ML15245A466
| ML15245A466 | |
| Person / Time | |
|---|---|
| Site: | Davis Besse  |
| Issue date: | 06/22/2015 |
| From: | Division of Reactor Safety III |
| To: | FirstEnergy Nuclear Operating Co |
| Reeser, D W | |
| Shared Package | |
| ML15217A121 | List: |
| References | |
| Download: ML15245A466 (79) | |
Text
Appendix D Scenario Outline Form ES-D-1 NUREG-1021, R9 Supp. 1 Page 1 of 16 FENOC Facsimile AG Facility:
Davis-Besse Scenario No.:
1 Op Test No.:
Operators:
SRO ATC BOP Initial Conditions:
100% Power CCW Pump 1 and MUP 2 in service Turnover: Maintain 100% Power Critical tasks: 1. ATWS (CT24
) 2. Establish FW flow and feed SGs (CT10) Event No. Malf. No. Event Type*
Event Description 1 SRO (TS) AFPT 1 Trip valve fails closed 2 C-BOP/SRO Circ Pump high stator temperature 3 I-ATC/SRO Pressurizer Level instrument failure 4 C-BOP/SRO Rising Condenser pressure 5 C-ATC/SRO (TS) Makeup Pump trip 6 R-ATC/SRO Loss of Letdown 7 C-ATC/SRO ATWS (trip pushbuttons fail) 8 M-All SG 1 stuck open safety 9 C-BOP/SRO AFPT 2 to SG 2 overfeed 10 C-ATC/SRO Spray valve fails open
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
Scenario Event Summary NUREG-1021, R9 Supp. 1 Page 2 of 16 FENOC Facsimile AG DAVIS-BESSE 2015 NRC SCENARIO 1 The Crew will take the watch with power at 100%. Following turnover the Lead Evaluator will cue the Auxiliary Feed Pump (AFP
- 1) Turbine Trip Throttle Valve (TTV) to fail closed and annunciator alarm, AFP1 TRBL, will come into alarm. The SRO will declare AFP 1 Inoperable and enter the applicable Tech Spec (TS).
After the AFP TS is entered, the Lead Evaluator can cue the Circulating Water Pump (CWP) stator temperature increase.
-OP-02517, Circulating Water System Malfunctions. The BOP will be directed to stop CWP 1 When CWP 1 is stopped the lead evaluator will cue the selected PZR Level instrument failure which will fail low over two minutes. Annunciator PZR LVL LO will alarm. The SRO will implement DB
-OP-02513, PZR Abnormal Operations. The ATC will place PZR level control valve MU32 in manual, select the alternate instrument and return MU32 to automatic control.
After MU32 is returned to automatic control the Lead Evaluator will cue the rising condenser pressure. The SRO will implement DB-OP-02518, HIGH CONDENSER PRESSURE. The BOP will recognize the Mechanical Hogger (motor vacuum pump) has failed to auto start. The BOP will start the Mechanical Hogger and the pressure increase will stop.
The Lead Evaluator will then cue the Makeup Pump trip.
The SRO will implement DB-OP-02512, Loss of RCS Makeup. The ATC will close MU2B, RCS Letdown, MU19 Seal injection and MU32 PZR level control. The SRO will enter the applicable TS for the Inoperable Makeup Pump. The ATC will start the standby Makeup pump and restore MU flow, Seal Injection flow and attempt to restore Letdown flow. The Letdown valve, MU2B, will be failed closed.
The SRO will implement DB-OP-02512, for Loss of Letdown Flowpath.
When it is determined Letdown flow cannot be established the SRO will direct a plant shutdown per DB-OP-02504, Rapid Shutdown.
While the shutdown is in progress the Lead Evaluator can cue the CD2796 close failure which causes a loss of condensate flow. The Deaerator levels will drop causing a runback and as the Deaerator levels approach off scale low the SRO will direct tripping the Reactor, tripping both MFPTs and Steam Feed Rupture Control System (SFRCS) initiation and isolation per the Deaerator level alarm procedure DB
-OP-02013, Alarm Panel 13 annunciators.
The ATC will attempt to trip the Reactor per DB
-OP-02000. The trip buttons will not function and the ATC will de
-energize E2 and F2 (CRD) to trip the Reactor (CT-24). The ATC will trip both MFPT and initiate and isolate SFRCS (CT-10). SG1 safety will stick open. DB-OP-02000, Overcooling Section 7, will be entered. The Motor Driven Feed Pump will fail to start.
AFPT 2 will start and feed at full flow with its discharge failed open.
The BOP will be required to control SG2 level with AFPT 2 speed control (CT-10).
The BOP will control RCS temperature using SG 2 AVV and the ATC will begin depressurizing the Reactor Coolant System to minimum subcooling margin. When the RCS spray valve is opened it will fail and the ATC will close the spray block.
When the spray valve is isolated and SG2 level is controlled the scenario can be terminated
.
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
1 Event #
1 Page 3 of 16 Event
Description:
AFPT 1 Trip Throttle Valve (TTV) fails closed Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 3 of 16 FENOC Facsimile AG Event 1: AFPT 1 TTV Fails Closed Indications Available:
10-4-G, AFP 1 TRBL 10-2-G, AFPT 1 OVRSPD TRIP Computer Alarm Z001, AFPT 1 STOP/GOV/STM IN ISO VLVS CREW Recognize AFP 1 TRBL Annunciator Alarm BOP Implement DB
-OP-02010, Feedwater Alarm Panel 10 Annunciators alarm 10-4-G, AFP 1 TRBL CREW Diagnose AFPT 1 Trip Throttle Valve not fully open by computer alarm Z001 BOP Dispatch Equipment Operator to inspect AFPT 1 Booth Cue After 2 minutes role play as Equipment Operator and report: "AFPT 1 Trip Throttle Valve is tripped closed" SRO Direct opening AFPT 1 Trip Throttle Valve. Request Maintenance assistance.
Booth Cue Role play as Equipment Operator and report: "AFPT 1 Trip Throttle Valve will not reset and Maintenance requests it be tagged out for troubleshooting
" SRO Declare AFPT 1 Inoperable. Enter TS 3.7.5, Condition B Direct energize blue TS Operability light SRO Request Risk evaluation or refer to Risk Matrix and determine risk level is Yellow (OPTIONAL)
On Lead Evaluator's discretion, insert Event 2, Circulating Water Pump high temp
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
1 Event # 2 Page 4 of 16 Event
Description:
Circulating Water Pump 1 high stator temperature Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 4 of 16 FENOC Facsimile AG Event 2: Stop Circulating Water Pump 1 due to high stator temperature Indications Available:
11-3-E CIRC WATER PUMP TEMP HI T110 CWP 1 MTR STATOR TEMP T113 CWP 1 TRBL CWP 1 elevated amps CREW Recognize symptoms of high stator temperature on Circulating Water Pump 1 BOP Refer to DB
-OP-02011, Heat Sink Alarm Panel Annunciators Direct an Equipment Operator to investigate Circ Water Pump 1 locally Trend computer point T110 SRO Implement DB
-OP-02517, Circulating Water System Malfunction Booth Cue Role play as an Equipment Operator:
- report Circ Water Pump 1 oil levels are normal, cooling water lineups are normal, no excessive vibration and no obstructions are around the motor vents BOP Stop Circ Water Pump 1 using DB-OP-02517, Attachment 1, Shutdown of a Loop 1 Circ Water Pump BOP Depress close on both Circ Water Loop 1 Pump Discharge Valves HIS856, Circ Water Pump 1 Discharge Valve HIS861, Circ Water Pump 2 Discharge Valve BOP When the Circ Water Pump Discharge Valves reach the throttled position, then depress close on the Discharge Valve for Circ Water Pump 1 HIS856, Circ Water Pump 1 Discharge Valve
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
1 Event # 2 Page 5 of 16 Event
Description:
Circulating Water Pump 1 high stator temperature Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 5 of 16 FENOC Facsimile AG Event 2: Stop Circ Water Pump 1 due to high stator temperature
- continued BOP Verify HIS856, Circ Water Pump 1 Discharge Valve Closed light comes on BOP Verify Circ Water Pump 1 has stopped (after time delay)
ATC Monitor Reactor power Reduce Reactor Power to less than or equal to the 100% CREW If Condenser pressure reaches 5 inches HgA, then reduce Reactor power to maintain Condenser pressure less than or equal to 5 inches HgA SRO Notify Chemistry of the change in alignment Booth Cue Role play as Chemistry to shutdown/realign the Circ Water Chemical Addition System and Chlorination System On Lead Evaluator's discretion, proceed to Event 3, PZR Level Instrument Failure
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
1 Event # 3 Page 6 of 16 Event
Description:
PZR Level Transmitter fails low over 2 minutes Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 6 of 16 FENOC Facsimile AG Event 3: Pressurizer Level RC 14
-2 fails low Indications Available:
Makeup flow increasing with no change in PZR level 4-2-E PZR LVL LO 4-1-E PZR LO LVL HTR TRIP MU 32 demand increasing CREW Recognize a Pressurizer level transmitter failure SRO Implement DB
-OP-02513, Pressurizer System Abnormal Operations
, for Failure of Selected Pressurizer Level or Temperature Instruments ATC Place MU 32 in HAND and control PZR level ATC Compare Pressurizer level instruments and select a functional alternate level instrument:
LTRC14-1 (L772) X instrument OR LTRC14-3 (L773) Y instrument SRO If NNI-Y instrument selected refer to DB
-OP-06407 for non
-preferred selector switch alignment ATC Return MU 32 to automatic control SRO IF Pressurizer Level is greater than 228 inches, then refer to Technical Specification 3.4.9 Condition A Booth Cue Role play Work Week Manager/I&C as necessary to investigate pressurizer level transmitter failure On Lead Evaluator's discretion, proceed to Event 4
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
1 Event # 4 Page 7 of 16 Event
Description:
Rising Condenser Pressure
- vacuum pump auto start failure Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 7 of 16 FENOC Facsimile AG Event 4: Rising Condenser pressure Indications Available:
15-1-F HP CNDSR PRESS HI 15-2-F LP CNDSR PRESS HI 15-5-B DEHC MINOR ALARM CREW Recognize rising Condenser pressure BOP NOTE: Crew may take actions prior to alarm Implement DB
-OP-02015, TURBINE ALARM PANEL 15 ANNUNCIATORS (alarm comes in at 5
.7 inches HgA)
Check pressure at PR530 Check pressure at PR541 SRO Implement DB-OP-02518, HIGH CONDENSER PRESSURE ATC Monitor Reactor Power Maintain Reactor Power 100% or less BOP IF AT ANY TIME Condenser Pressure reaches 4.5 inches HgA (LP Condenser),
THEN verify the Mechanical Hogger Starts ATC IF AT ANY TIME Condenser Pressure reaches 5 inches HgA THEN reduce Reactor Power to maintain Condenser pressure less than or equal to 5 inches HgA BOP Recognize Condenser Pressure reaches 4.5 inches HgA (LP Condenser) and Mechanical Hogger has not started BOP Start Mechanical Hogger HIS1005 Mechanical Hogger CREW Recognize condenser pressure rise has stopped On Lead Evaluator's discretion, w hen Condenser pressure rise has been stopped, proceed to Event 5, Loss of RCS Makeup
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
1 Event # 5 Page 8 of 16 Event
Description:
Makeup Pump 2 Trip Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 8 of 16 FENOC Facsimile AG Event 5: Makeup Pump 2 Trip Indications Available:
6-5-C SEAL INJ FLOW LO 6-6-C SEAL INJ TOTAL FLOW Makeup Pump red RUN light OFF Zero Makeup flow MU32, Pressurizer Level Control Opening MU19, RCP Seal Injection Flow Control Opening CREW Recognize a loss of running RCS Makeup Pump SRO Implement DB
-OP-02512, Makeup and Purification System Malfunctions for a loss of RCS Makeup Pump(s)
ATC Isolate Letdown using MU 2B Depress close HISMU2B BOP Verify CCW is being supplied to the RCPs using Attachment 1, Verification Of CCW Flow To Reactor Coolant Pumps BOP Verify CCW Pump in service BOP Verify CCW Non-Essential flow path to Containment available CC5095, Supply Open CC5097, CTMT BLDG Return Open BOP Verify CCW flow path to Containment available CC1411A Open CC1411B Open BOP Verify CCW return path from Containment available CC1407A Open CC1407B Open Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
1 Event # 5 Page 9 of 16 Event
Description:
Makeup Pump 2 Trip Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 9 of 16 FENOC Facsimile AG Event 5: Makeup Pump 2 Trip
- continued BOP Verify Seal Cooling CCW Return flow path is available RCP 1-1 CC4100 Open RCP 1-2 CC4200 Open RCP 2-1 CC4300 Open RCP 2-2 CC4400 Open BOP Check Annunciator Alarm 6 B, SEAL CCW FLOW LOW is extinguished BOP Notify SRO CCW flow is available to the Reactor Coolant pumps ATC Monitor Pressurizer level and compare to curve CC 4.3 Anytime Pressurizer Level is less than 160 inches, trip the reactor and go to DB
-OP-02000 ATC Isolate RCP Seal Injection by closing MU19 ATC Place MU32 in Hand AND close MU32 to isolate the normal Makeup flowpath SRO Refer to DB
-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation CREW Monitor RCP Seal parameters BOP/ATC Maintain Tave constant SRO Refer to TRM 8.1.1, Boration Systems
- Operating Enter TRM 8.1.1, Nonconformance A
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
1 Event # 5 Page 10 of 16 Event
Description:
Makeup Pump 2 Trip Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 10 of 16 FENOC Facsimile AG Event 5: Makeup Pump 2 Trip
- continued SRO Notify the Shift Manager to perform event notifications Dispatch Operator to investigate Booth Cue Role play if asked to investigate Makeup Pump 2 trip
- report 50/59 relay target on MUP 2 breaker AD105 Role play if asked no local pump problems observed ATC Verify Makeup Pump did not indicate cavitation No erratic amps, No erratic flow No erratic discharge pressure Makeup pump did not empty BOP Dispatch Operator to monitor makeup pump start ATC 1. Start Makeup Pump 1 oil pumps
- 2. Start Makeup Pump Booth Cue Role play as equipment Operator and report when stationed at MUP and proper operation of MUP 1 ATC Restore Makeup flow
- place MU32 in Automatic ATC Restore Seal Injection flow:
Verify MU19 closed Verify MU66A through D open Verify MU6408 Open Verify MU6409 Open Gradually over 2 minutes open MU19 to establish 12
-15 gpm seal inject flow (minimum 3 gpm to any RCP)
ATC Restore letdown
- Attempt to open MU2B ATC reports MU2B will not open MU2B is triggered to be failed closed. Proceed to event 6 Loss of Letdown Flowpath Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
1 Event # 6 Page 11 of 16 Event
Description:
Loss of Letdown Flowpath
- MU2B fails closed Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 11 of 16 FENOC Facsimile AG Event 6: Loss of Letdown Flowpath Indications Available:
MU2B will not open following Makeup Flow restoration ATC Reports to SRO Letdown cannot be restored SRO Implement DB
-OP-02512 for Loss of Letdown Flowpath SRO Contacts Equipment Operator and/or Maintenance to determine cause of MU2B fail to open Booth Cue "MU2B failure to open appears to be a problem with the valve" SRO Request Chemistry to maximize sample flow ATC Open RC240A & RC240B Pressurizer liquid sample isolations SRO Determines the response not obtained step applies for restoring letdown flow and a shutdown is required.
Implement DB
-OP-02504, Rapid Shutdown ATC ULD with ICS in Automatic At the LOAD CONTROL Panel, set the rate of change to the rate specified by the Command SRO Select the target RTP as determined by the Command SRO CREW Monitor Reactor Power to confirm power is being reduced at approximately the expected rate (NI vs. HBP)
SRO IF Pressurizer Level is greater than 228 inches, then refer to Technical Specification 3.4.9 Condition A On Lead Evaluator's discretion, when reactivity manipulation is attained, proceed to event 7, Loss of Condensate/ATWS
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
1 Event # 7 Page 12 of 16 Event
Description:
Loss of Condensate flow and ATWS Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 12 of 16 FENOC Facsimile AG Loss of Condensate
/ATWS Indications Available:
13-2-B CNDS PMP DISCH HDR PRESS FI578 COND PMP COMBINED FLOW indicates 0 MMPH CREW Recognize Condensate flow is lost BOP Implement DB
-OP-02013 for 13 B BOP Dispatch an Operator to investigate CD2796 Booth Cue Role play as Equipment Operator and report CD2796 is closed and will not open BOP Implement DB
-OP-02013 for low Deaerator level CREW Monitor proper runback when Deaerator levels reach 4 feet SRO When Deaerator levels approach off scale low direct:
Trip Reactor Trip both MFPTs Initiate and isolate SFRCS
-OP-02000 immediate actions Attempt to manually trip reactor Report failure of manual pushbuttons to trip reactor
- De-energize E2 and F2 Re-energize E2 and F2 Verify power decreasing on the Intermediate Range Manually trip the turbine
- Manually actuate SFRCS Proceed to Events 8
, 9 & 10 Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
1 Event # 8, 9 & 10 Page 13 of 16 Event
Description:
SG1 Safety sticks open, SG2 overfill and PZR Spray fails open Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 13 of 16 FENOC Facsimile AG Events 8, 9 & 10: SG1 Safety sticks open, SG2 overfill and PZR Spray fails open Indications Available:
SG1 Pressure lowering SG2 Level rising above setpoint RC2, PZR Spray valve not closing BOP Recognize no AFW flow to SG 1 BOP Specific Rule 4
- Steam Generator Control
- Refer to Attachment 5 to place the MDFP in service to feed SG 1 Enable both MDFP Discharge Valves Close both MDFP Discharge Valves Attempt to start the MDFP Recognize MDFP does not start Booth Cue If asked, role play as Equipment Operator and report MDFP breaker AD210 has overcurrent relay tripped CREW Recognize overcooling SG1 SRO Implement DB
-OP-02000, section 7 Overcooling ATC Implement Attachment 8, Place MU/HPI/LPI in Service Start/Verify running both CCW Pumps Start/Verify running both HPI Pumps Verify open HP 2A, HP 2B, HP 2C and HP 2D Start both LPI Pumps Open DH 64 and DH 63 Transfer Makeup Pump suctions, MU6405 & MU3971, to the BWST Set Pressurizer Level Controller to 100 inches Lock MU Pump suctions, MU6405 & MU3971, on the BWST Verify Pressurizer heaters are off BOP Verify proper SFRCS. Refer to DB
-OP-02000, Table 1 Events 8, 9 & 10: SG1 Safety sticks open, SG2 overfill and PZR Spray fails open
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
1 Event # 8, 9 & 10 Page 14 of 16 Event
Description:
SG1 Safety sticks open, SG2 overfill and PZR Spray fails open Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 14 of 16 FENOC Facsimile AG CREW Diagnose stuck open safety SG1 BOP Control SG2 AVV to maintain RCS temperature constant or slowly lowering BOP Recognize SG2 above setpoint with full Aux Feedwater flow.
- Critical Task BOP *Control SG2 level by performing one or more of the following:
Reduce AFPT 2 speed Close AF599 SRO Direct reducing RCS pressure to minimum adequate subcooling margin.
ATC Begin to depressurize the RCS using Pressurizer Spray ATC Open RC2, Pressurizer Spray ATC When attempting to stop depressurization recognize RC2 will not close ATC Close RC10, Pressurizer Spray Valve Block Valve When SG2 Level control is established and the depressurization has been stopped the Scenario can be terminated
NUREG-1021, R9 Supp. 1 Page 15 of 16 FENOC Facsimile AG Justification for Critical Tasks A. Shutdown Reactor
- ATWS (CT-24) The Reactor will be required to be tripped when Deaerator levels are lost resulting in a loss of Feedwater. The Reactor trip pushbuttons will fail which will require the CRDMs to be de-energized by momentarily de
-energizing buses E2 and F2 from the Control Room.
B. Establish FW flow and Feed SG (CT-10) The Steam Feed Rupture Control System will be required to be manually actuated to provide feedwater from AFP 2 and Steam Generator level control will have to be manually controlled to prevent overfill of SG2 which would result in the loss of the remaining secondary heat removal source.
NUREG-1021, R9 Supp. 1 Page 16 of 16 FENOC Facsimile AG SIMULATOR SETUP INFORMATION
- 1. Simulator Setup a) CCW Pump 1 and MUP 2 in service b) Mechanical Hogger Auto start failure c) MU2B fail to open after closure d) Auto Reactor trip prohibited e) Auto SFRCS initiate and isolate prohibited f) AFPT 2 Discharge valve failure g) Spray valve fails to close when manually opened
- 2. Procedures a) DB-OP-02010, Feedwater Alarm Panel 10 Annunciators for 10-4-G b) DB-OP-02011, Heat Sink Alarm Panel Annunciators, for 11-3-E c) DB-OP-02517, Circulating Water System Malfunction d) DB-OP-02513, Pressurizer System Abnormal for Level Instrument e) DB-OP-06221, Condensate System Procedure.
f) DB-OP-02015, TURBINE ALARM PANEL 15 ANNUNCIATORS g) DB-OP-02518, HIGH CONDENSER PRESSURE h) DB-OP-02012, Makeup and Purification System Malfunctions i) DB-OP-02013, Condensate and feedwater alarm panel annunciators j) DB-OP-02000, RPS, SFAS, SFRCS Trip, or Steam Generator Tube Rupture
- 2) For Simulator Instructor:
a) DB-OP-02518 Attachment 1 b) DB-OP-06006 Section 3.2, Starting Makeup Pump 1
Appendix D Scenario Outline Form ES-D-1 NUREG-1021, R9 Supp. 1 Page 1 of 17 FENOC Facsimile AG Facility:
Davis-Besse Scenario No.:
2 Op Test No.:
Operators:
SRO ATC BOP Initial Conditions:
100% Power EDG 1 OOS Turnover: Maintain 100% Power Planned: Swap Main Feed Pump Turbine Main Oil Pumps per the Monthly Activity Log Critical tasks: 1. Establish Electrical Power Alignment (CT
-2) Event No. Malf. No. Event Type*
Event Description 1 N-BOP/SRO Swap MFPT Oil Pumps 2 SRO (TS) Startup Transformer 02 Lockout 3 C-ATC/SRO Makeup Filter high differential pressure 4 I-BOP/SRO Deaerator level transmitter fails low 5 SRO (TS) Oil leak on Containment Spray Pump 6 R-ATC/SRO C-BOP/SRO RCP 1-1 high vibrations
- reduce power FW auto re
-ratio fails when trip RCP 7 C-ATC/SRO 3 Power Range N Is fail - Trip reactor 8 Major Loss of Offsite Power 9 Major RCS Leak 10 C-ATC/SRO EDG 2 trips after starting
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
Scenario Event Summary NUREG-1021, R9 Supp. 1 Page 2 of 17 FENOC Facsimile AG DAVIS-BESSE 2015 NRC SCENARIO 2 The Crew will take the watch with power at 100%. Following turnover the Crew will swap running Main Feed Pump Turbine Main Oil Pumps as directed by the Monthly Activity Log.
After the MFPT Oil Pumps are swapped the Lead Evaluator will cue the Startup Transformer 02 Lockout. SU XFMR 02 LOCKOUT will alarm and the SRO will enter the applicable Off
-Site AC Sources Technical Specification (TS).
After the SRO has declared the TS for Off-Site AC Sources the Lead Evaluator will cue the Makeup Filter High Differential Pressure. will alarm and PDI MU13 will indicate >25 PSID. The ATC will implement DB
-OP-02002, Letdown/Makeup Alarm Panel 2 Annunciators. The SRO will direct placing the standby Makeup filter in service in accordance with DB
-OP-06006, Makeup and Purification System.
When the standby Makeup filter has been placed in service the Lead Evaluator will cue Deaerator Storage Tank 2 level, LT 420, control signal fails low. DEAR TK 1 LVL will alarm. The BOP will manually control Deaerator level by manually controlling CD
-421 using LIC421.
Once LIC421 is placed in manual and level control is established the Lead Evaluator will cue the Containment Spray (CS) Pump 1 oil leak. An Equipment Operator will call the control room to report an oil leak on Containment Spray (CS) Pump 1. The SRO will declare the CS Pump Inoperable and enter the applicable TS.
After the SRO has declared the TS for the CS Pump, the Lead Evaluator will cue the RCP 1
-1 high vibrations. MOTOR VIB HI and MONITOR SYSTEM TRBL will alarm. The SRO will implement DB-OP-02515, RCP Pump and Motor Abnormal. The SRO will implement DB
-OP-02504, Rapid Shutdown to reduce power. The ATC will reduce power to less than 72% and RCP 1-1 will be stopped
. When the RCP is stopped FW will fail to auto re
-ratio and the BOP will be required to take loop demands to hand and auto re
-ratio.
After RCP 1
-1 is stopped the Lead Evaluator will cue the 3 of 4 Power Range Nuclear Instruments low failure. The SRO will implement DB
-OP-02505, Nuclear Instrument Failures and direct the ATC to trip the Reactor.
When the Reactor is tripped a Loss of Offsite Power will occur and an RCS leak will develop. EDG 2 will trip after starting. Since EDG 1 is OOS this will cause a blackout until the BOP starts Station Blackout Diesel Generator (SBODG) and powers 4160 buses D2 and D1 per Attachment 28 of DB
-OP-02000 IAW Specific Rule 6. (CT-8)
DB-OP-02000 Loss of Subcooling Margin Section 5 will be entered. Train 2 Makeup and HPI will be placed in service after the SBODG is aligned to D2 and D1 buses. (CT-2) Subcooling margin will be regained and HPI should be throttled. The SG Atmospheric Vent Valves will be controlled to maintain RCS temperature constant or slightly lowering.
The scenario can be terminated, at the Lead Evaluators discretion.
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
2 Event # 1 Page 3 of 17 Event
Description:
Swap running MFPT Main Oil Pumps per the Monthly Activity Log Time Position Applicant's Actions or Behavior NUREG-1021, R9, Supp. 1 Page 3 of 17 FENOC Facsimile Rev. 1 Event 1: Swap running MFPT Main Oil Pumps SRO Direct BOP to swap running MFPT 1 and 2 Main Oil Pumps as directed by the Monthly Activity Log per DB
-OP-06224,Main Feed Pump and Turbine, sections 3.23 and 3.24 BOP Swap MFPT 1 Main Oil Pumps BOP Verify Equipment Operator standing by to monitor oil pressures BOP 1. Start MFPT 1 Main Oil Pump 2, using HIS 1198 MAIN FEED PUMP 1 Main Oil Pump 2
- 2. Stop MFPT 1 Main Oil Pump 1, using HIS 119 5, MAIN FEED PUMP 1 Main Oil Pump 1 BOP NOTE: Contacts Equipment Operator for local indications Check MFPT 1 Main Oil Pump pressure indications:
PI 1194 Hydraulic Oil Pressure is > 200 PSIG PI 1216 Turbine Bearing Oil Pressure is > 10 PSIG PI 1207 Pump Bearing Oil Pressure is > 10 PSIG PI 2650 Control Oil Pressure is 52.5 - 62.5 PSIG PI 1206 Lube Oil System HDR Pressure (CTRM) is between 10 and 16 PSIG Booth Cue "PI 1194 indicates 238 psig. PI 1216 indicates 12 psig. PI 1207 indicates 12 psig PI 2650 indicates 55 psig." BOP Verify the available MFPT 1 Main Oil Pumps are in AUTO START: HIS 1195, MAIN FEED PUMP 1 Main Oil Pump 1 HIS 1198, MAIN FEED PUMP 1 Main Oil Pump 2 BOP Swap MFPT 2 Main Oil Pumps BOP Verify Equipment Operator standing by to monitor oil pressures
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
2 Event # 1 Page 4 of 17 Event
Description:
Swap running MFPT Main Oil Pumps per the Monthly Activity Log Time Position Applicant's Actions or Behavior NUREG-1021, R9, Supp. 1 Page 4 of 17 FENOC Facsimile Rev. 1 Event 1: Swap MFPT Main Oil Pumps
- continued BOP 1. Start MFPT 2 Main Oil Pump 1, using HIS 1236, MAIN FEED PUMP 2 Main Oil Pump 1
- 2. Stop MFPT 2 Main Oil Pump 2, using HIS 1247, MAIN FEED PUMP 2 Main Oil Pump 2 BOP NOTE: Contacts Equipment Operator for local indications Check MFPT 1 Main Oil Pump pressure indications:
PI 1246 Hydraulic Oil Pressure is > 200 PSIG PI 1259 Turbine Bearing Oil Pressure is > 10 PSIG PI 1257 Pump Bearing Oil Pressure is > 10 PSIG PI 2630 Control Oil Pressure is 52.5
- 62.5 PSIG PI 1256 Lube Oil System HDR Pressure (CTRM) is between 10 and 16 PSIG Booth Cue "PI 1246 indicates 238 psig. PI 1259 indicates 12 psig. PI 1257 indicates 12 psig PI 2630 indicates 55 psig." BOP Verify the available MFPT 2 Main Oil Pumps are in AUTO START: HIS 1236, MAIN FEED PUMP 1 Main Oil Pump 1 HIS 1247, MAIN FEED PUMP 1 Main Oil Pump 2 On Lead Evaluator's discretion, insert Event 2
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
2 Event # 2 Page 5 of 17 Event
Description:
Startup Transformer 02 Lockout Time Position Applicant's Actions or Behavior NUREG-1021, R9, Supp. 1 Page 5 of 17 FENOC Facsimile Rev. 1 Event 2: Startup Transformer 2 Lockout Indications Available:
1-1-G SU XFMR 02 LOCKOUT 1-2-G SU XFMR 02 DNGR ACB 34562 Open
& ACB 34564 Open 81-B-65 Open & 81-B-67 Open CREW Recognize Startup Transformer 02 Lockout CREW Recognize loss of K bus ATC Implement DB
-OP-02001, Electrical Distribution Panel 1 SRO Notify the Load Dispatcher K Bus is de
-energized Booth Cue Role play as Load Dispatcher: "We are sending a crew to investigate" SRO Direct Isolation of SU Transformer 02 Refer to DB
-OP-06311, 345KV Switchyard Procedure SRO Dispatch Equipment Operator to investigate S/U Xfmr 02 Booth Cue Role play as Equipment Operator: "Local Annunciator Alarm (102-7-A) SUDDEN PRESSURE is in alarm. SU Transformer 02 has no visible damage."
-OP-2102, Startup Transformer 02 Alarm Panel 102 Annunciators for alarm 102 A (same actions as transformer lockout)
ATC Transfer B bus reserve source selector switch to X01
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
2 Event # 2 Page 6 of 17 Event
Description:
Startup Transformer 02 Lockout Time Position Applicant's Actions or Behavior NUREG-1021, R9, Supp. 1 Page 6 of 17 FENOC Facsimile Rev. 1 Event 2: Startup Transformer 2 Lockout
- continued SRO Refer to Tech Spec 3.8.1, AC Sources
- Operating Enter TS 3.8.1, Condition A & D Direct performance of DB
-SC-03023, Off
-Site Sources SM Cue Another Operator will ensure completion and review of DB
-SC-03023, Off
-Site Sources On Lead Evaluator's discretion, when Tech Spec declared proceed to Event 3
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
2 Event # 3 Page 7 of 17 Event
Description:
Makeup Filter high differential pressure Time Position Applicant's Actions or Behavior NUREG-1021, R9, Supp. 1 Page 7 of 17 FENOC Facsimile Rev. 1 Event 3: Makeup Filter high differential pressure Indications Available:
2 PDI MU13 indicates >25 PSID CREW Recognize Makeup Filter high differential pressure for in service Makeup Filter 1 ATC Implement DB
-OP-02002, Letdown/Makeup Alarm Panel 2 Annunciators SRO Direct placing Makeup Filter 2 in service in accordance with DB-OP-06006, Makeup and Purification System ATC Swap to Makeup Filter 2 ATC Open MU12B, MAKEUP FILTER 2 INLET ISOLATION, using HISMU12B.
ATC Close MU12A, MAKEUP FILTER 1 INLET ISOLATION, using HISMU12A.
On Lead Evaluator's discretion, proceed to Event 4
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
2 Event # 4 Page 8 of 17 Event
Description:
Deaerator level transmitter fails low over a ramp Time Position Applicant's Actions or Behavior NUREG-1021, R9, Supp. 1 Page 8 of 17 FENOC Facsimile Rev. 1 Event 4: Deaerator level transmitter fails low Indications Available:
13-4-C, DEAR STRG TK 1 LVL 13-4-D, DEAR STRG TK 2 LVL (may also alarm)
Level indicator failed low (Indicator to LIC CD421)
Actual Deaerator Level rising as LCV opens CREW Recognize Deaerator Storage Tank 1 level BOP Diagnose high Deaerator Storage Tank 1 water level as indicated at LI 202, DEAERATOR STORAGE TANK 1.
-OP-02013, Condensate Feedwater Alarm Panel Annunciators BOP Verify the proper number of Condensate Pumps are in operation for the present unit load BOP Diagnose Deaerator Storage Tank 1 level transmitter failure BOP Manually control Deaerator 1 level by manually controlling CD
-421 using LIC
-421 and throttling closed (may also take CD
-420 to manual for Deaerator 2)
Booth Cue Role play as an Equipment Operator to investigate CD420 and CD421 Report valves appear to be working normally Booth Cue Role play as Maintenance/Work Week Manager/Field Supervisor to initiate repair of level transmitter On Lead Evaluator's discretion, proceed to Event 5
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
2 Event # 5 Page 9 of 17 Event
Description:
Oil Leak On Containment Spray Pump 1 Time Position Applicant's Actions or Behavior NUREG-1021, R9, Supp. 1 Page 9 of 17 FENOC Facsimile Rev. 1 Event 5: Oil Leak on Containment Spray Pump 1 Indications Available:
Equipment Operator report Booth Cue Role play as Equipment operator and report "Containment Spray Pump 1 inboard bearing has a severe oil leak and no level is indicated. The sight glass is broken and will need replaced.
" SRO May contact Maintenance and/or Work Week Manager Booth Cue If necessary
, role play as maintenance and report "Containment Spray Pump 1 will be required to be removed from service to repair broken sight glass" SRO Declare Containment Spray Pump 1 Inoperable Enter Tech Spec 3.6.6, Condition A SRO Dispatch Operator to remove close power fuses for BE111, Containment Spray Pump 1 Booth Cue Role play as Equipment Operator to remove close power fuses for BE111, Containment Spray Pump 1 BOP Turn on CS Pump 1 Blue Operability Light On Lead Evaluator's discretion after Tech Spec has been entered, proceed to Event 5 Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
2 Event # 7 Page 10 of 17 Event
Description:
Power Range Nuclear Instrument Failure Time Position Applicant's Actions or Behavior NUREG-1021, R9, Supp. 1 Page 10 of 17 FENOC Facsimile Rev. 1 Event 6: Indications Available:
6 6-5-A MONITOR SYSTEM TRBL CREW Recognize RCP 1
-1 high vibrations SRO Implement DB
-OP-02515, RCP and Motor Abnormal procedure CREW Verify the RCP 1-1 motor conditions exceed operational limits using the PPC or SPDS SRO Implement DB
-OP-02515 Attachment 1, Reactor Coolant Pump Shutdown SRO Implement DB
-OP-02504, Rapid Shutdown Direct power reduction to 70%
ATC ULD with ICS in Automatic At the LOAD CONTROL Panel, set the rate of change to the rate specified by the Command SRO Select the target RTP as determined by the Command SRO CREW Monitor Reactor Power to confirm power is being reduced at approximately the expected rate (NI vs. HBP)
ATC Monitor Regulating Rod Insertion Limits during the Shutdown per Technical Specification 3.2.1 ATC Attempt to maintain Axial Power Imbalance between 0 and negative 20 percent using APSRs BOP Perform Attachment 6, Balance of Plant Actions for Rapid Shutdown Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
2 Event # 7 Page 11 of 17 Event
Description:
Power Range Nuclear Instrument Failure Time Position Applicant's Actions or Behavior NUREG-1021, R9, Supp. 1 Page 11 of 17 FENOC Facsimile Rev. 1 Event 6: - continued BOP At approximately 90 percent power, notify the Field Supervisor to remove the Auxiliary Feed Pump Turbine Main Steam Minimum flow lines from service BOP When Condensate flow is less than 7.0 MPPH (FI578), then establish two Condensate pumps in operation SRO Notify the System Control Center (SCC) Load Dispatcher of the unit load reduction BOP ATC Reduce reactor power to
-1 BOP Verify proper Feedwater flow ratios of 2.4 to 1 BOP Recognize auto re
-ratio is not occurring
- Take both FW Loop Demands to Hand Ratio FW to approximately 2.38 MPPH on SG1 Ratio FW to approximately 5.74 MPPH on SG2 ATC Verify Tave control is on RCS Loop 2 SRO Check RCS flow is greater than the flow required by TS 3.4.1, DNB Limits.
REFER TO DB
-OP-03006, Miscellaneous Instrument Shift Checks. (Computer Point F744) SRO Notify I&C to reduce the RPS High Flux Trip setpoints within 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br /> On Lead Evaluator's discretion proceed to Event 7 Event 7: 3 Power Range Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
2 Event # 7 Page 12 of 17 Event
Description:
Power Range Nuclear Instrument Failure Time Position Applicant's Actions or Behavior NUREG-1021, R9, Supp. 1 Page 12 of 17 FENOC Facsimile Rev. 1 NIs fail low Indications Available:
5-3-5 ARTS T-G TRIP BYPASSED Power range NIs 5,6 and 7 indicate 0 CREW Recognize Power range NIs have failed low SRO Implement DB
-OP-02505, Nuclear Instrumentation Failures SRO Direct tripping the Reactor due to 3 of 4 Power Range Instruments are in a condition that prevents automatic reactor protection CREW GO TO DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube Rupture ATC Perform DB
-OP-02000 immediate actions:
- 1. Manually trip the reactor Depress the reactor trip pushbutton
- 2. Verify reactor power is decreasing on the intermediate range 3. Manually trip the turbine
- 4. Depress the turbine trip pushbutton SRO Direct the implementation of DB
-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube Rupture Verify immediate actions Check for Specific Rule or Symptom Mitigation Proceed to Events 8, 9 and 10
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
2 Event # 8, 9 and 10 Page 13 of 17 Event
Description:
Loss of Offsite power, RCS Leak, EDG 2 trips after starting Time Position Applicant's Actions or Behavior NUREG-1021, R9, Supp. 1 Page 13 of 17 FENOC Facsimile Rev. 1 Event 8: Loss of Offsite Power Event 9: Reactor Coolant System Leak Event 10: Emergency Diesel Generator 2 trips Indications Available:
Loss of Control Room Lighting Loss of Subcooling Margin CREW Recognize loss of all AC Power BOP Specific Rule 6 Recognize C1 and D1 are de
-energized Recognize EDG 1 is OOS and EDG 2 has a fault Dispatch an Equipment Operator to EDG 2
- Critical Task BOP Energize D2 Bus by performing Attachment 28, Restore Power to C1 or D1 from the SBODG Verify ABDD2 is open Verify AD110 is open
- Start the SBODG Verify AD213 is closed
- Close AD 301
- Critical Task BOP Energize C1 Verify HBBD is open
- Close ABDD2
- Close ABDC1 OR Energize D1
- Close AD110
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
2 Event # 8, 9 and 10 Page 14 of 17 Event
Description:
Loss of Offsite power, RCS Leak, EDG 2 trips after starting Time Position Applicant's Actions or Behavior NUREG-1021, R9, Supp. 1 Page 14 of 17 FENOC Facsimile Rev. 1 Events 8, 9 and 10 continued BOP Perform Specific Rule 4 Verify proper AFW actuation Refer to Attachment 3 for AVV control Verify D2 Bus is energized Verify an air compressor is running Control RCS temperature constant or slightly lowering CREW DB-OP-02000 check for Symptoms SRO Route to Section 5, Loss of Subcooling Margin CREW Verify all RCPs are tripped
- Critical Task BOP Implement Attachment 8, Place MU/HPI/LPI in Service as equipment is available Start/Verify running a CCW Pump
- Manually start a HPI Pump (auto start is failed)
- Open HP 2A and HP 2B OR HP 2C and HP 2D Refer to Attachment 11, HPI Flow Balancing Start a LPI Pump Open DH 64 OR DH 63 Transfer a MU Pump suction to the BWST Set Pressurizer Level Controller to 100 inches Close MU 19 Close MU 32
- Start a Makeup Pump
- Control Pressurizer level using MU 32 or Alternate Injection Line ATC If Pressurizer level is < 40 inches and as equipment becomes Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
2 Event # 8, 9 and 10 Page 15 of 17 Event
Description:
Loss of Offsite power, RCS Leak, EDG 2 trips after starting Time Position Applicant's Actions or Behavior NUREG-1021, R9, Supp. 1 Page 15 of 17 FENOC Facsimile Rev. 1 available:
Lock the running MU Pump suction on the BWST Isolate Letdown Verify Pressurizer heaters are off Open MU 6421 (if 2 Makeup Pumps are running)
Open MU 6419 (if 2 Makeup Pumps are running)
Direct an Equipment Operator to open MU6423B ATC Verify proper SFAS actuation BOP Verify proper SFRCS actuation BOP Verify proper SG level control BOP Realign AFW if an SFRCS low pressure trip occurs CREW Check for Overcooling CREW Check for ICC Conditions CREW Monitor for adequate Subcooling Margin ATC When Subcooling Margin is regained throttle Makeup and/or HPI as necessary per Specific Rule 3 Note: Not required to wait for subcooling margin to be regained to terminate scenario When DB-OP- - Scenario may be terminated at Lead Evaluators discretion
NUREG-1021, R9, Supp. 1 Page 16 of 17 FENOC Facsimile Rev. 1 Justification for Critical Tasks A. Electrical Power Alignment
,(CT- 8) Loss of Emergency Generator 2 with a loss of off
-site power and Emergency Generator 1 out of service results in a station blackout. The Station Blackout Diesel Generator will be required to be placed in service to supply an essential bus.
B. Initiate High Pressure Injection (CT- 2) The Reactor Coolant System Leak that develops following the loss of off
-site power will result in a loss of subcooling margin. Once an essential bus is powered by the Station Blackout Diesel Generator High Pressure Injection will be required to be placed in service to restore Reactor Coolant System inventory and subcooling margin NUREG-1021, R9, Supp. 1 Page 17 of 17 FENOC Facsimile Rev. 1 SIMULATOR SETUP INFORMATION
- 1. Simulator Setup a) Emergency Diesel Generator 1 Out of Service b) Makeup Filter 1 in service c) EDG trip after auto start d) HPI auto start prohibited
- 2. Procedures a) DB-OP-02001, Electrical Distribution Panel 1 Annunciators b) DB-OP-2102, Startup Transformer 02 Alarm Panel 102 Annunciators for alarm 102 A c) DB-OP-06311, 345KV Switchyard Procedure d) DB-OP-02000, Letdown/Makeup Alarm Panel 2 Annunciators e) DB-OP-02013, Condensate Feedwater Alarm Panel Annunciators f) DB-OP-02515, RCP and Motor Abnormal procedure g) DB-OP-02504, Rapid Shutdown h) DB-OP-02000, RPS, SFAS, SFRCS Trip, or Steam Generator Tube Rupture
- 3. For Simulator Instructor:
a) DB-OP-06311, Switchyard, Main Transformer, Auxiliary Transformer and Startup Transformers, Section 3.17 b) DB-OP-02001 for 1 G c) DB-OP-02504, Rapid Shutdown Attachment 15
- 4. For Normal Evolution a) DB-OP-06224 Section 3.24 and 3.25 Appendix D Scenario Outline Form ES-D-1 NUREG-1021, R9 Supp. 1 Page 1 of 16 FENOC Facsimile AG Facility:
Davis-Besse Scenario No.:
3 Op Test No.:
NRC 2015 Examiners:
Operators:
SRO ATC BOP Initial Conditions:
70% Power RCP 1-1 OOS EDG 1 OOS Turnover: Maintain 70% Power Planned: Perform MFPT 1 Stop Valve Test, DB
-SS-04052 Critical tasks:
-5) 3. Close RC11 PORV Block Valve (Emergent)
Event No. Malf. No. Event Type*
Event Description 1 N-BOP/SRO MFPT 1 Stop Valve Test, DB
-SS-04052 2 C-ATC/SRO (TS) PORV Leakage 3 I-ATC/BOP SRO RCS Hot Leg RTD slowly drifts HI 4 C-BOP MFPT Low Oil pressure
- trip MFPT 5 R-ATC SRO (TS) Dropped Rod
- Power reduction 6 Major SG Tube Rupture
- trip Reactor 7 C-BOP/SRO Loss of Feedwater
-SFRCS fails auto actuation 8 C-ATC/SRO PZR Spray valve fails closed
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
Scenario Event Summary NUREG-1021, R9 Supp. 1 Page 2 of 16 FENOC Facsimile AG DAVIS-BESSE 2015 NRC SCENARIO 3 The Crew will take the watch with power at 70% with 3 RCPs in operation. Following turnover the BOP will perform DB
-SS-04052, MFPT 1 Stop Valve Test.
On cue from the Lead Evaluator, a leak will be introduced on the PZR Pressure Operated Relief Valve (PORV). The crew will respond to computer and Panel 9 annunciator alarms and isolate the PORV IAW DB
-OP-02513, PRESSURIZER SYSTEM ABNORMAL OPERATION. The SRO will enter the applicable TS for the PORV.
When the SRO has declared the TS for the PORV, the Lead Evaluator will cue the selected Thot RTD transmitter (TT RC3A1) to slowly fail high. HOT LEG TEMP HIGH annunciator alarm will sound and the Integrated Control System (ICS) will begin reducing power to lower Tave. The ATC will place the Rod Control Panel in manual and the BOP will place Feedwater Loop Demands in manual to stabilize the plant. The good instrument will be selected and Tave will be restored to 582
°F. Rod Control Panel and Feedwater Loop Demand control stations will then be returned to AUTO.
When ICS is returned to Auto the Lead Evaluator will cue the MFPT oil leak. MFPT 2 LUBE OIL TK LVL will alarm. The BOP will implement DB
-OP-02010, Feedwater Alarm Panel 10 Annunciators. An Equipment Operator will report MFP 2 bearing oil header spraying oil and the pump making a squealing sound. The SRO will direct tripping the MFPT and ICS will run the plant back to 55% power OR direct power reduction to 55% and then tripping pump.
After the MFPT is removed from service the Lead Evaluator will cue the dropped control rod. Alarms CRD LCO and CRD ASYMETRIC ROD will sound and a Rod bottom light will be ON.
-OP-02516, CRD Malfunctions. The ATC will be directed to reduce power to 33% per DB
-OP-02504, Rapid Shutdown. The SRO will enter the applicable TS for the Inoperable control rod.
After the TS has been declared for the Inoperable control rod the Lead Evaluator will cue the Steam Generator Tube Rupture. Alarms MN STM LINE 2 RAD HI and VAC SYS DISCH RAD HI will sound.
Rising MU flow with lowering MUT level and PZR level will be observed. The SRO will implement DB-OP-02531, Steam Generator Tube Leak. The ATC will evaluate the leak to be greater than 50 gpm and the SRO will route to B-OP-02000, Section 8, SG Tube Rupture
.
The BOP will place HPI/LPI/MU in service and the ATC will reduce power to SG low level limits. The BOP will transfer steam loads from the Turbine to the Turbine Bypass Valves. When load is less than 50 MWe the ATC will trip the Reactor.
When the reactor is tripped the remaining MFPT will trip and Auxiliary Feedwater will fail to automatically actuate. The BOP will depress the SFRCS pushbuttons to initiate AFW and isolate Main Feedwater and Main Steam (CT-10). The ATC will be directed to reduce RCS pressure to minimum subcooling margin. When this is attempted it will be recognized that the PZR spray valve is failed closed and the alternate PZR Vent Line method will be used. The ATC will control HPI to maintain RCS inventory (CT-5). When the pressure reduction has begun the scenario can be terminated, at the Lead Evaluators discretion.
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 1 Page 3 of Event
Description:
Perform DB
-SS-04052, MFPT 1 Stop Valves Periodic Test Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 3 of 16 FENOC Facsimile Rev. 1 Event 1: Perform DB
-SS-04052, MFPT 1 Stop Valves Periodic Test SRO Direct BOP to perform MFPT 1 Stop Valves Periodic Test BOP Verify Local Operator at MFPT 1 BOP Test HP Stop Valve BOP Depress and hold HIS793, HP STOP VALVE TEST CLOSE Check HIS793 Green light ON, Red light OFF Booth Cue Role play as Equipment Operator
- "Observed MFPT 1 HP Stop Valve stroked smoothly" BOP Release HIS793, HP STOP VALVE TEST CLOSE Check HIS793 Red light ON, Green light OFF BOP Test LP Stop Valve BOP Depress and hold HIS795, LP STOP VALVE TEST CLOSE Check amber TEST light ON, HIS Red light OFF Booth Cue Role play as Equipment Operator
- "Observed MFPT 1 L P Stop Valve stroked smoothly" BOP Release HIS795, LP STOP VALVE TEST CLOSE Check amber TEST light OFF, HIS Red light ON On Lead Evaluator's discretion, insert Event 2
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 2 Page 4 of Event
Description:
PORV Leakage Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 4 of 16 FENOC Facsimile Rev. 1 Event 2: PORV Leakage Indications Available:
4-2-D, PZR QUENCH TANK PRESS HI 4-4-C, HOT LEG PRESS LO T773, RC PRZR PWR RLF OUT TEMP, RC12
-1 rising RCS pressure lowering ATC Refer to DB-OP-02004, Reactor Coolant Alarm Panel 4 Annunciators Procedure CREW Recognize RCS pressure is lowering
- CREW Diagnose PORV leakage due to computer point T773, RC PRZR PWR RLF OUT TEMP, RC12
-OP-02513, Pressurizer Systems Abnormal Operating Procedure SRO Direct closure of RC11, PORV Block valve
- CRITICAL TASK ATC Close PORV Block Close RC11 using HISRC11, PORV BLOCK CREW Determine RCS leakage has stopped SRO Refer to Tech Spec 3.4.11 Pressurizer Pilot Operated Relief Valve (PORV)
Declare PORV INOPERABLE Enter 3.4.11 Condition A Remove power from PORV Block valve SRO Direct open breaker BE1602 for Pressurizer Pilot Operated Relief Valve (PORV) Block Valve
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 2 Page 5 of Event
Description:
PORV Leakage Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 5 of 16 FENOC Facsimile Rev. 1 Event 2: PORV Leakage
- continued Booth Cue Role play opening BE1602 for PORV Block Valve SRO Refer to Tech Specs 3.4.13, RCS Operational Leakage SRO Refer to TRM 8.4.4, Reactor Coolant System Vents Note DNBR Tech Spec 3.4.1 may be entered and exited during this scenario On Lead Evaluator's discretion, proceed to Event 3
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 3 Page 6 of Event
Description:
Selected Thot RTD transmitter (TT RC3A1) slowly fails high Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 6 of 16 FENOC Facsimile Rev. 1 Event 3: Selected Thot RTD transmitter (TT RC3A1) slowly fails high Indications Available:
4-2-B, HOT LEG TEMP HIGH 14-2-F ICS ULD TRBL 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 CREW Recognize ICS is reducing Rx power to lower Tave to 582°F SRO Implement DB-OP-02526, Primary to Secondary Heat Transfer Upset ATC Place Rod Control Panel in Manual and adjust power BOP Place BOTH FEEDWATER DEMAND H/A Stations in HAND Maintain Feedwater flow matched with Plant power BOP Check DEHC Load Control Center is in Automatic AND controlling Turbine Header Pressure 830
- 930 psig ATC Check RCS pressure between 2105 and 2205 psig ATC Place SG/RX Demand in Hand Place Reactor Demand in Hand BOP Place SG Load Ratio Note DNBR Tech Spec 3.4.1 may be entered and exited during this scenario Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 3 Page 7 of Event
Description:
Selected Thot RTD transmitter (TT RC3A1) slowly fails high Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 7 of 16 FENOC Facsimile Rev. 1 Event 3: Selected Thot RTD transmitter (TT RC3A1) slowly fails high
- continued SRO Assign manual control responsibilities and control bands:
Insert or withdraw Control Rods to maintain Reactor Power within 1% of current power level Adjust FW Flow to maintain RCS Tave within 2°F of current temperature Adjust FW Flow to maintain RCS cold leg differential temperature within 2 degrees of zero Maintain Turbine Header Pressure within 10 psig of current pressure SRO Refer to DB
-OP-06407, Non
-Nuclear Instrumentation System Operating Procedure for transferring NNI Instrument Inputs to ICS Hand/Auto Stations ATC Compare Hot Leg Temperature Indicators TI RC3A1 and T1 RC3B1 on RC Panel C5718 Select the good instrument TTRC3A3 Reset ICS Mismatch alarm14 E in cabinet area per DB-OP-02014, Panel 14 Annunciator alarms ATC/BOP Return Tave to 582
°F Adjust FW Loop Demands Adjust Rod positions SRO Implement DB
-OP-02526 Att. 1, Return ICS Stations to AUTO ATC 1. Place Rod Control Panel in AUTO
- 2. Place Reactor Demand Station in AUTO BOP Place BOTH FEEDWATER DEMAND H/A Stations in AUTO ATC Place SG/RX Demand in AUTO On Lead Evaluator's discretion, proceed to Event 4
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 4 Page 8 of Event
Description:
MFPT Low Oil pressure
- trip MFPT Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 8 of 16 FENOC Facsimile Rev. 1 Event 4: MFPT Low Oil pressure
- trip MFPT Indications Available:
10-3-D, MFPT 2 LUBE OIL TK LVL BOP Implement DB
-OP-02010, Feedwater Alarm Panel 10 Annunciators BOP Dispatch Equipment Operator to investigate MFPT 2 Booth Cue Role play as Local Operator: "MFP 2 bearing oil header is spraying oil and MFP is making a squealing noise
". SRO Direct trip MFPT 2 immediately OR Direct power reduction to 55% to remove MFPT 2 from service Refer to DB
-OP-02504, Rapid Shutdown ATC If directed to reduce power per Attachment 1, DB
-OP-02504: At the LOAD CONTROL panel, set the rate of change specified by the SRO Select the target RTP determined by the SRO BOP As directed by the SRO Trip MFPT 2 using HS798 Turbine Trip SRO IF an ICS Runback occurs, THEN REFER TO DB
-OP-06401, Integrated Control System Operating Procedure BOP If desired Scenario can continue while MFPT coasts down Lockout MFP 2 oil pumps SM If asked, refer to RA
-EP-02850 for Hazardous Waste Spill On Lead Evaluator's discretion, proceed to Event 5
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 5 Page 9 of Event
Description:
Dropped Control Rod Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 9 of 16 FENOC Facsimile Rev. 1 Event 5: Dropped Control Rod Indications Available:
Annunciator 5 E, CRD LCO Annunciator 5 E, CRD ASYMETRIC ROD Control Rod 5
-8 Rod Bottom light ON CREW Recognize that a single Control Rod has inserted into the core SRO Implement DB
-OP-02516, CRD Malfunctions SRO Direct Power reduction to 33% at 3% RTP per minute ATC Set ULD MAX LOAD LIMIT to 33% RTP Set ULD Rate of Change to 3% RTP per minute SRO Refer to DB
-OP-02504, Rapid Shutdown ATC If annunciator 4 E, PZR LEVEL LO alarms due to the dropped rod Tave transient then reduce MU32 (PZR level control) set point to approximately 180 inches CREW Monitor Reactor Power to confirm power is being reduced at approximately the expected rate SRO IF Pressurizer Level is greater than 228 inches, then refer to Technical Specification 3.4.9 Condition A ATC Monitor Regulating Rod Insertion Limits during the Shutdown per Technical Specification 3.2.1 BOP Perform Attachment 6, Balance of Plant Actions for Rapid Shutdown Stop LPFW Drain Pumps Establish one Condensate Pump in operation Place S/G Load Ratio H/A in Hand
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 5 Page 10 of Event
Description:
Dropped Control Rod Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 10 of 16 FENOC Facsimile Rev. 1 Event 5: Dropped Control Rod
- continued BOP Notify Equipment Operators to commence Attachment 15, Field Actions for Rapid Shutdown SRO Notify the Shift Man ager to make notifications SRO Notify Reactor Engineering SRO Request I&C to investigate SRO Refer to DB
-OP-02516 Attachment 3 to determine Tech Spec applicability
- Tech Spec. 3.1.4 for the dropped rod, Condition A, verify SDM is within limits within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> On Lead Evaluator's discretion, proceed to Event 6
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 6 Page 11 of Event
Description:
Steam Generator Tube Rupture Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 11 of 16 FENOC Facsimile Rev. 1 Event 6: Steam Generator Tube Rupture Indications Available:
12-1-B MN STM LINE 2 RAD HI 9-4-A VAC SYS DISCH RAD HI High activity on condenser off
-gas radiation monitors High activity on either main steam line radiation monitor Increasing Makeup flow CREW Recognize indications of a tube leak SRO Implement DB
-OP-02531, Steam Generator Tube Leak ATC Calculate the leak rate using Attachment 1, Steam Generator Tube Leak Rate Calculation
(~300 gpm)
-OP-02000, SFAS, RPS, SFRCS Trip or SG Tube Rupture, Section 8 ATC Monitor Pressurizer level Anytime Pressurizer level is
<100 inches
- trip Reactor SRO Notify the Shift Manager to refer to RA
-EP-01500, Emergency Classification
- Critical Task BOP Implement Attachment 8, Place MU/HPI/LPI in Service Start/Verify running both CCW Pumps *Start/Verify running both HPI Pumps
- Verify open HP 2A, HP 2B, HP 2C and HP 2D Start both LPI Pumps Open DH 64 and DH 63 Transfer MU Pump suctions to the BWST Standby Makeup pump does not start ATC If Pressurizer <200 inches isolate Letdown
- Close MU2B
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 6 Page 12 of Event
Description:
Steam Generator Tube Rupture Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 12 of 16 FENOC Facsimile Rev. 1 Event 6: Steam Generator Tube Rupture
- continued ATC Place SG/RX in Hand and reduce power to place both SGs on low level limits
(~ 24% Power)
Booth Cue If called to investigate Makeup pump 1 failure to start report overcurrent relay "breaker AC105 overcurrent relay actuated" SRO Direct Chemistry to perform Attachment 2 SRO Direct Radiation Protection to perform Attachment 3 SRO Direct an Equipment Operator/Field Supervisor to perform ATC Trip the reactor prior to Pressurizer level going below 100 inches or when less than 50 MWE BOP When both SGs on low level limits Place Turbine Bypass valves in Hand Reduce Generator load to less than 50 MWe ATC Trip Reactor BOP Place Turbine Bypass Valves in Auto ATC Perform DB
-OP-02000 Immediate Actions Manually trip the reactor Verify power decreasing in the intermediate range Manually trip the turbine
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 7 & 8 Page 13 of Event
Description:
Loss of all Feedwater and Pressurizer Spray Valve fails closed Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 13 of 16 FENOC Facsimile Rev. 1 Event 7: Loss of Main Feedwater
- SFRCS fails to actuate Event 8: Pressurizer Spray valve fails to open for pressure reduction CREW Implement Specific Rules
- Critical Task BOP Recognize Main Feedwater is lost and SFRCS is not actuated Manually Initiate and Isolate SFRCS CREW Check for Symptoms SRO Route to section 8 for SG Tube Rupture BOP Verify Attachment 8 is complete ATC If Pressurizer Level is less than 40 inches:
Lock MU Pump suctions on the BWST Isolate Letdown Verify Pressurizer heaters are off ATC Verify Pressurizer level controller set at 100 inches SRO Verify DB
-OP-02531 Attachments are in progress Direct Chemistry to perform Attachment 2 Direct Radiation Protection to perform Attachment 3 Direct an Equipment Operator/Field Supervisor to perform Attachment 4 ATC Turn off all Pressurizer heaters ATC When directed use Pressurizer Spray to reduce RCS pressure
- Recognize the Spray valve would not open SRO Route to step in Section 8.0 for using the Pressurizer Vent for RCS pressure reduction Event 8: Pressurizer Spray valve fails to open for pressure reduction
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 7 & 8 Page 14 of Event
Description:
Loss of all Feedwater and Pressurizer Spray Valve fails closed Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 14 of 16 FENOC Facsimile Rev. 1 ATC Start the Quench Tank Circ Pump ATC Block SFAS low RCS pressure trips when Block Permits light *Critical Task ATC Reduce RCS pressure :
Pressurizer Vent Line Method
- Open RC 200
- Open RC 239A Cycle RC 239A and Pressurizer Heaters to control RCS Pressure *Critical Task ATC Throttle High Pressure Injection Control Pressurizer level by controlling MU and HPI When pressure reduction has begun the Scenario can be terminated
NUREG-1021, R9 Supp. 1 Page 15 of 16 FENOC Facsimile Rev. 1 Justification for Critical Tasks A. Establish FW flow and feed SGs (CT-10) When the Reactor is tripped the remaining Main Feedwater Pump will trip resulting in a loss of Main Feedwater. SFRCS will fail to automatically isolate and actuate Auxiliary Feedwater on Main Feedwater reverse differential pressure as required resulting in a loss of all feedwater. Manual actuation of the SFRCS pushbuttons will be required to restore secondary heat removal B. Control High Pressure Injection (CT-5) A Steam Generator Tube Rupture will require High Pressure Injection to be placed in service and throttled to prevent violating the RPV P
-T Limit by maintaining RCS inventory and minimum subcooling margin C. Close RC11, PORV Block Valve (Post Event Emergent Critical Task)
PORV (RC2A) leakage will require the closure of RC11 PORV Block Valve to prevent an uncontrolled depressurization of the Reactor Coolant System, over
-pressurization of the Pressurizer Quench Tank, and subsequent radioactive release to the Containment.
NUREG-1021, R9 Supp. 1 Page 16 of 16 FENOC Facsimile Rev. 1 SIMULATOR SETUP INFORMATION
- 1. Simulator Setup a) 70% Power b) RCP 1-1 Out of Service c) Emergency Diesel Generator 1 Out of Service d) SFRCS Failure to auto trip on loss of Main Feedwater e) Makeup Pump 1 fails to start f) PZR Spray valve failed closed on Rx trip 2. Procedures a) DB-SS-04052, MFPT 1 Stop Valves Periodic Test b) DB-OP-02004, Reactor Coolant Alarm Panel 4 Annunciators Procedure c) DB-OP-02513, Pressurizer Systems Abnormal Operation Procedure d) DB-OP-02526, Primary to Secondary Heat Transfer Upset e) DB-OP-06407, Non-Nuclear Instrumentation System Operating Procedure f) DB-OP-02010, Feedwater Alarm Panel 10 Annunciators g) DB-OP-02504, Rapid Shutdown h) OP-06401, Integrated Control System Operating Procedure i) DB-OP-02516, CRD Malfunctions j) DB-OP-02531, Steam Generator Tube Leak k) DB-OP-02000, RPS, SFAS, SFRCS Trip, or Steam Generator Tube Rupture
- 2) For Simulator Instructor:
a) None Appendix D Scenario Outline Form ES-D-1 NUREG-1021, R9 Supp. 1 Page 1 of 16 FENOC Facsimile AG Facility:
Davis-Besse Scenario No.:
3 Op Test No.:
NRC 2015 Examiners:
Operators:
SRO ATC BOP Initial Conditions:
70% Power RCP 1-1 OOS EDG 1 OOS Turnover: Maintain 70% Power Planned: Perform MFPT 1 Stop Valve Test, DB
-SS-04052 Critical tasks:
-5) 3. Close RC11 PORV Block Valve (Emergent)
Event No. Malf. No. Event Type*
Event Description 1 N-BOP/SRO MFPT 1 Stop Valve Test, DB
-SS-04052 2 C-ATC/SRO (TS) PORV Leakage 3 I-ATC/BOP SRO RCS Hot Leg RTD slowly drifts HI SEE NOTE BELOW 4 C-BOP MFPT Low Oil pressure
- trip MFPT SEE NOTE BELOW 5 R-ATC SRO (TS) Dropped Rod
- Power reduction SEE NOTE BELOW 6 Major SG Tube Rupture
- trip Reactor 7 C-BOP/SRO Loss of Feedwater
-SFRCS fails auto actuation 8 C-ATC/SRO PZR Spray valve fails closed NOTE - Events 3, 4, and 5 were not completed due to premature trip of the reactor caused by applicants' failure to isolate the leaking PORV (Event 2)
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
Scenario Event Summary NUREG-1021, R9 Supp. 1 Page 2 of 16 FENOC Facsimile AG DAVIS-BESSE 2015 NRC SCENARIO 3 The Crew will take the watch with power at 70% with 3 RCPs in operation. Following turnover the BOP will perform DB
-SS-04052, MFPT 1 Stop Valve Test.
On cue from the Lead Evaluator, a leak will be introduced on the PZR Pressure Operated Relief Valve (PORV). The crew will respond to computer and Panel 9 annunciator alarms and isolate the PORV IAW DB
-OP-02513, PRESSURIZER SYSTEM ABNORMAL OPERATION. The SRO will enter the applicable TS for the PORV
. When the SRO has declared the TS for the PORV, the Lead Evaluator will cue the selected Thot RTD transmitter (TT RC3A1) to slowly fail high. HOT LEG TEMP HIGH annunciator alarm will sound and the Integrated Control System (ICS) will begin reducing power to lower Tave. The ATC will place the Rod Control Panel in manual and the BOP will place Feedwater Loop Demands in manual to stabilize the plant. The good instrument will be selected and Tave will be restored to 582
°F. Rod Control Panel and Feedwater Loop Demand control stations will then be returned to AUTO.
When ICS is returned to Auto the Lead Evaluator will cue the MFPT oil leak. MFPT 2 LUBE OIL TK LVL will alarm. The BOP will implement DB
-OP-02010, Feedwater Alarm Panel 10 Annunciators. An Equipment Operator will report MFP 2 bearing oil header spraying oil and the pump making a squealing sound. The SRO will direct tripping the MFPT and ICS will run the plant back to 55% power OR direct power reduction to 55% and then tripping pump.
After the MFPT is removed from service the Lead Evaluator will cue the dropped control rod. Alarms CRD LCO and CRD ASYMETRIC ROD will sound and a Rod bottom light will be ON. The SRO will implement DB
-OP-02516, CRD Malfunctions. The ATC will be directed to reduce power to 33% per DB
-OP-02504, Rapid Shutdown. The SRO will enter the applicable TS for the Inoperable control rod.
After the TS has been declared for the Inoperable control rod the Lead Evaluator will cue the Steam Generator Tube Rupture. Alarms MN STM LINE 2 RAD HI and VAC SYS DISCH RAD HI will sound.
Rising MU flow with lowering MUT level and PZR level will be observed. The SRO will implement DB-OP-02531, Steam Generator Tube Leak. The ATC will evaluate the leak to be greater than 50 gpm and the SRO will route to B-OP-02000, Section 8, SG Tube Rupture
. The BOP will place HPI/LPI/MU in service and the ATC will reduce power to SG low level limits. The BOP will transfer steam loads from the Turbine to the Turbine Bypass Valves. When load is less than 50 MWe the ATC will trip the Reactor.
When the reactor is tripped the remaining MFPT will trip and Auxiliary Feedwater will fail to automatically actuate. The BOP will depress the SFRCS pushbuttons to initiate AFW and isolate Main Feedwater and Main Steam (CT-10).
The ATC will be directed to reduce RCS pressure to minimum subcooling margin. When this is attempted it will be recognized that the PZR spray valve is failed closed and the alternate PZR Vent Line method will be used. The ATC will control HPI to maintain RCS inventory (CT-5). When the pressure reduction has begun the scenario can be terminated, at the Lead Evaluators discretion.
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 1 Page 3 of Event
Description:
Perform DB
-SS-04052, MFPT 1 Stop Valves Periodic Test Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 3 of 16 FENOC Facsimile Rev. 1 Event 1: Perform DB
-SS-04052, MFPT 1 Stop Valves Periodic Test SRO Direct BOP to perform MFPT 1 Stop Valves Periodic Test BOP Verify Local Operator at MFPT 1 BOP Test HP Stop Valve BOP Depress and hold HIS793, HP STOP VALVE TEST CLOSE Check HIS793 Green light ON, Red light OFF Booth Cue Role play as Equipment Operator
- "Observed MFPT 1 HP Stop Valve stroked smoothly" BOP Release HIS793, HP STOP VALVE TEST CLOSE Check HIS793 Red light ON, Green light OFF BOP Test LP Stop Valve BOP Depress and hold HIS795, LP STOP VALVE TEST CLOSE Check amber TEST light ON, HIS Red light OFF Booth Cue Role play as Equipment Operator
- "Observed MFPT 1 L P Stop Valve stroked smoothly" BOP Release HIS795, LP STOP VALVE TEST CLOSE Check amber TEST light OFF, HIS Red light ON On Lead Evaluator's discretion, insert Event 2
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 2 Page 4 of Event
Description:
PORV Leakage Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 4 of 16 FENOC Facsimile Rev. 1 Event 2: PORV Leakage Indications Available:
4-2-D, PZR QUENCH TANK PRESS HI 4-4-C, HOT LEG PRESS LO T773, RC PRZR PWR RLF OUT TEMP, RC12
-1 rising RCS pressure lowering ATC Refer to DB-OP-02004, Reactor Coolant Alarm Panel 4 Annunciators Procedure CREW Recognize RCS pressure is lowering
- CREW Diagnose PORV leakage due to computer point T773, RC PRZR PWR RLF OUT TEMP, RC12
-OP-02513, Pressurizer Systems Abnormal Operating Procedure SRO Direct closure of RC11, PORV Block valve
- CRITICAL TASK ATC Close PORV Block Close RC11 using HISRC11, PORV BLOCK CREW Determine RCS leakage has stopped SRO Refer to Tech Spec 3.4.11 Pressurizer Pilot Operated Relief Valve (PORV)
Declare PORV INOPERABLE Enter 3.4.11 Condition A Remove power from PORV Block valve SRO Direct open breaker BE1602 for Pressurizer Pilot Operated Relief Valve (PORV) Block Valve
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 2 Page 5 of Event
Description:
PORV Leakage Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 5 of 16 FENOC Facsimile Rev. 1 Event 2: PORV Leakage
- continued Booth Cue Role play opening BE1602 for PORV Block Valve SRO Refer to Tech Specs 3.4.13, RCS Operational Leakage SRO Refer to TRM 8.4.4, Reactor Coolant System Vents Note DNBR Tech Spec 3.4.1 may be entered and exited during this scenario On Lead Evaluator's discretion, proceed to Event 3
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 3 Page 6 of Event
Description:
Selected Thot RTD transmitter (TT RC3A1) slowly fails high Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 6 of 16 FENOC Facsimile Rev. 1 Event 3: Selected Thot RTD transmitter (TT RC3A1) slowly fails high DELETED Indications Available:
4-2-B, HOT LEG TEMP HIGH 14-2-F ICS ULD TRBL 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 CREW Recognize ICS is reducing Rx power to lower Tave to 582°F SRO Implement DB
-OP-02526, Primary to Secondary Heat Transfer Upset ATC Place Rod Control Panel in Manual and adjust power BOP Place BOTH FEEDWATER DEMAND H/A Stations in HAND Maintain Feedwater flow matched with Plant power BOP Check DEHC Load Control Center is in Automatic AND controlling Turbine Header Pressure 830
- 930 psig ATC Check RCS pressure between 2105 and 2205 psig ATC Place SG/RX Demand in Hand Place Reactor Demand in Hand BOP Place SG Load Ratio Note DNBR Tech Spec 3.4.1 may be entered and exited during this scenario Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 3 Page 7 of Event
Description:
Selected Thot RTD transmitter (TT RC3A1) slowly fails high Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 7 of 16 FENOC Facsimile Rev. 1 Event 3: Selected Thot RTD transmitter (TT RC3A1) slowly fails high
- continued SRO Assign manual control responsibilities and control bands:
Insert or withdraw Control Rods to maintain Reactor Power within 1% of current power level Adjust FW Flow to maintain RCS Tave within 2°F of current temperature Adjust FW Flow to maintain RCS cold leg differential temperature within 2 degrees of zero Maintain Turbine Header Pressure within 10 psig of current pressure SRO Refer to DB
-OP-06407, Non
-Nuclear Instrumentation System Operating Procedure for transferring NNI Instrument Inputs to ICS Hand/Auto Stations ATC Compare Hot Leg Temperature Indicators TI RC3A1 and T1 RC3B1 on RC Panel C5718 Select the good instrument TTRC3A3 Reset ICS Mismatch alarm14 E in cabinet area per DB-OP-02014, Panel 14 Annunciator alarms ATC/BOP Return Tave to 582
°F Adjust FW Loop Demands Adjust Rod positions SRO Implement DB
-OP-02526 Att. 1, Return ICS Stations to AUTO ATC 1. Place Rod Control Panel in AUTO
- 2. Place Reactor Demand Station in AUTO BOP Place BOTH FEEDWATER DEMAND H/A Stations in AUTO ATC Place SG/RX Demand in AUTO On Lead Evaluator's discretion, proceed to Event 4
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 4 Page 8 of Event
Description:
MFPT Low Oil pressure
- trip MFPT Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 8 of 16 FENOC Facsimile Rev. 1 Event 4: MFPT Low Oil pressure
- trip MFPT DELETED Indications Available:
10-3-D, MFPT 2 LUBE OIL TK LVL BOP Implement DB
-OP-02010, Feedwater Alarm Panel 10 Annunciators BOP Dispatch Equipment Operator to investigate MFPT 2 Booth Cue Role play as Local Operator: "MFP 2 bearing oil header is spraying oil and MFP is making a squealing noise
". SRO Direct trip MFPT 2 immediately OR Direct power reduction to 55% to remove MFPT 2 from service Refer to DB
-OP-02504, Rapid Shutdown ATC If directed to reduce power per Attachment 1, DB
-OP-02504: At the LOAD CONTROL panel, set the rate of change specified by the SRO Select the target RTP determined by the SRO BOP As directed by the SRO Trip MFPT 2 using HS798 Turbine Trip SRO IF an ICS Runback occurs, THEN REFER TO DB
-OP-06401, Integrated Control System Operating Procedure BOP If desired Scenario can continue while MFPT coasts down Lockout MFP 2 oil pumps SM If asked, refer to RA
-EP-02850 for Hazardous Waste Spill On Lead Evaluator's discretion, proceed to Event 5
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 5 Page 9 of Event
Description:
Dropped Control Rod Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 9 of 16 FENOC Facsimile Rev. 1 Event 5: Dropped Control Rod DELETED Indications Available:
Annunciator 5 E, CRD LCO Annunciator 5 E, CRD ASYMETRIC ROD Control Rod 5
-8 Rod Bottom light ON CREW Recognize that a single Control Rod has inserted into the core SRO Implement DB
-OP-02516, CRD Malfunctions SRO Direct Power reduction to 33% at 3% RTP per minute ATC Set ULD MAX LOAD LIMIT to 33% RTP Set ULD Rate of Change to 3% RTP per minute SRO Refer to DB
-OP-02504, Rapid Shutdown ATC If annunciator 4 E, PZR LEVEL LO alarms due to the dropped rod Tave transient then reduce MU32 (PZR level control) set point to approximately 180 inches CREW Monitor Reactor Power to confirm power is being reduced at approximately the expected rate SRO IF Pressurizer Level is greater than 228 inches, then refer to Technical Specification 3.4.9 Condition A ATC Monitor Regulating Rod Insertion Limits during the Shutdown per Technical Specification 3.2.1 BOP Perform Attachment 6, Balance of Plant Actions for Rapid Shutdown Stop LPFW Drain Pumps Establish one Condensate Pump in operation Place S/G Load Ratio H/A in Hand
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 5 Page 10 of Event
Description:
Dropped Control Rod Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 10 of 16 FENOC Facsimile Rev. 1 Event 5: Dropped Control Rod
- continued BOP Notify Equipment Operators to commence Attachment 15, Field Actions for Rapid Shutdown SRO Notify the Shift Man ager to make notifications SRO Notify Reactor Engineering SRO Request I&C to investigate SRO Refer to DB
-OP-02516 Attachment 3 to determine Tech Spec applicability
- Tech Spec. 3.1.4 for the dropped rod, Condition A, verify SDM is within limits within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> On Lead Evaluator's discretion, proceed to Event 6
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 6 Page 11 of Event
Description:
Steam Generator Tube Rupture Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 11 of 16 FENOC Facsimile Rev. 1 Event 6: Steam Generator Tube Rupture Indications Available:
12-1-B MN STM LINE 2 RAD HI 9-4-A VAC SYS DISCH RAD HI High activity on condenser off
-gas radiation monitors High activity on either main steam line radiation monitor Increasing Makeup flow CREW Recognize indications of a tube leak SRO Implement DB
-OP-02531, Steam Generator Tube Leak ATC Calculate the leak rate using Attachment 1, Steam Generator Tube Leak Rate Calculation
(~300 gpm)
-OP-02000, SFAS, RPS, SFRCS Trip or SG Tube Rupture, Section 8 ATC Monitor Pressurizer level Anytime Pressurizer level is
<100 inches
- trip Reactor SRO Notify the Shift Manager to refer to RA
-EP-01500, Emergency Classification
- Critical Task BOP Implement Attachment 8, Place MU/HPI/LPI in Service Start/Verify running both CCW Pumps *Start/Verify running both HPI Pumps
- Verify open HP 2A, HP 2B, HP 2C and HP 2D Start both LPI Pumps Open DH 64 and DH 63 Transfer MU Pump suctions to the BWST Standby Makeup pump does not start ATC If Pressurizer <200 inches isolate Letdown
- Close MU2B
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 6 Page 12 of Event
Description:
Steam Generator Tube Rupture Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 12 of 16 FENOC Facsimile Rev. 1 Event 6: Steam Generator Tube Rupture
- continued ATC Place SG/RX in Hand and reduce power to place both SGs on low level limits
(~ 24% Power)
Booth Cue If called to investigate Makeup pump 1 failure to start report overcurrent relay "breaker AC105 overcurrent relay actuated" SRO Direct Chemistry to perform Attachment 2 SRO Direct Radiation Protection to perform Attachment 3 SRO Direct an Equipment Operator/Field Supervisor to perform ATC Trip the reactor prior to Pressurizer level going below 100 inches or when less than 50 MWE BOP When both SGs on low level limits Place Turbine Bypass valves in Hand Reduce Generator load to less than 50 MWe ATC Trip Reactor BOP Place Turbine Bypass Valves in Auto ATC Perform DB
-OP-02000 Immediate Actions Manually trip the reactor Verify power decreasing in the intermediate range Manually trip the turbine
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 7 & 8 Page 13 of Event
Description:
Loss of all Feedwater and Pressurizer Spray Valve fails closed Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 13 of 16 FENOC Facsimile Rev. 1 Event 7: Loss of Main Feedwater
- SFRCS fails to actuate Event 8: Pressurizer Spray valve fails to open for pressure reduction CREW Implement Specific Rules
- Critical Task BOP Recognize Main Feedwater is lost and SFRCS is not actuated Manually Initiate and Isolate SFRCS CREW Check for Symptoms SRO Route to section 8 for SG Tube Rupture BOP Verify Attachment 8 is complete ATC If Pressurizer Level is less than 40 inches:
Lock MU Pump suctions on the BWST Isolate Letdown Verify Pressurizer heaters are off ATC Verify Pressurizer level controller set at 100 inches SRO Verify DB
-OP-02531 Attachments are in progress Direct Chemistry to perform Attachment 2 Direct Radiation Protection to perform Attachment 3 Direct an Equipment Operator/Field Supervisor to perform Attachment 4 ATC Turn off all Pressurizer heaters ATC When directed use Pressurizer Spray to reduce RCS pressure
- Recognize the Spray valve would not open SRO Route to step in Section 8.0 for using the Pressurizer Vent for RCS pressure reduction Event 8: Pressurizer Spray valve fails to open for pressure reduction
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
3 Event # 7 & 8 Page 14 of Event
Description:
Loss of all Feedwater and Pressurizer Spray Valve fails closed Time Position Applicant's Actions or Behavior NUREG-1021, R9 Supp. 1 Page 14 of 16 FENOC Facsimile Rev. 1 ATC Start the Quench Tank Circ Pump ATC Block SFAS low RCS pressure trips when Block Permits light *Critical Task ATC Reduce RCS pressure :
Pressurizer Vent Line Method
- Open RC 200
- Open RC 239A Cycle RC 239A and Pressurizer Heaters to control RCS Pressure *Critical Task ATC Throttle High Pressure Injection Control Pressurizer level by controlling MU and HPI When pressure reduction has begun the Scenario can be terminated
NUREG-1021, R9 Supp. 1 Page 15 of 16 FENOC Facsimile Rev. 1 Justification for Critical Tasks A. Establish FW flow and feed SGs (CT-10) When the Reactor is tripped the remaining Main Feedwater Pump will trip resulting in a loss of Main Feedwater. SFRCS will fail to automatically isolate and actuate Auxiliary Feedwater on Main Feedwater reverse differential pressure as required resulting in a loss of all feedwater. Manual actuation of the SFRCS pushbuttons will be required to restore secondary heat removal B. Control High Pressure Injection (CT-5) A Steam Generator Tube Rupture will require High Pressure Injection to be placed in service and throttled to prevent violating the RPV P
-T Limit by maintaining RCS inventory and minimum subcooling margin C. Close RC11, PORV Block Valve (Post Event Emergent Critical Task)
PORV (RC2A) leakage will require the closure of RC11 PORV Block Valve to prevent an uncontrolled depressurization of the Reactor Coolant System, over
-pressurization of the Pressurizer Quench Tank, and subsequent radioactive release to the Containment.
NUREG-1021, R9 Supp. 1 Page 16 of 16 FENOC Facsimile Rev. 1 SIMULATOR SETUP INFORMATION 1. Simulator Setup a) 70% Power b) RCP 1-1 Out of Service c) Emergency Diesel Generator 1 Out of Service d) SFRCS Failure to auto trip on loss of Main Feedwater e) Makeup Pump 1 fails to start f) PZR Spray valve failed closed on Rx trip
- 2. Procedures a) DB-SS-04052, MFPT 1 Stop Valves Periodic Test b) DB-OP-02004, Reactor Coolant Alarm Panel 4 Annunciators Procedure c) DB-OP-02513, Pressurizer Systems Abnormal Operation Procedure d) DB-OP-02526, Primary to Secondary Heat Transfer Upset e) DB-OP-06407, Non
-Nuclear Instrumentation System Operating Procedure f) DB-OP-02010, Feedwater Alarm Panel 10 Annunciators g) DB-OP-02504, Rapid Shutdown h) OP-06401, Integrated Control System Operating Procedure i) DB-OP-02516, CRD Malfunctions j) DB-OP-02531, Steam Generator Tube Leak k) DB-OP-02000, RPS, SFAS, SFRCS Trip, or Steam Generator Tube Rupture
- 2) For Simulator Instructor:
a) None Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 10 Page 1 of 14 FENOC Facsimile AG Facility:
Davis-Besse Scenario No.:
4 Op Test No.:
NRC 2015 Examiners:
Operators:
SRO ATC BOP Initial Conditions:
2% power MFP 2 maintaining 800
-1000 RPM 2 TBVs per side are isolated Turnover:
Plant was shut down for bushing replacement on the Main Transformer.
Plant startup per DB
-OP-06901, complete through Step 3.25 Reactor startup is in progress and currently at 2%. Mode 1 checklist is complete Planned: Continue a plant startup per DB
-OP-06901, starting at Step 3.26
. Raise Reactor power to 4% in preparation for mode change Place MFP 2 in service and continue the power rise Critical tasks:
- 1. Initiate LPI (CT-4) 2. Trip All Reactor Coolant Pumps (CT
-1) 3. Implementation of CTRM habitability (CT
-27) Event No. Malf. No. Event Type*
Event Description 1 N-BOP/SRO Transfer from Motor Driven Feed Pump to MFP 2 Event 1 deleted since crew completed a Normal Evolution as part of Scenario 3.
2 R-ATC/SRO Increase power to 4%
3 C-BOP/SRO (TS) Service Water Pump Trip 4 C-ATC/SRO MU32, PZR LVL Control valve, fails open 5 I-BOP/SRO SG 2 Pressure Instrument Fails High 6 C-ATC/SRO (TS) RCS Leak in Containment 7 M-ALL Large LOCA 8 C-BOP/SRO C-ATC/SRO CCW Pump fails to start LPI Pumps 1 & 2 fail to start
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
Scenario Event Summary NUREG-1021, Revision 10 Page 2 of 14 FENOC Facsimile AG DAVIS-BESSE 2015 NRC SCENARIO 4 The scenario begins with the plant in Mode 2 ~2% power plant startup in progress. . Aux Boiler is in service. MFP 2 is ready to place in service, currently maintaining 800
-1000 RPM. 2 TBVs per side are isolated. DB
-OP-06901 is completed up to step 3.27. The BOP will place MFP 2 in service and The ATC will raise Reactor Power while controlling heatup rate at less than 35°F/Hr
. The BOP will place the Anticipatory Reactor Trip System (ARTS) test toggle switches for the Operating Main Feed Pump in OPERATE.
Once power has been raised to 4% and stabilized the Lead Evaluator can cue the Service Water Pump supplying secondary loads to trip. SW HDR PRESS alarm will sound and the SRO will implement D B-OP-02511, Loss of Service Water Pumps/ System. The BOP will isolate Service Water (SW) to that train Containment Air Cooler (CAC) and verify Circulating Water aligned to cool secondary loads. The SRO will enter the applicable TS and direct the spare SW Pump to be placed in service. The BOP will restore secondary loads and restore CAC SW flow.
After Service Water is restored to normal, the Lead Evaluator will cue Normal Makeup Line, MU32, PZR level control valve to fail open. MU FLOW HI TRN 2 will alarm. The ATC will need to isolate MU32 and the SRO will implement DB-OP-02512 Makeup and Purification System Malfunctions for loss of normal makeup and place the alternate injection line in service.
When the alternate injection line is placed in service and PZR level is restored
, the Lead Evaluator will cue the SG 2 pressure transmitter PT SP12A2 failing high, resulting in SG2 TBVs and AVV opening. The BOP will close the AVV, isolate the in service TBV, select an alternate pressure transmitter and restore the TBV and AVV to service.
With the alternate SG 2 pressure transmitter selected and the plant stabilized the Lead Evaluator will cue the RCS leak in Containment. The SRO will implement DB-OP-02522, Small RCS Leaks to mitigate the leak.
The reactor will require tripping per immediate actions of DB
-OP-02522 due to PZR level below 100 inches.
When the Reactor is tripped the RCS leak will increase to a large LOCA. The Emergency Diesel Generators will start on SA level 2 actuation. The standby Component Cooling Water Pump will fail to auto start and will be started from the control panel.
Subcooling margin will be lost requiring the RCPs to be tripped (CT-1). Section 5 of DB
-OP-02000, Loss of Subcooling Margin, will be entered.
Transition will be made to Section 10, Large LOCA. LPI will have failed to auto start and will be initiated manually (CT
-4). Control Room EVS will be placed in service (CT-27).
When Control Room EVS is placed in service the scenario can be terminated at the Lead Evaluators discretion.
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
4 Event # 1 & 2 Page 3 of 14 Event
Description:
Transfer from Motor Driven Feed Pump to Main Feed Pump 2
& increase Power Time Position Applicant's Actions or Behavior NUREG-1021, Revision 10 Page 3 of 14 FENOC Facsimile AG Event 1: Transfer from Motor Driven Feed Pump to Main Feed Pump 2 DELETED Event 2: Raise Reactor power to 4%
SRO Direct transfer of feedwater from the MDFP to MFP 2 BOP Raise Main Feed Pump Speed until discharge pressure is between 1000 and 1050 psig BOP Contact Equipment Operator to close FW6396 Booth Cue Role play as equipment operator to close FW6396 BOP Stop the Motor Driven Feed Pump BOP Contact Equipment Operator to:
Verify Closed FW170, FW Mini Bypass to condenser Close FW104, D/A Storage Tanks to Condenser Verify Closed FW33, D/A Storage Tanks to Condenser Complete shutdown of the MDFP per DB
-OP-06225 BOP If directed
- adjust FC438 MFP recirc controller to 4.0 MMPH SRO Direct Power increase to 4% while controlling heatup rate at less than 35
°F/Hr and stabilize ATC Toggle increase on the ICS Reactor Demand Station Monitor Heatup Rate on the SPDS Monitor Reactor power Stabilize Reactor power at 4%
SRO When MFPT is in service with flow to the Steam Generators establish direct MFPT 2 ARTS INPUT TEST toggle switches be placed in OPERATE
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
4 Event # 3 Page 4 of 14 Event
Description:
Increase Reactor power to 4%
Time Position Applicant's Actions or Behavior NUREG-1021, Revision 10 Page 4 of 14 FENOC Facsimile AG Event 2: Increase Reactor power to 4%
BOP Place MFP 2 ARTS MFP Input Test switches in OPERATE ARTS Channel 1 MAIN FEED PUMP INPUT TEST ARTS Channel 2 MAIN FEED PUMP INPUT TEST ARTS Channel 3 MAIN FEED PUMP INPUT TEST ARTS Channel 4 MAIN FEED PUMP INPUT TEST SRO Direct Placing ARTS MAIN FEED PUMP NORMAL BYPASS switches in NORMAL BOP Place the ARTS MAIN FEED PUMP NORMAL BYPASS switches in NORMAL ARTS Channel 1, verify Main Feed Pump 1/5 light OFF ARTS Channel 2, verify Main Feed Pump 1/5 light OFF ARTS Channel 3, verify Main Feed Pump 1/5 light OFF ARTS Channel 4, verify Main Feed Pump 1/5 light OFF On Lead Evaluator's discretion, proceed to Event 3
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
4 Event # 3 Page 5 of 14 Event
Description:
Service Water Pump trip Time Position Applicant's Actions or Behavior NUREG-1021, Revision 10 Page 5 of 14 FENOC Facsimile AG Event 3: Service Water Pump Trip Indications Available:
(P946) SW HDR 2 PRESS SWP 2 not running CREW Recognize loss of Service Water Loop 2 SRO Implement DB
-OP-02511, Loss of Service Water Pumps/ System BOP Perform Attachment 20 of DB
-OP-02511, Isolation of Containment Air Cooler Supplying Press OPEN on HIS1357,SW1357 Stop CAC 2(HIS5032)
Close SW1367 BOP Verify CT2955 opens to supply secondary loads SRO Direct an Equipment Operator or Electrical Maintenance to investigate targets on SW Pump 2 Booth Cue Role Play as an Equipment Operator to report a 50/51A target, Alarm
-Time and Instantaneous Overcurrent on Breaker AD107 BOP Direct an Equipment Operator to align SW Pump 3 as SW Pump 2 using Attachment 2 Booth Cue Role Play as an Equipment Operator to align SW Pump 3 as SW Pump 2 using Attachment 2
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
4 Event # 3 Page 6 of 14 Event
Description:
Service Water Pump trip Time Position Applicant's Actions or Behavior NUREG-1021, Revision 10 Page 6 of 14 FENOC Facsimile AG Event 3: Service Water Pump Trip
- continued BOP Control secondary loads on Circ Water using Attachment 10 Verify SW 1399 is closed Verify SW 1395 is closed Verify CT 2955 is open Direct an Equipment Operator to complete Attachment 10 for Circ Water Supplying Secondary loads Booth Cue Role play as Equipment Operator to complete Attachment 10 for Circ Water Supplying Secondary loads (no actions required)
SRO Refer to Tech Spec 3.7.8 for an inoperable Service Water Train Enter TS 3.7.8 Condition A
- SW Loop 2 INOPERABLE Enter TS 3.8.1 Condition B
- EDG 2 INOPERABLE BOP Energize SWS and EDG Blue Operability lights SRO Start SW Pump 3 BOP Return Secondary Loads to SW Loop using Attachment 13, Restoration of SW Loop 2 to Secondary Loads Direct an Equipment Operator to throttle the in
-service TPCW Heat Exchanger Outlet Valves Open SW 1395 Close CT 2955 Booth Cue Role play as Equipment Operator to perform local actions of Attachment 13 for restoration of SW Loop 2 to Secondary Loads (no actions required)
On Lead Evaluator's discretion, proceed to Event 4
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
4 Event # 4 Page 7 of 14 Event
Description:
MU32 Pressurizer Level Control fails open Time Position Applicant's Actions or Behavior NUREG-1021, Revision 10 Page 7 of 14 FENOC Facsimile AG Event 4: MU32 Pressurizer Level Control fails open Indications Available:
2-4-C MU FLOW HI TRN 2 Pressurizer level increasing Makeup flow increasing ATC Refer to DB
-OP-02002, Letdown/Makeup Alarm Panel 2 Annunciators for 2-4-C ATC Check for small RCS leak indications ATC Attempt to manually control MU 32 ATC Monitor Pressurizer level for greater than 2 75 inches Informs SRO level is or will go above 275 inches due to the inability to close MU32 SRO Direct closing MU 6422, MAKEUP TRAIN 2 TO RCS ISOLATION ATC Close MU 6422, MAKEUP TRAIN 2 TO RCS ISOLATION SRO Refer to Tech Spec 3.4.9 if Pressurizer level exceeds 228 inches SRO Implement DB
-OP-02512 Makeup and Purification System Malfunctions for loss of Normal RCS Makeup Flowpath ATC If Pressurizer level goes below 200 inches isolate letdown by closing MU2B ATC Verify Pressurizer level is above the minimum required level in accordance with Curve CC 4.3 Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
4 Event # 4 Page 8 of 14 Event
Description:
MU32 Pressurizer Level Control fails open Time Position Applicant's Actions or Behavior NUREG-1021, Revision 10 Page 8 of 14 FENOC Facsimile AG Event 4: MU32 Pressurizer Level Control fails open
- continued ATC Verify Seal Injection flow is normal SRO Dispatch Equipment Operator to investigate MU32 Request Maintenance support Booth Cue Role play as an Equipment Operator and report MU 32 is open with no visible indication of cause Role play as Maintenance as required and report MU32 will need to be tagged out for repair ATC Reduce Letdown flow to minimum (25 gpm)
Throttle MU6
, Flow Control Close MU4, Orifice Block SRO Direct placing the Alternate injection line in service per Attachment 4 of DB-OP-02512 Makeup and Purification System Malfunctions ATC Verify MU 6422, MU CTMT Isolation, is closed Open MU 6421, CTMT Iso For Alt MU Inj Line Throttle open MU 6419, Alt MU Inj Line to establish RCS Makeup Flow Direct Equipment Operator to Open MU 6423B, Mini
-Flow Bypass Around MU 6419 Booth Cue Role play as Equipment Operator to Open MU 6423B SRO Refer to TRM 8.1.1, Boration Systems
- Operating ATC Restore Letdown flow On Lead Evaluator's discretion, proceed to Event 5
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
4 Event # 5 Page 9 of 14 Event
Description:
SG2 Pressure Instrument Fails High Time Position Applicant's Actions or Behavior NUREG-1021, Revision 10 Page 9 of 14 FENOC Facsimile AG Event 5: SG2 Pressure Instrument Fails High Indications Available:
14-4-E, ICS INPUT MISMATCH TBVs and AVV going open side 2 SG 2 pressure decreasing BOP Recognize indications of PT SP12A2 failing high BOP Implement DB-OP-02014, MSR/ICS Alarm Panel Annunciators for 14-4-E BOP Place Loop 2 TBVs in HAND and lower the demand BOP Place AVV 2 in HAND and close SRO Implement DB
-OP-06407, Non
-Nuclear Instrumentation System Operating Procedure, for transferring NNI Instrument Inputs to ICS Hand/Auto Stations CREW Verify PT SP12A2 instrument is bad Verify PT SP12A1 instrument is good BOP Select PT SP12A1 BOP Return ICS to Auto per DB-OP-06401, ICS Procedure Place Loop 2 TBVs in AUTO Place AVV 2 in Auto BOP Reset ICS Input Mismatch Annunciator On Lead Evaluator's discretion, proceed to Event 6
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
4 Event # 6 Page 10 of 14 Event
Description:
Reactor Coolant System Leak in Containment Time Position Applicant's Actions or Behavior NUREG-1021, Revision 10 Page 10 of 14 FENOC Facsimile AG Event 6: Reactor Coolant System Leak in Containment Indications Available:
Pressurizer Level decreasing Makeup Tank level decreasing CTMT Normal Sump level rising CREW Recognize indications of an RCS leak in Containment SRO Implement DB-OP-02522, Small RCS leaks CREW Recognize immediate action requirements to trip the Reactor with Pressurizer level less than 100 inches SRO Direct Reactor trip ATC Perform DB
-OP-02000 Immediate actions Trip the Reactor Verify power is decreasing Trip the Turbine SRO Implement DB
-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture SRO/ATC Verify immediate actions CREW Check for Specific Rules NOTE RCS Leak becomes a Large LOCA following Reactor trip Proceed to Event 7 & 8 Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
4 Event # 7 & 8 Page 11 of 14 Event
Description:
Large LOCA, LPI and CCW Pump failure to start Time Position Applicant's Actions or Behavior NUREG-1021, Revision 10 Page 11 of 14 FENOC Facsimile AG Event 7: Large LOCA
- LPI fails to start 8: CCW Pump failure to start CREW Recognize a loss of subcooling margin
- Critical Task BOP Implement Specific Rule 2
- Trip all 4 Reactor Coolant Pumps BOP Select Incores on Pam panels
-OP-02000 Section 5, Loss of SCM
- Critical Task BOP Implement Attachment 8, Place MU/HPI/LPI in Service Start/Verify running both CCW Pumps Start/Verify running both HPI Pumps Verify open HP 2A, HP 2B, HP 2C and HP 2D
- Start both LPI Pumps Transfer MU Pump suctions to the BWST Set Pressurizer Level Controller to 100 inches Start/Verify running the second MU Pump Lock MU Pump suctions on the BWST Isolate Letdown Verify Pressurizer heaters are off Open MU 6421 Open MU 641 9 ATC Control MU
\HPI\LPI per specific Rule 3 and Attachment 13 ATC Verify proper SFAS actuation BOP Verify proper SFRCS actuation
Appendix D Operator Action Form ES-D-2 Op Test No.:
2015 Scenario #
4 Event # 7 & 8 Page 12 of 14 Event
Description:
Large LOCA, LPI and CCW Pump failure to start Time Position Applicant's Actions or Behavior NUREG-1021, Revision 10 Page 12 of 14 FENOC Facsimile AG Event 7: Large LOCA
- continues BOP Verify proper SG level control BOP Realign AFW if an SFRCS low pressure trip occurs CREW Determine RCS Pressure has lowered to the point where LPI flow into the RCS is observed SRO Route to Section 10, Large LOCA Cooldown SRO Notify Shift Manager to refer to RA
-EP-01500, Emergency Classification SRO Dispatch Equipment Operator to perform Attachment 7, Section 1 to close breakers for DH7A, DH7B, DH9A, DH9B and HP31 SRO Direct actions for at least 1350 GPM flow in both LPI lines:
ATC Stop both Makeup Pumps ATC Transfer MU Suctions to the MU Tank MU6405 and MU3971 ATC Verify piggyback valves closed DH63 and DH64
NUREG-1021, Revision 10 Page 13 of 14 FENOC Facsimile AG Justification for Critical Tasks A. Trip all Reactor Coolant Pumps. (CT
-1) When Subcooling Margin is lost all Reactor Coolant Pumps are required to be stopped immediately B. Initiate Low Pressure Injection (CT-4) Following the Reactor trip a Large LOCA will develop requiring Low Pressure injection to be placed in service to provide inventory for core recovery as well as long term core cooling
. LPI will fail to actuate and will require manual actuation
. C. Implementation of Control Room habitability (CT
-27) During a LOCA event, Control Room Emergency Ventilation is placed in service to aid in controlling radiation levels due to the ingression of airborne fission products
NUREG-1021, Revision 10 Page 14 of 14 FENOC Facsimile AG SIMULATOR SETUP INFORMATION
- 1. Simulator Setup a) Fail HPI Pump 1 SFAS Output Module b) Fail CCW Pump 2 auto start c) Two TBV bypass valves isolated on each side
- place isolated tags on panel d) SW Train 2 supplying Secondary Loads e) RCS Leak becomes LOCA on Reactor trip f) LPI Pumps fail to auto start
- 2. Procedures a) DB-OP-06901, Plant Startup Procedure signed off appropriately to Step 3.27 b) DB-OP-02511, Loss of Service Water Pumps/ System c) DB-OP-02002, Letdown/Makeup Alarm Panel 2 Annunciators for 2-4-C d) DB-OP-02512 Makeup and Purification System Malfunctions e) DB-OP-02014, MSR/ICS Alarm Panel Annunciators for 14 E f) DB-OP-06407, Non
-Nuclear Instrumentation System Operating Procedure g) DB-OP-02522, Small RCS leaks h) DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture 2) For Simulator Instructor:
a) DB-OP-02511, Loss of SW, Attachments 2 and 10 b) DB-OP-06016 Section 4.2 c) Use INSIGHT file for MU Flow Hi alarm