REFER to DB-OP-06319, Instrument AC System Procedure, Emergency Operations Section.
SRO REFER to Technical Specification:
3.8.2.1 Applies 24 Hour Clock for operability On Lead Evaluators discretion, proceed to Event 6
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
3 Event #
6 Page 11 of 18 Event
Description:
OTSG Tube Leak Time Position Applicants Actions or Behavior Booth Operator Instructions:
When directed, insert command for Event 6 Indications Available:
9-4-A, VAC SYS DISCH RAD HI 4-4-C, HOT LEG PRESS LO Makeup flow rising PZR level lowering CREW Refer to Annunciator Response DB-OP-02009 SRO Dispatch an operator to the affected RE to check if a high flow or low flow condition exists by observing flow at FI 1003A and FI 1003B.
SRO GO to DB-OP-02531, Steam Generator Tube Leak, for guidance.
RO Isolate Letdown by closing MU-2B.
RO IF second Makeup Pump is available, THEN start the second Makeup Pump AND verify Makeup flow is rising.
FI MU 31, MAKEUP FLOW TRAIN 2 FI 6425, MAKEUP FLOW TRAIN 1 CREW Determine which SG is leaking (OTSG-1)
CREW Calculate a leak rate using Attachment 1, Steam Generator Tube Leak Rate Calculation. (CALC 115 gpm)
SRO Determine Emergency Classification. REFER to RA-EP-01500, emergency Classification.
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
3 Event #
6 Page 12 of 18 Event
Description:
OTSG Tube Leak Time Position Applicants Actions or Behavior SRO Notify Chemistry personnel to perform Attachment 2, Chemistry Personnel Responsibilities.
SRO Notify Radiation Protection personnel to perform Attachment 3, Radiation Protection Personnel Responsibilities.
SRO Perform Attachment 4, Control of Secondary Contamination and Offsite Releases.
SRO Determine the appropriate actions based on the following criteria:
SRO IF the leak rate calculation exceeds T.S. 3.4.6.2 limits with 4 RCPs running, THEN GO TO Subsection 4.2.
SRO Notify the System Control Center (SCC) of the unit load reduction.
As determined by the Unit Supervisor, reduce unit load by any of the following methods:
RO At the LOAD CONTROL panel:
- 1.
Set the RATE OF CHANGE to a rate specified by the Unit Supervisor.
- 2.
Set the MIN LIMIT - MW to 180 Mwe.
- 3.
Depress the DEC pushbutton to lower the unit load to the target determined by the Unit Supervisor.
On Lead Evaluators discretion, proceed to Event 7
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
3 Event #
7, 8 & 9 Page 13 of 18 Event
Description:
MFPT #2 Trips; OTSG Tube Leak Rises to Rupture Following the Reactor Trip; PZR Spray Valve Fails CLOSED During Depressurization Time Position Applicants Actions or Behavior Booth Operator Instructions:
When directed, insert command for Event 7 Indications Available:
MFPT #2 Trips Reactor Trip RO Manually Trip the Reactor RO Reactor Trip Pushbutton has been depressed:
AND Power is decreasing on the Intermediate Range Nuclear Instrumentation RO Manually trip the Turbine.
Turbine Trip Pushbutton has been depressed AND Turbine Stop Valves 1, 2, 3 AND 4 are closed.
SRO Implement any necessary Specific Rules SG LEVEL SETPOINTS - May apply. MDFP must be started to feed OTSG 1.
SRO Implement any necessary Symptom Mitigation Sections
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
3 Event #
7, 8 & 9 Page 14 of 18 Event
Description:
MFPT #2 Trips; OTSG Tube Leak Rises to Rupture Following the Reactor Trip; PZR Spray Valve Fails CLOSED During Depressurization Time Position Applicants Actions or Behavior Section 8.0 STEAM GENERATOR TUBE RUPTURE - does apply. SRO will route to Section 8.0, Step 8.7 CRITICAL TASK RO IF HPI piggyback operation is NOT in service, THEN line up and start HPI piggyback operation as follows:
Start the standby CCW Pump.
Start BOTH HPI Pumps HPI Pump 1 HPI Pump 2 Open HPI Injection Valves HP 2A HP 2B HP 2C HP 2D Start BOTH LPI Pumps LPI Pump 1 LPI Pump 2 Open piggyback valves DH 63 DH 64
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
3 Event #
7, 8 & 9 Page 15 of 18 Event
Description:
MFPT #2 Trips; OTSG Tube Leak Rises to Rupture Following the Reactor Trip; PZR Spray Valve Fails CLOSED During Depressurization Time Position Applicants Actions or Behavior RO Align the Makeup and Letdown System as follows:
RO Verify letdown is isolated.
RO Lock MU Pump suctions in the BWST position.
MU 3971 MU 6405 RO Verify the Standby MU Pump is running.
RO IF BOTH MU Pumps are running, THEN open MU 6421, CTMT ISOLATION FOR ALTERNATE INJECTION LINE.
RO Control MU flow using MU 6419 and MU 32.
BOP Verify SG levels are controlled at OR increasing the proper level using Specific Rule 4.
SG 1 SG 2 RO Depressurize the RCS as follows:
Turn off all PZR heaters.
CAUTION:
With the SFAS Low RCS Pressure Trip blocked, the operator is responsible for initiating SFAS should the leak rate increase such that Pressurizer level OR RCS pressure can NOT be controlled.
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
3 Event #
7, 8 & 9 Page 16 of 18 Event
Description:
MFPT #2 Trips; OTSG Tube Leak Rises to Rupture Following the Reactor Trip; PZR Spray Valve Fails CLOSED During Depressurization Time Position Applicants Actions or Behavior CREW IF SFAS has NOT actuated on Low RCS Pressure, AND RCS pressure decrease is being manually controlled, THEN block the SFAS Low RCS Pressure trip when the BLOCK PERMIT comes on.
RO Use Pressurizer Spray to reduce RCS pressure to maintain minimum adequate subcooling margin.
Open RC 10, PZR SPRAY BLOCK Valve.
RO Open RC 2, PZR SPRAY Valve (valve does NOT open).
SRO IF Pressurizer Spray is NOT available OR is NOT sufficient to reduce RCS pressure THEN REFER to Step 8.14 for guidance on Depressurizing the RCS without PZR Spray.
RO Depressurize the RCS as follows:
RO Turn off all PZR Heaters.
RO Start the QT Circ Pump if available.
RO Reduce RCS pressure to close to the minimum adequate SCM curve (Fig. 1) using one of the following methods:
PZR Vent Line Method
- 1.
Open RC239A, PZR STEAM SPACE SAMPLE VALVE
- 2.
Open RC 200, PZR VENT TO QT ISOLATION.
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
3 Event #
7, 8 & 9 Page 17 of 18 Event
Description:
MFPT #2 Trips; OTSG Tube Leak Rises to Rupture Following the Reactor Trip; PZR Spray Valve Fails CLOSED During Depressurization Time Position Applicants Actions or Behavior
- 3.
Manually cycle RC 200 AND control PZR heaters to maintain RCS pressure.
- 1.
Open RC 11, PORV Block Valve
- 2.
Open RC 2A, PORV
- 3.
Manually cycle the PORV AND control PZR heaters to maintain RCS pressure close to the minimum adequate SCM curve of Figure 1.
CAUTION:
With the SFAS Low RCS Pressure trips blocked, the operator is responsible for initiating SFAS if the leak rate rises such that PZR level OR RCS pressure can NOT be controlled.
CREW IF SFAS has NOT actuated on Low RCS Pressure, AND if the RCS pressure decrease is being manually controlled with adequate SCM THEN block the SFAS Low RCS Pressure trips when the BLOCK PERMITs come in.
RO Allow HPI and MU to recover PZR level AND maintain PZR level from 80 to 120 inches by controlling HPI and MU.
SRO Check for entry into PTS criteria. REFER to Specific Rule 5.
CREW Establish a 50°F/hr cooldown rate.
BOP IF SFRCS has tripped the AVVs, THEN block the trip and take control as follows:
Appendix D Operator Action Form ES-D-2 Op Test No.:
1 Scenario #
3 Event #
7, 8 & 9 Page 18 of 18 Event
Description:
MFPT #2 Trips; OTSG Tube Leak Rises to Rupture Following the Reactor Trip; PZR Spray Valve Fails CLOSED During Depressurization Time Position Applicants Actions or Behavior
- 1. Place BOTH AVV H/A Stations in HAND
- 2. Reduce BOTH demands to zero.
- 3. Press the AVV BLOCK pushbuttons (HIS-ICS-11D or HIS-ICS-11C).
- 4. Press AUTO on HIS-ICS-11B or HIS-ICS-11A.
- 5. Control SG pressure using the H/A Station.
CRITICAL TASK CREW Depressurize the RCS down to AND maintain close to the minimum adequate subcooling margin limit during RCS cooldown.
Scenario may be terminated when RCS depressurization is in progress