ML14351A093
| ML14351A093 | |
| Person / Time | |
|---|---|
| Site: | Farley  |
| Issue date: | 12/17/2014 |
| From: | NRC/RGN-II |
| To: | Southern Nuclear Operating Co |
| Shared Package | |
| ML14351A112 | List: |
| References | |
| ES-D-1 50-348/OL-14, 50-364/OL-14 | |
| Download: ML14351A093 (204) | |
Text
Appendix D Scenario #1 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 1 Op-Test No.: FA2014-301 Examiners: Operators: SRO RO BOP Initial Conditions: 4% power, UOP-1.2, v110, completed thru step 5.65. Ready to perform step 5.66. MOL, 1340 ppm Cb; 1B SGFP on service. Aux steam from U-2.
Turnover:
1B SGFP is on service, MFR bypass valves are on service.
Current Risk Assessment is GREEN and projected to remain GREEN.
A Train O/S, A Train protected.
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia SPLIT TRAIN ALIGNMENT Event Malf. Event Type* Event Description No. No.
1 R (RO) Raise Power to 12% using control rods and steam dumps.
N (BOP) 2 N (BOP) Start 1A CTMT Cooler in Fast 3 Imf C (RO) FK-122 Fails open in Auto (P - CT) fk122-A 4 imf mal- I (BOP) R-35A Fails high, automatic actions do not occur rmsip35 A/ TS (SRO) T.S. 3.3.7 Cond A preset 5 imf I (BOP) PT-508 Fails high (P - CT) pt508 6 imf C (RO) 1A RCP trips (P - CT) crcrcp1
_cc3 T.S. 3.4.4 Cond A TS (SRO) 7 Imf mal- M (ALL) Steam break inside containment, MSIVs will not close, Automatic mss1B /
Preset C (RO) SI is blocked (CT-2) 8 Preset / C (BOP) 1B CS pump does not auto start. (*CT-3) dmf crsh001 MOV 8820A does not open. (*CT-3) c_cc5 *1 CS spray pump required (Orange Path on Z until CS established)
After ECP 2.1 entry and 27psig in containment MSIVs close.
Terminate on transition out of ECP-2.1 to EEP-2 or examiners discretion (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley October 2014 exam Page 1 of 4
Appendix D Scenario 1 Presets Form ES-D-1 PRESETS 7 Fail auto SI signals, Manual SI works
- CMFmalf / csftyinj_cc1 / open CMFmalf / csftyinj_cc11 / open 4 3622, 3624 and 3626 will not close on hi rad
- Cmf mal / chvh3622_d_cc3 closed Cmf mal / chvh3624_d_cc3 closed Cmf mal / chvh3626_d_cc3 closed 7 1A MSIVs will not close on the auto or manual closure
- CMFmalf / crsh001a_cc5 / open CMFmalf / cmsh002a_d_cc5 / open CMFmalf / crsh001a_opos3 / open CMFmalf / cmsh002a_d_opos3 / open 7 1B MSIVs will not close on the auto or manual closure
- CMFmalf / crsh001b_cc5 / open CMFmalf / cmsh002b_d_cc5 / open CMFmalf / crsh001b_opos3 / open CMFmalf / cmsh002b_opos3 / open 7 1C MSIVs will not close on the auto or manual closure
- CMFmalf / crsh001c_cc5 / open CMFmalf / cmsh002c_d_cc5 / open CMFmalf / crsh001c_opos3 / open CMFmalf / cmsh002c_opos3 / open 8 1B CS pump does not auto start - will start from MCB
- CMFmalf / cbkp01b_d_cc5/ open MOV 8820A does not open on phase B- will open from MCB
- CMFmalf / cbk8820a_d_cc5 / open Triggers and Commands Farley October 2014 exam Page 2 of 4
Scenario 1 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 4% power, UOP-1.2, v110, completed thru step 5.65, Ready to perform step 5.66. MOL, 1340 ppm Cb; 1B SGFP on service. Aux steam from U-2.
Turnover:
1B SGFP is on service, MFR bypass valves are on service.
Current Risk Assessment is GREEN and projected to remain GREEN.
A Train O/S, A Train protected.
Event 1 Commence Ramp up to 12% power.
Verifiable actions: RO uses rods to increase RCS temperature, adjusts Steam Dumps to increase Stm flow and Rx power. BOP adjusts MFW flow to the SGs (Bypass FRVs on service) and may adjust steam dumps instead of the RO.
Event 2 Start 1A CTMT Cooler in Fast.
Verifiable actions: BOP will stop the 1A CTMT cooler and then start the 1A CTMT Cooler in FAST (2 separate switches).
Event 3 FK-122 fails open in auto. (P - CT)
Verifiable actions: RO will take manual control of FK-122.
Event 4 R-35A Fails high, automatic actions do not occur.
Verifiable actions: BOP will manually isolate the three (3) dampers that failed to automatically isolate (HS on BOP). TS 3.3.7 Function 3 Condition A.
Event 5 PT-508 Fails high. (P - CT)
Verifiable Actions: BOP takes manual control of SGFP speed as SGFP speed will decrease as will SGWL.
Event 6 1A RCP trips. (P - CT)
Verifiable Actions: RO manually shuts 1A spray valve, PK-444C. BOP will maintain SGWL. T.S. 3.4.4 Cond A.
Event 7 A Steam Break inside CTMT will occur and MSIVs will not close.
AUTO SI is blocked.
Verifiable Actions: RO manually initiate SI. (CT)
Event 8 1B CTMT Spray (CS) pump fails to auto start, MOV-8820A 1A CS discharge does not auto open.
Verifiable Actions: BOP start 1B CS pump OR open MOV-8820A. (CT) Orange path on FRP-Z.1 until CS flow is established.
At step 2 of ECP-2.1, 1A MSIV closes.
Terminate on transition from ECP-2.1 to EEP-2 or examiners discretion. Transition criteria to leave ECP-2.1 may or may not be met with in scenario design time.
UOP-1.2/ SOP/ARP/AOP-16/ARP/AOP-100/AOP-4/EEP-0/ESP-0.1/EEP-0/EEP-2/ECP-2.1/EEP-2.
Farley October 2014 exam Page 3 of 4
Scenario 1 Critical Task sheet Appendix D Form ES-D-1 Sheet CRITICAL TASK SHEET
- 1. Manually actuate at least one train of SIS-actuated safeguards before any of the following: (CT-2)
Transition to any E-2 series procedure or FRG.
- 2. Manually actuate at least the minimum required complement of containment cooling equipment before an extreme (red path) challenge develops to the containment CSF.
(CT-3)
SCENARIO Low power instrument and component failures with a Steam Break.
OBJECTIVE/ The team should be able to:
OVERVIEW: ramp the plant from 4% to 12 % power, start a Containment cooler in FAST, respond to a component malfunction FCV-122, respond to an instrument malfunction of R-35A, respond to an instrument malfunction affecting SGFP speed, respond to a RCP trip, diagnose a steam break (MSIVs do not close) , manually SI (blocked),
manually start Containment Spray, diagnose that all SGs are faulted and transition to ECP-2.1, 1C MSIV closes in ECP-2.1 and terminate when transition back to EEP-2 is performed or at examiners discretion.
Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes
- 1. Total malfunctions (5-8) 6
- 2. Malfunctions after EOP entry (1-2) 2
- 3. Abnormal events (2-4) 3
- 4. Major transients (1-2) 1
- 5. EOPs entered/requiring substantive actions (1-2) 1
- 6. EOP contingencies requiring substantive actions (0-2) 1
- 7. Critical tasks (2-3) 5 Farley October 2014 exam Page 4 of 4
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 1 Page 1 of 41 Event
Description:
Ramp up to 12% power Indications Available Annunciators: NA Increase Reactor power to 12% and get ready to roll the Main Turbine. When simulator is taken to run the crew is expected to increase Reactor power to 12% IAW UOP-1.2. At 8% the NRC will evaluate going to the next event. This evolution will take approx. 15 -20 minutes Note to Examiner When simulator is taken to run the crew is expected to increase Reactor power to 12% IAW UOP-1.2. At 8% the Lead Examiner may evaluate going to the next event. This evolution will take approx. 15 -20 minutes. Crew may choose to perform event 2 (Shift 1A CTMT Cooler to Fast Speed) prior to raising power.
UOP-1.2, Startup of Unit from Hot Standby to Minimum Load, v110.0 Time Pos. Expected Actions/Behavior Comments RO (step 5.66) Begin to increase reactor power Manual adjustment of rods to greater than 12% with following controls. (not more than 3 steps at a Manual adjustment of control rods time)
Stm dump control - adjust PK-Steam dumps in Steam Pressure 464 counterclockwise to Control Mode release more steam, decrease NOTE: SOP-2.3 instructions for Tavg, pull rods and increase associated dilution are on page 3 power RO (step 5.68) WHEN Nuclear at Power Permissive P-10 permissive status light is illuminated (2/4 power ranges greater than 10%), THEN perform the following: {CMT-0003695}
(step 5.68.a) Block the intermediate range reactor trip and overpower rod stop.
Place INTEMEDIATE RANGE BLOCK TRN A to BLOCK.
Place INTEMEDIATE RANGE BLOCK TRN B to BLOCK.
(step 5.68.b) On the Bypass and Permissive Panel verify the following:
The INTERM RANGE TRAIN A TRIP BLOCKED light illuminated.
The INTERM RANGE TRAIN B TRIP BLOCKED light illuminated.
(step 5.68.c )Block the power range low setting reactor trip.
Place POWER RANGE BLOCK TRN A to BLOCK.
Place POWER RANGE BLOCK TRN B to BLOCK.
(step 5.68.d) Verify the following on the Bypass and Permissive Panel:
The POWER RANGE LOW SETTING TRAIN A TRIP BLOCKED light illuminated.
The POWER RANGE LOW SETTING TRAIN B TRIP BLOCKED light illuminated.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 1 Page 2 of 41 Event
Description:
Ramp up to 12% power UOP-1.2, Startup of Unit from Hot Standby to Minimum Load, v110.0 (CONT)
Time Pos. Expected Actions/Behavior Comments RO (step 5.68.e) Verify that Low Power Trip Block P-7 status light is not illuminated to ensure the unblocking of the following reactor trips.
Pressurizer Low Pressure Pressurizer High Water Level Loss of Flow-Two Loops RO (step 5.68.f)Verify NR-45B is in the desired speed, i.e., 2nd speed (2 min/div) OR normal speed. (10 min/div)
SRO (step 5.68.g) IF not previously performed at Disconnect 915 is already Section 5 Reference 53, direct qualified closed.
OPS personnel to close disconnect switch 915 in accordance with FNP-0-SOP-36.8 When 8-12% power is reached or at the discretion of the Lead Examiner move to event.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 1 Page 3 of 41 Event
Description:
Ramp up to 12% power SOP-2.3, CVCS RX Makeup Control System, Dilution, Appendix C, v60.1 Time Pos. Expected Actions/Behavior Comments RO 2.0 Dilution 2.1 IF necessary, THEN set the total batch integrator to the desired quantity.
2.2 IF necessary, THEN adjust LTDN TO VCT FLOW LK 112 setpoint as desired.
2.3 Position the MKUP MODE CONT SWITCH to STOP.
2.4 Position the MKUP MODE SEL SWITCH to DIL or ALT DIL.
2.5 IF using ALT DIL AND it is desired to bypass the VCT, THEN place the MKUP TO VCT valve Q1E21FCV114A in close.
2.6 Position the MKUP MODE CONT SWITCH to START.
2.7 Verify proper dilution operation by observing the following:
- IF using ALT DIL, MAKEUP TO CHG PUMP SUCTION HDR FCV113B opens.
- FCV-114A opens, unless bypassing VCT.
- RMW TO BLENDER Q1E21FCV114B opens.
- Reactor makeup flow displayed on FI-168 MAKEUP FLOW TO CHG/VCT.
Verify the dilution automatically stops when the total flow batch integrator reaches setpoint:
- Reactor makeup flow returns to zero as displayed on FI-168
- MKUP TO VCT , FCV114A closes.
- RMW TO BLENDER, FCV114B closes.
- IF ALT DIL was used, THEN FCV-113B closes.
2.9 IF VCT was bypassed, THEN verify MKUP TO VCT valve Q1E21FCV114A (Q1E21V339) in AUTO.
2.10 Position the MKUP MODE SEL SWITCH to AUTO.
2.11 Position the MKUP MODE CONT SWITCH to START.
2.12 IF LK 112 setpoint was adjusted per Step 2.2, THEN return setpoint to that required for current conditions.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 2 Page 4 of 41 Event
Description:
Shift 1A CTMT Cooler to Fast Speed IAW SOP-12.1, step 4.7 Indications Available:
- NONE SOP-12.1, Containment Air Cooling System, v41.1 Time Pos. Expected Actions/Behavior Comments BOP (Step 4.7.1.1) Stop 1A Contaiment cooler fan BOP (Step 4.7.1.2) Check CTMT CLR 1A DISCH 3186A closed light illuminated BOP (Step 4.7.1.3) Start 1A CTMT Cooler Fan is Fast Speed BOP (Step 4.7.1.2) Check CTMT CLR 1A DISCH 3186A open light illuminated Start the next event when the 1A CTMT cooler is running in fast speed or at discretion of the Lead Examiner
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 3 Page 5 of 41 Event
Description:
FK-122, Charging Flow Controller, fails HI Indications Available Annunciators: Recognize indications of FK-122 FAILING HI
- CHG HDR FLOW HI-LO (EA2) - FT-122 will indicate pegged High
- REGEN HX LTDN FLOW DISCH TEMP - VCT level will HI (DE1) (possible if not discovered in a - Przr level will slowly timely manner) - LK-459F will slowly
Note to Examiner Based upon the component malfunction AOP-100 is the expected entry procedure but AOP-16.0 may be entered if crew determines event is a CVCS malfunction.
AOP-100 actions begin on this page.
AOP-16.0 actions begin on page 5.
AOP-100, Instrumentation Malfunction, section 1.2, v13.0 Time Pos. Expected Actions/Behavior Comments RO (step 1) Check pressurizer level is on or trending to program value RO (step 1 RNO) Take Manual control of FK- POTENTIAL CRITICAL TASK 122, CHG FLOW controller and restore PZR If > 10% power and operators level. fail to take manual control of FK-122, trip will occur on high PZR level.
RO (step 2) Check RCP Seal Injection flows 6-13 gpm
[] Adjust as necessary using HIK 186, RCP SEAL INJECTION FLOW CONTROLLER SRO (step 3) Determine if a pressurizer level transmitter/indicator loop has failed None have failed RO (step 4) Check letdown in service
- Letdown is in service
- Proceed to step 6 SRO (step 6) Refer to TS 3.3.1 and 3.3.3 Since there are no instrument failures TS 3.3.1 and 3.3.3 do (step 7) Notify the Shift Manager not apply.
(step 8) When plant conditions permit then restore components to automatic control
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 3 Page 6 of 41 Event
Description:
FK-122, Charging Flow Controller, fails HI AOP-16, CVCS Malfunction, v20.0 Time Pos. Expected Actions/Behavior Comments SRO Determine a charging system malfunction is occurring and direct entry into AOP-16.
RO (Step 1) Verify CHG flow adequate to cool Flow will be adequate letdown CHG FLOW - FI-122A LTDN HX OUTLET FLOW - FI-150 REGEN HX OUTLET TEMP - TI-140 BOP (Step 2) Stop any load change in progress SRO (step 3) [CA]IF Charging line rupture NO charging header rupture occurs, THEN Go To ATTACHMENT 2 has occurred, RO (Step 4) Monitor VCT level to ensure proper level is maintained RO (Step 5) Observe CHG HDR PRESS and NOTE: Actual amps will be MOTOR AMPS to ensure proper charging lower than normal pump operation PI-121, CHG HDR PRESSURE, and ammeter for chg pump RO (Step 6) Check charging pump - RUNNING YES 1C chg pump RO (Step 7) Check Charging flow FK-122, CHG NOTE: There will be flow FLOW CONTROLLER, controlling in AUTO indicated and FK-122 in AUTO with flow indicated - Seal inj flow will decrease due to FCV-122 going open.
FK- 122 is taken to manual control -RNO POTENTIAL CRITICAL TASK Adjust SEAL WTR INJECTION HIK-186, If > 10% power and operators SEAL WATER INJECTION as required to fail to take manual control of maintain RCP seal injection flow 6-13 gpm. FK-122, trip will occur on high PZR level.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 3 Page 7 of 41 Event
Description:
FK-122, Charging Flow Controller, fails HI AOP-16, CVCS Malfunction, v20.0 (CONT)
Time Pos. Expected Actions/Behavior Comments RO (Step 8) Check DE3 clear YES RO (Step 9) Determine Status of Normal Since there is flow, go to Letdown: RNO to go to step 19.
LTDN HX OUTLET FLOW, FI-150
- NO FLOW INDICATED SRO (step 19) Determine charging status NO - go to 19 RNO
- CHG FLOW, FI122A ABNORMAL FLOW INDICATED.
SRO (step 19.1 RNO) THEN go to procedure and step in effect.
SRO - Submit a Condition Report and notify the Work Week Coordinator (Maintenance ATL on backshifts)
- Notify the Shift Manager Move to next event when FK-122 is in manual and PZR level is stable or at the discretion of the Lead Examiner.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 4 Page 8 of 41 Event
Description:
R-35A, Control Room Air Intake Radiation Monitor, fails HI Indications Available Annunciators: Recognize indications of R-35A failing HIGH
- BOP PANELS ALARM (BE5) on MCB - BOP/ R-35A HI ALARM (LD4)
- BOP/ R-35A HI ALARM (LD4) - IPC R-35A indication Note to Examiner When R-35A fails high the only indication will be annunciators and IPC Data. Since R-35A is in the plant and normally on the BOP, (not in the simulator), a call to the extra operator will get a response.
Drawing D205012, HVAC & Filtration P&ID Control Room and Computer Room, is available to assist the crew if requested ARP-3.1, BOP Panel Annunciator Panel L, v33.0 LD4 Time Pos. Expected Actions/Behavior Comments SRO Direct ARP entry for LD4 BOP (step 1) Verify Computer Room AHU NOTE: These three valves will dampers closed. fail to close automatically QSV47HV3622 COMPUTER RM HVAC RTN QSV47HV3624 CONT RM HVAC SUPP QSV47HV3626 COMPUTER RM HVAC SUPP BOP should close these 3 valves SRO/ (step 2) Call to have TSC HVAC aligned in Calls Booth to have TSC BOP the recirc mode ventilation aligned.
SRO/ (step 3) Determine the validity of the high Calls booth to verify that the BOP activity indication as follows: instrument is aligned and
- a. Verify that the instrument is aligned for functioning properly normal operation and is functioning properly.
- b. Sample or survey the affected system or area as required.
BOP (step 4) Verify both control room doors closed SRO (step 6) Consult Technical Specifications TS 3.3.7 on the next page 3.3.7 to determine the required alignment for the following:
Control Room Pressurization Units Control Room Recirculation Units Control Room Utility Exhaust Fan
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 4 Page 9 of 41 Event
Description:
R-35A, Control Room Air Intake Radiation Monitor, fails HI TECHNICAL SPECIFICATION 3.3.7, Control Room Emergency Filtration/Pressurization System (CREFS) Actuation Instrumentation Table 3.3.7-1 (page 1 of 1)
CREFS Actuation Instrumentation FUNCTION APPLICABLE REQUIRED SURVEILLANCE TRIP MODES OR OTHER CHANNELS REQUIREMENTS SETPOINT SPECIFIED CONDITIONS
- 1. Manual Initiation 1,2,3,4, (a), (b) 2 trains SR 3.3.7.6 NA
- 2. Automatic Actuation 1,2,3,4 2 trains SR 3.3.7.3 NA Logic and Actuation SR 3.3.7.4 Relays SR 3.3.7.5
- 3. Control Room 1,2,3,4 1 SR 3.3.7.1 < 800 cpm Radiation Control (a), (b) 2 SR 3.3.7.2 Room Air Intake SR 3.3.7.7 (R-35A, B)
- 4. Containment Refer to LCO 3.3.2, "ESFAS Instrumentation," Function 3.a., for all initiation functions and Isolation - requirements.
Phase A (a) During CORE ALTERATIONS.
(b) During movement of irradiated fuel assemblies.
CONDITION REQUIRED COMPLETION ACTION TIME A. One or more A.1 Place one 7 days Functions CREFS train in with one emergency required recirculation channel or train mode.
SRO TS 3.3.7 Table 3.3.7-1 has two Functions that need to be addressed:
- 3 R-35A AND R-35B are BOTH INOPERABLE. R-35A is inoperable due to the failure, and R-35B is inoperable as soon as the flow path past the detector is isolated by closed dampers. A mandatory LCO would be initiated since one channel is required and neither channel is operable. The unit is in either mode 1 or 2 with no fuel movement in progress and only one rad monitor is required in this condition. This is condition A as shown above.
SRO Submit a condition report on the failed instrument, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report SRO Inform the SM of the failure and Tech Spec entry After Tech Spec analysis or at the discretion of the Lead Examiner move to next event.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 5 Page 10 of 41 Event
Description:
PT-508 Fails HI Indications Available Annunciators: Recognize indications of PT-508 failure
- 1A,1B,OR 1C SG STM FLOW > FEED - SGFP speed FLOW (JB1, JB2, JB3) - FRVs opening
- 1A,1B,OR 1C SG LVL DEV (JF1, JF2, - SGWL NR JF3 ) - Feed flows to zero
- TAVG/TREF DEV (HF3)
Note to Examiner Afterwards, PT-508 will fail high and SGFP speed will decrease. The crew will enter AOP-100 and take manual control of the SGFP controller to increase speed and control SG water levels. If no action is taken the Reactor will trip at 28% SG NR levels AOP-100, Instrumentation Malfunction, v13.0, Section 1.4 Time Pos. Expected Actions/Behavior Comments SRO Direct entry into AOP-100 BOP (step 1) Immediate operator action NOTE: Feed flows will be Check that steam and feed flows matched on decreasing and FRVs begin to all SGs open fully
- Take manual control of SK-509A, SGFP MASTER CONTROLLER and POTENTIAL CRITICAL TASK increase SGFP speed (could also If operators fail to take manual control of the SGFP speed take control of INDIVIDUAL controller the Rx will trip on Controllers) low SG level.
- Possibly take manual control of all FRVs, FK-478, 488, 498, SG FW FLOW CONTROL VLVS SRO (step 2) IF adverse trend in SG level exists, THEN establish trip criteria.
If any are approached then Trip the reactor and go to EEP-0.
BOP (step 3) Place the Main Turbine on HOLD BOP (step 4) Adjust SGFP speed back to within NOTE: Approximate P can the normal operating range for the feed be determined from the flow/steam flow P required for the existing following MCB indications.
power level. [ ] SGFP DISCH PRESS See table on next page for values PI4003
[ ] SG Pressure indications
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 5 Page 11 of 41 Event
Description:
PT-508 Fails HI AOP-100, Instrumentation Malfunction, v13.0, Section 1.4 Time Pos. Expected Actions/Behavior Comments Unit 1 NO LOAD P is 50 psid from 0-28.1%. PROGRAM P is linear from 50-190 psid from 28.1% to 100%. TABLE 1 provides approximate P values for varying power levels.
% POWER DP 30 54 psid 40 73 psid 50 93 psid 60 112 psid BOP (step 5.0) Check Steam Dumps in Tavg Mode.
- STM DUMP MODE SEL A-B TRN TAVG RO (step 6 and 8)
- Call Shift Manager
- Submit a condition report on the failed instrument, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report At the discretion of the Lead Examiner move to next Event.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 6 Page 12 of 41 Event
Description:
1A RCP Trip Indications Available:
Annunciators: Indications of 1A RCP Trip:
- 1A RCS Loop Flow LO or 1A RCP BRK - 1A RCP Amps decrease to zero Open (EF1) - FI-414, 415, 416, 1A RCS Loop flow
- 4160 VOLT BKR TRIPPED (MF4) - TI-412D, Tavg 1A RCS Loop
- RCP UV SINGLE INPUT ALERT (EF4)
- Rx Coolant Loops DT Dev HI-LO (HF2)
Note to Examiner 1A RCP will trip. Power is less than 30% so a reactor trip will not occur and is not required until RCS loop temperature decreases to less than 541°F.
AOP-4.0, Loss of Reactor Coolant Flow, v19.0 Time Pos. Expected Actions/Behavior Comments RO Announces receipt of MCB annunciators Reports trip of 1A RCP SS Directs RO and BOP Perform IOAs of AOP-4.0 Updates Team and Enters AOP-4.0 RO (step 1) Closes Przr spray valves for 1A RCP Immediate Operator Action PK-444C BOP (step 2) Maintain SG narrow range level POTENTIAL CRITICAL TASK stable at approximately 65% using: If operators fail to take manual FRV Bypasses control of SG water level <
82%. SGFP trip will occur and manual reactor trip will be required.
RO (step 3) Monitor Tavg for all three RCS loops [CA] Step 541°F. (TS 3.4.2)
If the A Loop decreases below 541°F then Loop A Temp may fall below 541F and require a reactor trip and transition to trip the reactor. EEP-0 (see page 13) If loop temperatures remain > 541F then initiatiation of next event will cause transition to EEP-0 RO (step 4) Maintain PRZR pressure 2200-2300 [CA] Step psig.
RO (step 5) Check normal letdown -
ESTABLISHED RO (step 6) Maintain PRZR level at approximately 22%.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 6 Page 13 of 41 Event
Description:
1A RCP Trip AOP-4.0, Loss of Reactor Coolant Flow, v19.0 (CONT)
Time Pos. Expected Actions/Behavior Comments SRO (step 7) Within six hours of the loss of RCS NOTE: Tech Spec 3.4.4, RCS flow complete the following: LoopsMODES 1 and 2, IF the unit is in Mode 1 or 2, THEN place unit Condition A requires the unit to in Mode 3 using the following procedures: be in mode 3 in 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. This UOP-2.1, SHUTDOWN OF UNIT FROM is procedurally driven.
MINIMUM LOAD TO HOT STANDBY TECHNICAL SPECIFICATION 3.4.4, RCS LoopsMODES 1 and 2 CONDITION REQUIRED COMPLETION Tech Spec will be evaluated ACTION TIME after the scenario A. Requirements A.1 Be in MODE 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> of LCO not 3.
met.
TECHNICAL SPECIFICATION 3.4.2, Minimum Temp for Critical OPSMODES 1 and 2 with Keff > 1.0 CONDITION REQUIRED COMPLETION Tech Spec will be evaluated ACTION TIME after the scenario This TS A. Tavg in one A.1 Be in MODE 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br /> or more RCS 3. NOT APPLICABLE if Tavg is loops not within maintained > 541F limit.
Move to the next event after the Reactor is tripped or at the discretion of the Lead Examiner
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7 Page 14 of 41 Event
Description:
Steam Line Break Inside CTMT during ESP-0.1 Indications Available Annunciators: Indications of STM Break in CTMT
- Various and numerous - Pzr level
- Fire Alarm (MH1) - RCS pressure
- Ctmt pressure
- SG Pressure Note to Examiner
- AOP 4.0 may direct tripping the RX and entry to EEP-0. Since SI is not required, transition to ESP-0.1 is directed at step 4.
- EEP-0.0 re-entry will occur subsequent to the STM Break in CTMT and the associated SI
- On Step 3 of ESP-0.1, 1B SG will have a Stm Fault inside containment. MSIVs do not auto close so three SGs will be affected until MSIVs are closed. When the Steam Break occurs an Automatic SI will actuate if not already in.
- 1B CS pump will not auto start and the 1A CS pump discharge will not open and initiate event 8.
- Entry to FRP-Z.1 may be required. FRP-Z.1 actions are on page 21.
EEP-0, Reactor Trip or Safety Injection, v45 Time Pos. Expected Actions/Behavior Comments RO/ Immediate Operator actions of EEP-0 Immediate Action steps BOP (step 1) Check reactor trip.
Check all reactor trip breakers and reactor trip bypass breakers - OPEN.
Check nuclear power - FALLING.
Check rod bottom lights - LIT.
(step 2) Check turbine - TRIPPED.
TSLB2 14-1 thru 4 lit .
(step 3) Check power to 4160 V ESF busses.
4160 V ESF busses - AT LEAST ONE ENERGIZED A Train (F 4160V bus) power available lights lit OR B Train (G 4160V bus) power available lights lit Verify operating diesel generators are being supplied from at least one SW pump.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7 Page 15 of 41 Event
Description:
Steam Line Break Inside CTMT during ESP-0.1 EEP-0, Reactor Trip or Safety Injection, v45 (CONT)
Time Pos. Expected Actions/Behavior Comments RO/ (step 4) Check SI Status. IF SI is not actuated then BOP Check any SI actuated indication. ESP-0.1 Transition will BYP & PERMISSIVE SAFETY INJECTION occur. (next page)
[] ACTUATED status light lit
[] MLB-1 1-1 lit IF SI actuated EEP-0.0 will
[] MLB-1 11-1 lit continue at step 5 (Page 17)
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7/8 Page 16 of 41 Event
Description:
Steam Line Break Inside CTMT During ESP-0.1 ESP.0.1, Reactor Trip Response, version 34 Time Pos. Expected Actions/Behavior Comments SRO Directs actions in ESP-0.1 per RO/BOP Actions listed below RO (step 1) Check RCS temperature NOTE: this is a continuing
- Stable at or approaching 547°F action step
- TAVG 1A(1B,1C) RCS LOOP RCS temperature will be
[] TI 412D decreasing due to the RCP
[] TI 422D STM DUMP trips and AFW flow
[] TI 432D BOP (step 1.1.1 RNO) Verify steam dumps closed.
STM DUMP INTERLOCK
[] A TRN in OFF RESET OR
[] B TRN in OFF RESET BOP (step 1.1.2 RNO)Verify atmospheric reliefs closed 1A(1B,1C) MS ATMOS REL VLV
[] PC 3371A
[] PC 3371B
[] PC 3371C BOP (step 1.1.3 RNO) Verify SGBD isolated BOP (step 1.1.4 RNO) IF cooldown continues, Adjusts pots for AFW flow to THEN control total AFW flow to stop RCS maintain > 395 gpm if SG NR cooldown. levels are <31% using MCB placard BOP (step 1.1.5) IF MSIVs are closed, THEN MSIVs are open proceed to step 1.1.10
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7/8 Page 17 of 41 Event
Description:
Steam Line Break Inside CTMT During ESP-0.1 ESP.0.1, Reactor Trip Response, version 34 Time Pos. Expected Actions/Behavior Comments BOP (step 1.1.6 RNO) Verify MSRs reset.
REHEATER CONTROL SYSTEM
[] CP 4054 BOP (step 1.1.7) Verify Main Steam Drain Pots isolated
[] MS DRN VLVS N1N11V904A/B/C/D handswitch to close.
BOP (step 1.1.8 RNO) Direct personnel to perform Calls booth to perform this the TB SO Actions Following A Reactor Trip step. Step and/or Safety Injection per FNP-0-SOP-0.0.
BOP (step 2) WHEN RCS average temperature NOTE: this is a continuing less than 554°F, THEN verify feedwater action step 1.1.2, Isolating status. Main steam drain pots is if
- Verify FRVs closed directed and may not be directed.
(step 2.2) MDAFWP AUTO/DEFEAT
[] 1A in DEFEAT
[] 1B in DEFEAT (step 2.3) -Verify BOTH SGFPs tripped (step 2.4) -Verify total AFW flow to the SGs
>395 gpm RO (step 3) Verify ALL RX TRIP breakers OPEN Steam line break will initiate after this step.
Auto SI is blocked.
Critical task Manually actuate at least one train of SI before transition to any E-1 series, E-2 series, E-3 series, or FRP.
( page 22)
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7/8 Page 18 of 41 Event
Description:
Steam Line Break Inside CTMT During ESP-0.1 EEP-0, Reactor Trip or Safety Injection, v45 Time Pos. Expected Actions/Behavior Comments RO/ Immediate Operator actions of EEP-0 Immediate Action steps of BOP (step 1) Check reactor trip. EEP-0 Check all reactor trip breakers and reactor trip bypass breakers - OPEN.
Check nuclear power - FALLING.
Check rod bottom lights - LIT.
(step 2) Check turbine - TRIPPED.
TSLB2 14-1 thru 4 lit NOTE: 3 DGs will be running (step 3) Check power to 4160 V ESF when the SI is initiated busses. manually.
4160 V ESF busses - AT LEAST ONE OATC will check SW header ENERGIZED pressure, ctmt cooler flows and CCW Hx SW flows and A Train (F 4160V bus) power available lights SW pump lights.
lit OR B Train (G 4160V bus) power available lights lit Verify operating diesel generators are being supplied from at least one SW pump.
RO/ (step 4) Check SI Status. IF SI is actuated then BOP Check any SI actuated indication. transition to ESP-0.1 will not BYP & PERMISSIVE SAFETY INJECTION occur and EEP-0.0 will
[] ACTUATED status light lit continue on (Page 18)
[] MLB-1 1-1 lit
[] MLB-1 11-1 lit SRO (step 5) Directs continuing into EEP-0. See Tab at end of scenario for Directs the BOP to perform Attachment 2. Attachment 2 and 4 actions.
(Page 25)
(step 6) Check containment pressure- HAS NOTE: [CA] step RO REMAINED LESS THAN 27 psig RO (step 6.1 RNO) Verify Phase B CTMT ISOL -
ACTUATED
[] MLB-3 1-1 lit
[] MLB-3 6-1 lit
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7/8 Page 19 of 41 Event
Description:
Steam Line Break Inside CTMT During ESP-0.1 EEP-0, Reactor Trip or Safety Injection, v45 Time Pos. Expected Actions/Behavior Comments RO (step 6.2 RNO) Stop all RCPs.
[] 1A [] 1B [] 1C RO (step 6.3 RNO) Verify PHASE B CTMT ISO If 1B CS pump not started or alignment. MOV8820A not opened in (step 6.3.1) Check All MLB-3 lights lit. FRP-Z.1 they will be opened IF any MLB-3 light NOT lit, THEN verify using Attachment 5.
PHASE B CTMT ISO using ATTACHMENT 5, PHASE B CONTAINMENT ISOLATION.
RO (step 6.4 RNO) Check containment spray Should have CS flow by FRP-Z.1, E-0 Att 5 or SOP-0.8 actions. If not, may secure CS pumps.
RO (step 7) Announce "Unit 1 reactor trip and safety injection".
Check secondary heat sink Available o Check total AFW flow > 395 gpm
[] FI 3229A
[] FI 3229B
[] FI 3229C o Total Flow FI 3229 OR
- Check any SG NR level > 31% {48%}
- WHEN all SG narrow range levels less than 31%{48%}, THEN maintain total AFW flow greater than 395 gpm.
- WHEN at least two SG narrow range levels greater than 28% AND TDAFWP NOT required, THEN stop TDAFWP.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7/8 Page 20 of 41 Event
Description:
Steam Line Break Inside CTMT During ESP-0.1 EEP-0, Reactor Trip or Safety Injection, v45 Time Pos. Expected Actions/Behavior Comments RO (step 8.4) WHEN SG narrow range level greater than 31%{48%}, THEN maintain SG narrow range NOTE: [CA] step -
level 31%-65%{48%-65%}.
Control MDAFWP flow.
[] A TRN reset
[] B TRN reset MDAFWP TO 1A/1B/1C SG B TRN
[] FCV 3227 in MOD Control TDAFWP flow.
TDAFWP FCV 3228
[] RESET reset TDAFWP SPEED CONT
[] SIC 3405 adjusted RO (step 9) Check RCS temperature.
IF any RCP running, THEN check RCS average temperature - STABLE AT OR APPROACHING 547°F.
[] TI 412D
[] TI 422D
[] TI 432D RO (step 9 RNO) IF RCS temperature less than NOTE: RNO column since 547°F and falling, THEN perform the RCS temp will be <547°F following.
(step 9.1.1) Verify steam dumps closed.
STM DUMP INTERLOCK
[] A TRN in OFF RESET
[] B TRN in OFF RESET (step 9.1.2) Verify atmospheric reliefs closed on MCB
[] Demand at 0 and minimum red light LIT (step 9.1.3) Control total AFW flow to minimize RCS cooldown, AFW FLOW TO 1A(1B,1C) SG
[] FI 3229A
[] FI 3229B
[] FI 3229C AFW TOTAL FLOW
[] FI 3229 IF MSIVs are closed THEN proceed to step If MSIVs are closed then 9.1.8 RNO column requires IF MSIVs are open, THEN isolate steam breaking condenser vacuum loads in the turbine building while continuing with RNO step 9.1.6. NOTE: Will call TBSO to accomplish this task
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7/8 Page 21 of 41 Event
Description:
Steam Line Break Inside CTMT During ESP-0.1 EEP-0, Reactor Trip or Safety Injection, v45 Time Pos. Expected Actions/Behavior Comments RO (step 10) Check pressurizer PORVs and spray valves. [CA] step -
WHEN pressurizer pressure less than 2335 psig, THEN verify both PRZR PORVs closed.
Verify both PRZR PORVs indicate CLOSED Check PRZR PORV temperature STABLE OR FALLING.
[] PORV Temp TI-463 Check PRT parameters STABLE or FALLING.
[] PRT LVL LI-470
[] PRT TEMP TI-471 WHEN pressurizer pressure less than 2260 psig, THEN verify normal pressurizer spray valves closed OR in the process of closing.
[] PK 444C
[] PK 444D Check any PRZR PORV ISO - OPEN RO (step 11) Check RCP criteria.
Check SUB COOLED MARGIN MONITOR indication - GREATER THAN 16°F{45°F}
SUBCOOLED IN CETC MODE RO (step 12) Monitor charging pump miniflow NOTE: Based on RCS criteria. pressure, close miniflows <
Control charging pump miniflow valves based 1300 psig.
on RCS pressure.
[] PI 402A
[] PI 403A Diagnostics The SRO will direct the parameters to be reviewed and will determine appropriate procedure to transition to.
SRO (step 13) Check SGs not faulted. The 1B Steam Generator Will
[] Check no SG pressure - FALLING IN AN be Faulted an MSIVs cannot UNCONTROLLED MANNER OR LESS be shut. Transition to FRP-Z.1 THAN 50 psig. (Page 21) or EEP-2 (Page 23) should occur.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7/8 Page 22 of 41 Event
Description:
Steam Line Break Inside CTMT During ESP-0.1 FRP-Z.1, Response to High CTMT Pressure, v15.0 Time Pos. Expected Actions/Behavior Comments SRO Direct transition to EEP-2 or FRP-Z.1 See EEP-2 (page 23) if FRP-Z.1 not entered RO (step 1) Verify PHASE A CTMT ISO -
ACTUATED.
[] MLB-2 1-1 lit
[] MLB-2 11-1 lit (step 2) Check all MLB-2 lights - LIT.
- Verify containment ventilation isolation.
- Verify all containment purge dampers-CLOSED.
- Verify containment mini purge dampers -
CLOSED.
- Stop MINI PURGE SUPP/EXH FAN.
RO (step 3) Check if containment spray is NOTE: [CA] step -
required.
- Containment pressure - HAS RISEN TO GREATER THAN 27 psig.
- Verify PHASE B CTMT ISO - Critical task Start the 1B CS pump (Step ACTUATED 3.3) OR Open MOV8020A (Step 3.4.3 RNO) before a
- Verify containment spray pumps - Red Path challenge RUNNING develops to the containment
- Check containment spray flow in both CSF trains - > 0 gpm.
CS FLOW on FI 958A and FI 958B = 0 BOP Check all MLB-3 lights - LIT.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7/8 Page 23 of 41 Event
Description:
Steam Line Break Inside CTMT During ESP-0.1 FRP-Z.1, Response to High CTMT Pressure, v15.0 Time Pos. Expected Actions/Behavior Comments BOP (step 4) Verify containment fan cooler alignment.
Verify all available containment fan coolers -
STARTED IN SLOW SPEED.
CTMT CLR FAN SLOW SPEED
[] 1A
[] 1B - TRIPPED
[] 1C
[] 1D - DID NOT START Verify associated emergency service water outlet valves - OPEN.
EMERG SW FROM 1A(1B,1C,1D) CTMT CLR
[] Q1P16MOV3024A
[] Q1P16MOV3024B
[] Q1P16MOV3024C
[] Q1P16MOV3024D BOP (step 5) Verify MSIV and bypass valves MSIVs Will not close BOP (step 6) Check if feed flow should be isolated to any SG.
Check any SG pressure - FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.
Verify all faulted SG main feed stop valves -
CLOSED.
SRO/ Evaluation - IF all SGs faulted THEN Reduces AFW to 20 gpm per BOP maintain 20 gpm AFW flow to each SG. SG SRO Goes to procedure and step in effect Most likely will be E-0
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7/8 Page 24 of 41 Event
Description:
Steam Line Break Inside CTMT During ESP-0.1 EEP- 2.0, Faulted Steam Generator Isolation, v15.0 Time Pos. Expected Actions/Behavior Comments BOP (step 1) Verify all MSIV and bypass valves MSIVs will not close
- CLOSED.
Place handswitches for all MSIVs to the CLOSED position (6 total)
SRO (step 2) Check if any SG not faulted. Transitions to ECP-2.1 (next Check pressure in at least one SG - STABLE page)
OR RISING.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7/8 Page 25 of 41 Event
Description:
Steam Line Break Inside CTMT During ESP-0.1 ECP-2.1, Uncontrolled Depressurization of All Steam Generators, v24.0 Time Pos. Expected Actions/Behavior Comments SRO (Step 1) [CA] IF any SG pressure rises NOTE: [CA] step during performance of this procedure, THEN go to FNP-1-EEP-2, FAULTED STEAM GENERATOR ISOLATION.
BOP (Step 2) Check secondary pressure 1A MSIV Closes boundary isolated.
2.1 Verify all main steam isolation and bypass valves CLOSED.
[] Q1N11HV3369A
[] Q1N11HV3369B
[] Q1N11HV3369C
[] Q1N11HV3370A
[] Q1N11HV3370B
[] Q1N11HV3370C 1A(1B,1C) SG MSIV - BYPASS
[] Q1N11HV3368A
[] Q1N11HV3368B
[] Q1N11HV3368C
[] Q1N11HV3976A
[] Q1N11HV3976B
[] Q1N11HV3976C (Step 2.1 RNO) Place the associated test switch in the TEST position 1A - 3369A/70A 1B - 3369B/70B 1C - 3369C/70C
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7/8 Page 26 of 41 Event
Description:
Steam Line Break Inside CTMT During ESP-0.1 ECP-2.1, Uncontrolled Depressurization of All Steam Generators, v24.0 Time Pos. Expected Actions/Behavior Comments Verify all faulted SG atmospheric reliefs -
MANUALLY CLOSED.
1A(1B,1C) MS ATMOS REL VLV
[] PC 3371A
[] PC 3371B
[] PC 3371C Verify all faulted SG main feed stop valves - CLOSED.
MAIN FW TO 1A(1B,1C) SG STOP VLV
[] Q1N21MOV3232A
[] Q1N21MOV3232B
[] Q1N21MOV3232C Verify blowdown from all faulted SGs - ISOLATED.
[] Q1G24HV7614A
[] Q1G24HV7614B
[] Q1G24HV7614C SRO Re-evaluates (Step 1) [CA] IF any SG Transitions to EEP-2 pressure rises during performance of this procedure, THEN go to FNP-1-EEP-2, FAULTED STEAM GENERATOR ISOLATION.
End Scenario after transition back into EEP-2 or at discretion of Lead Examiner
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7 Page 27 of 41 Event
Description:
ATTACHMENT 2 of EEP-0 EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments (Step 1) Verify one CHG PUMP in each train - STARTED.
BOP [] A train (1A or 1B) amps > 0
[] B train (1C or 1B) amps > 0 BOP (Step 2) Verify RHR PUMPs - STARTED.
RHR PUMP
[] 1A amps > 0
[] 1B amps > 0 BOP (Step 3) Verify Safety Injection Flow.
(Step 3.1) Check HHSI flow - GREATER THAN 0 gpm.
[] FI 943 BOP (Step 3.2) Check RCS pressure - LESS THAN 275 psig{435 psig}.
BOP (step 3.3) Check LHSI flow - greater than 1.5 X103 gpm
[] 1B RHR HDR FLOW FI-605B BOP (Step 4) Verify each SW train - HAS TWO SW PUMPs STARTED.
[] A train (1A,1B or 1C)
[] B train (1D,1E or 1C)
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7 Page 28 of 41 Event
Description:
ATTACHMENT 2 of EEP-0 EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments BOP (Step 5) Verify each train of CCW -
STARTED.
(Step 5.1) Verify one CCW PUMP in each train- STARTED.
[] FI 3043CA > 0 gpm OR
[] FI 3043BA > 0 gpm B train HX 1A or 1B CCW FLOW
[] FI 3043AA > 0 gpm OR
[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM 1A(1B, 1C) CCW HX
[] Q1P16FI3009AA > 0 gpm
[] Q1P16FI3009BA > 0 gpm
[] Q1P16FI3009CA > 0 gpm (Step 5.3) Check instrument air available.
Verify at least one air compressor started.
AIR COMPRESSOR
[] 1A
[] 1B
[] 1C Check INST AIR PRESS PI 4004B greater than 85 psig.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7 Page 29 of 41 Event
Description:
ATTACHMENT 2 of EEP-0 EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments BOP (step 6) Verify containment ventilation isolation.
Verify containment purge dampers -
CLOSED.
[] 3197
[] 3198D
[] 3198C
[] 3196
[] 3198A
[] 3198B Verify containment mini purge dampers -
CLOSED.
CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D
[] 2866C
[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C
[] 2866D
[] 2867D Stop MINI PURGE SUPP/EXH FAN. Will place HS to STOP BOP (step 7) Verify containment fan cooler alignment.
Verify at least one containment fan cooler per train - STARTED IN SLOW SPEED.
CTMT CLR FAN SLOW SPEED A train
[] 1A [] 1B B train
[] 1C [] 1D Verify associated emergency service water outlet valves - OPEN.
EMERG SW FROM 1A(1B,1C,1D) CTMT CLR
[] Q1P16MOV3024A
[] Q1P16MOV3024B
[] Q1P16MOV3024C
[] Q1P16MOV3024D
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7 Page 30 of 41 Event
Description:
ATTACHMENT 2 of EEP-0 EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments BOP (step 8) Verify AFW Pumps - STARTED.
Verify both MDAFW Pumps - STARTED
[] 1A MDAFW Pump amps > 0
[] 1B MDAFW Pump amps > 0 AND
[] FI-3229A indicates > 0 gpm
[] FI-3229B indicates > 0 gpm
[] FI-3229C indicates > 0 gpm (Step 8.2) Check TDAFW Pump start required.
Condition TSLB Setpoint Coincidence RCP Bus TSLB2 1-1 2680 V 1/2 Detectors Undervoltage 1-2 1-3 on 2/3 Busses Low Low SG TSLB4 28% 2/3 Detectors Water Level 4-1,4-2,4-3 on 2/3 SGs In Any 5-1,5-2,5-3 2/3 SGs 6-1,6-2,6-3 BOP (step 8.3) Verify TDAFWP started.
[] MLB-4 1-3 lit
[] MLB-4 2-3 lit
[] MLB-4 3-3 lit TDAFWP SPEED
[] SI 3411A > 3900 rpm TDAFWP SPEED CONT
[] SIC 3405 adjusted to 100%
Verify TDAFW flow path to each SG.
TDAFWP TO 1A(1B,1C) SG
[] Q1N23HV3228A in MOD
[] Q1N23HV3228B in MOD
[] Q1N23HV3228C in MOD TDAFWP TO 1A(1B,1C) SG FLOW CONT
[] HIC 3228AA open
[] HIC 3228BA open
[] HIC 3228CA open
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7 Page 31 of 41 Event
Description:
ATTACHMENT 2 of EEP-0 EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments BOP (step 9) Verify main feedwater status.
Verify main feedwater flow control and bypass valves - CLOSED.
[] FCV 478
[] FCV 488
[] FCV 498 Verify both SGFPs - TRIPPED.
Verify SG blowdown - ISOLATED.
[] Q1G24HV7614A closed
[] Q1G24HV7614B closed
[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample -
ISOLATED MLB lights lit.
1A(1B,1C) SGBD SAMPLE STEAM GEN ISO
[] MLB1 19-2 lit Q1P15HV3328 closed
[] MLB1 19-3 lit Q1P15HV3329 closed
[] MLB1 19-4 lit Q1P15HV3330 closed BOP (Step 10) Check no MSL isolation actuation signal present.
Signal Setpoint coincidence TSLB LO SG PRESS < 585 psig 2/3 TSLB4 19-2,3,4 Hi stm flow >40% 1/2 on 2/3 TSLB4 16-3,4 and and 17-3,4 18-3,4 Lo-Lo Tavg <543°F 2/3 TSLB2 10-1,2,3 HI-HI ctmt press >16.2 psig 2/3 TSLB1 2-2,3,4 (Step 11) Verify PHASE A CTMT ISO. RNO (Step 11.1) Verify PHASE A CTMT ISO - Step 11.2 Verify PHASE A ACTUATED. CTMT ISO alignment using BOP [] MLB-2 1-1 lit ATTACH 3, PHASE A CTMT
[] MLB-2 11-1 lit ISO 11.2 Check all MLB-2 lights - LIT.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7 Page 32 of 41 Event
Description:
ATTACHMENT 2 of EEP-0 EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments BOP (step 12) Check all reactor trip and reactor trip bypass breakers - OPEN Reactor trip breaker A Reactor trip breaker B Reactor trip bypass breaker A Reactor trip bypass breaker B BOP (step 13) Trip CRDM MG set supply breakers.
1A(1B) MG SET SUPP BKR
[] N1C11E005A
[] N1C11E005B BOP (step 14) Secure secondary components.
Stop both heater drain pumps.
HDP
[] 1A
[] 1B Check any condensate pump started.
IF started, THEN stop all but one condensate pump.
[] 1A
[] 1B If NO condensate pumps are started then place all HSs to STOP 14.3 IF condensate pump operating, THEN verify backup cooling aligned to condensate pumps per FNP-0-SOP-0.0, APPENDIX B, Will call TBSO to TB SO Actions Following A Reactor Trip Or accomplish this.
Safety Injection.
BOP (step 15) Verify both CRACS mode selector switches in the ON position.
CRACS Mode Selector Switch
[] A TRAIN
[] B TRAIN Will call BOOTH to have this accomplished since this is not in the simulator BOP (step 16) WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.
230 KV BKR
[] 810 - OPEN
[] 914 - OPEN
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7 Page 33 of 41 Event
Description:
ATTACHMENT 2 of EEP-0 EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments BOP (step 17) Verify two trains of ECCS equipment aligned.
Perform ATTACHMENT 4, Two Train ECCS Alignment Verification.
End of Attachment 2
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 1 Event # 7 Page 34 of 41 Event
Description:
ATTACHMENT 2 of EEP-0 EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments (Step 1) Verify both ECCS trains aligned.
[] Check DF01 closed
[] Verify DF02 closed
[] Check DG15 closed
[] Verfiy DG02 closed
[] Verify two trains of battery chargers -
energized Amps > 0 (Step 1.6) Verify two trains of ESF equipment aligned.
[] Check all MLB-1 lights LIT Verify charging pump suction and discharge valves - OPEN.
[] Q1E21MOV8132A
[] Q1E21MOV8132B
[] Q1E21MOV8133A
[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO
[] Q1E21MOV8130A
[] Q1E21MOV8130B
[] Q1E21MOV8131A
[] Q1E21MOV8131B (Step 1.7) Verify all post accident containment air mixing system fans - STARTED. (BOP)
POST ACCIDENT MIXING FAN
[] 1A
[] 1B
[] 1C
[] 1D RX CAV H2 DILUTION FAN
[] 1A
[] 1B (Step 1.8) WHEN power restored to any de-energized emergency bus, THEN verify alignment of associated equipment.
BOP (Step 1.9) Verify SFP Cooling in service per Call Radside SO SOP-54.0, Spent Fuel Pit Cooling And Purification System.
End of Attachment 4
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # Event # Page 35 of 41 Event
Description:
Attachment 5 of EEP-0 EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments BOP (Step 1) Check all the following MLB-3 indicating lights lit.
BOP (Step 1 RNO) Verify associated component Verifies component status status. based on below MLB indications.
LIT = Proper status Re-position components as required to place in proper status BOP (Step 2) Verify proper PRF system Goes to SOP-60 (page 35 for operation using FNP-1-SOP-60.0, A train in service and page 38 PENETRATION ROOM FILTRATION for B train in service )
SYSTEM.
BOP (Step 3) Notify control room of phase B Containment isolation status.
End of Attachment 5
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # Event # Page 36 of 41 Event
Description:
Attachment 5 of EEP-0 SOP-60.0, Penetration Room Filtration, v35 A Train Time Pos. Expected Actions/Behavior Comments BOP (step 4.3.1) IF both trains of PRF are Goes to section 4.6 started, THEN secure B train of PRF per section 4.6, Securing B Train of PRF Operation During a LOCA.
BOP (step 4.6.1) Verify the following dampers closed:
SFP to 1A PRF SUPPLY DAMPER Q1V48HV3538A SFP to 1B PRF SUPPLY DAMPER Q1V48HV3538B BOP (step 4.6.2) Verify Phase B reset as indicated by MLB-3 lights 1.1 and 6.1 not lit.
BOP (step 4.6.3) Place 1B PRF exhaust fan Q1E15M001B in automatic by placing the handswitch to STOP and release.
BOP (step 4.6.4) Place 1B PRF recirculation fan Q1E15M002B in automatic by placing the handswitch to STOP and release.
BOP (step 4.6.5) Place 1B PRF RECIRC FAN EXH DAMPER Q1E15HV3356B handswitch to AUTO.
BOP (step 4.6.6) Close 1B PRF RECIRC FAN RECIRC DAMPER Q1E15MOV3361B BOP (step 4.6.7) Return 1B PRF RECIRC FAN RECIRC DAMPER Q1E15MOV3361B switch to AUTO.
BOP (step 4.6.8) Close 1B PRF SUCTION DAMPER Q1E15MOV3362B BOP (step 4.6.9) Return 1B PRF SUCTION Returns to step 4.3.2 DAMPER Q1E15MOV3362B switch to AUTO.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # Event # Page 37 of 41 Event
Description:
Attachment 5 of EEP-0 SOP-60.0, Penetration Room Filtration, v35 A Train Time Pos. Expected Actions/Behavior Comments BOP (step 4.3.2) Verify closed SFP to 1A PRF SUPPLY DAMPER Q1V48HV3538A (BOP).
BOP (step 4.3.3) Verify closed SFP to 1B PRF SUPPLY DAMPER Q1V48HV3538B (BOP).
BOP (step 4.3.4) Verify Phase B reset as indicated by MLB-3, lights 1.1 and 6.1 not lit BOP (step 4.3.5) Verify open 1A PRF SUCTION DAMPER Q1E15MOV3362A.
BOP (step 4.3.6) Verify 1A PRF recirculation fan Q1E15M002A started.
BOP (step 4.3.7) Verify open 1A PRF RECIRC FAN EXH DAMPER Q1E15HV3356A.
BOP (step 4.3.8) Verify 1A PRF exhaust fan Q1E15M001A started.
BOP (step 4.3.9) Verify open 1A PRF EXH FAN DISCH DAMPER Q1E15HV3357A.
BOP (step 4.4.10) IF required to maintain Evaluates P - May or may penetration room pressure at least - 0.5 IN not perform this step. If not WC as indicated by PENE RM TO ATMOS then Returns to Attachment 5 P PDI 3367A and PDI 3367B, AND power of E-0 to A train PRF is available, THEN place the A train of PRF in service as follows:
BOP (step 4.4.10.1) Verify open 1A PRF SUCT DAMPER Q1E15MOV3362A.
BOP (step 4.4.10.2) Verify 1A PRF recirculation fan started.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # Event # Page 38 of 41 Event
Description:
Attachment 5 of EEP-0 SOP-60.0, Penetration Room Filtration, v35 A Train Time Pos. Expected Actions/Behavior Comments BOP (step 4.4.10.3) Verify open 1A PRF RECIRC FAN EXH DAMPER Q1E15MOV3356A.
BOP (step 4.4.10.4) Verify 1A PRF exhaust fan started.
BOP (step 4.4.10.5) Verify open 1A PRF EXH Returns to Attachment 5 of FAN DISCH DAMPER E-0.
Q1E15HV3357A.
End of Section
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # Event # Page 39 of 41 Event
Description:
Attachment 5 of EEP-0 SOP-60.0, Penetration Room Filtration, v35 B Train Time Pos. Expected Actions/Behavior Comments BOP (step 4.4.1) IF both trains of PRF are Goes to section 4.5 started, THEN secure A train of PRF per section 4.5, Securing A Train of PRF Operation During a LOCA.
BOP (step 4.5.1) Verify the following dampers closed:
SFP to 1A PRF SUPPLY DAMPER Q1V48HV3538A SFP to 1B PRF SUPPLY DAMPER Q1V48HV3538B Q1E15MOV336lA switch to AUTO.
BOP (step 4.5.2) Verify Phase B reset as indicated by MLB-3 lights 1.1 and 6.1 not lit.
BOP (step 4.5.3) Place 1A PRF exhaust fan Q1E15M001A in automatic by placing the handswitch to STOP and release.
BOP (step 4.5.4) Place 1A PRF recirculation fan Q1E15M002A in automatic by placing the handswitch to STOP and release.
BOP (step 4.5.5) Place 1A PRF RECIRC FAN EXH DAMPER Q1E15HV3356A handswitch to AUTO.
BOP (step 4.5.6) Close 1A PRF RECIRC FAN RECIRC DAMPER Q1E15MOV3361A BOP (step 4.5.7) Return 1A PRF RECIRC FAN RECIRC DAMPER
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # Event # Page 40 of 41 Event
Description:
Attachment 5 of EEP-0 SOP-60.0, Penetration Room Filtration, v35 B Train Time Pos. Expected Actions/Behavior Comments BOP (step 4.5.8) Close 1A PRF SUCTION DAMPER Q1E15MOV3362A BOP (step 4.5.9) Return 1A PRF SUCTION Returns to step 4.4.2 DAMPER Q1E15MOV3362A switch to AUTO.
BOP (step 4.4.2) Verify closed SFP to 1A PRF SUPPLY DAMPER Q1V48HV3538A (BOP).
BOP (step 4.4.3) Verify closed SFP to 1B PRF SUPPLY DAMPER Q1V48HV3538B (BOP).
BOP (step 4.4.4) Verify Phase B reset as indicated by MLB-3 lights 1.1 and 6.1 not lit.
BOP (step 4.4.5) Verify open B PRF SUCTION DAMPER Q1E15MOV3362B.
BOP (step 4.4.6) Verify 1B PRF recirculation fan started.
BOP (step 4.4.7) Verify open 1B PRF RECIRC FAN EXH DAMPER Q1E15HV3356B.
BOP (step 4.4.8) Verify 1B PRF exhaust fan started.
BOP (step 4.4.9) Verify open 1B PRF EXH FAN DISCH DAMPER Q1E15HV3357B.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # Event # Page 41 of 41 Event
Description:
Attachment 5 of EEP-0 SOP-60.0, Penetration Room Filtration, v35 B Train Time Pos. Expected Actions/Behavior Comments (step 4.4.10) IF required to maintain Evaluates P - May or may penetration room pressure at least -0.5 IN not perform this step. If not WC as indicated by PENE RM TO ATMOS then Returns to Attachment 5 P PDI 3367A and PDI 3367B, of E-0.
AND power to A train PRF is available, THEN place the A train of PRF in service as follows:
BOP (step 4.4.10.1) Verify open 1A PRF SUCT DAMPER Q1E15MOV3362A.
BOP (step 4.4.10.2) Verify 1A PRF recirculation fan started.
BOP (step 4.4.10.3) Verify open 1A PRF RECIRC FAN EXH DAMPER Q1E15MOV3356A.
BOP (step 4.4.10.4) Verify 1A PRF exhaust fan started.
BOP (step 4.4.10.5) Verify open 1A PRF EXH Returns to Attachment 5 of E-0 FAN DISCH DAMPER Q1E15HV3357A.
End of Section
Appendix D Crew Briefing sheet Form ES-D-3 Op-Test No.: FA2014301 Page 1 of 2 Brief This simulator performance scenario is performed in the EVALUATION MODE. You should not direct questions to the evaluators. Otherwise, you should perform as if you were in the MCR.
Your ability to maintain a log is not being graded, but maintaining a rough log is recommended to help during briefs.
If you need to communicate with the Unit 2 operator, call Unit 2 at 2434 or page the Unit 2 Unit Operator.
Respond to what you see. If there is a problem with the simulation, the session will be terminated or adjusted as appropriate based on the specific problem.
Assign operating positions.
Ask for and answer questions.
Appendix D Turnover sheet Form ES-D-3
[ X ] Unit 1 [ ] Unit 2 Shift: Date Off-going SS Oncoming SS [ ]N [X]D Today Part I - To be reviewed by the oncoming Supervisor prior to assuming the shift.
Security Keys A, S, D, SW, X on key ring . SS Unit 4% power, 1340 ppm Cb, MOL 10000 MWD/MTU Status TARGET ZERO STPs/Evolutions: Every Day, Every Job Safely A Train On-Service - A Train Protected 1.0 ; 109.1 No adj. ; 63.7 ; FSP-20,0 ;
Status of Special Testing All MODE 1 STPs are complete. Permission to proceed to MODE 1 has been granted.
General Information
- 1. Shift Goal is to Raise power to 12% and prepare roll the Main Turbine to 1800 rpm
- 2. Shift 1A CTMT Cooler to Fast Speed.
- 3. Current Risk Assessment is GREEN and projected is GREEN
- 4. Aux steam is being supplied from Unit 2
- 5. 1B SGFP is on service with FRV Bypass valves in AUTO
- 6. UOP-1.2 ver 110, is complete through Section 5.0, Step 65. Continue the startup starting at Section 5.0, Step 66.
- 7. Unit 2 is at 100% power with no major issues.
- 8. Disconnect 915 is closed.
9.
10.
Equipment Status Maintain VCT gas pressure 25-30 psig Reactivity Plan Waste Management Status Control rods and steam dumps, and 20 gallon #3 RHT - On Service dilutions as required.
WGS - secured LCO Status Night Orders No New Night Orders Part II Review Shift Complement LCOs Reviewed SS (initials) reviewed as early in shift as possible Part III: STP-1.0 Operator Logs Cond. Report Autolog ELDS & GEN Keys Reviewed/Signed Reviewed Queue Reviewed Spreadsheet Turned Reviewed verified Over
[ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes
Unit One Reactivity Briefing Sheet RCS Temp 549.0 °F Current RCS Borations / Dilutions:
RX PWR 4.0 % Borate Dilute Current Xenon Concentration 2277 PCM 0 Gal. 20 Gal.
Burnup 10000 MWD/MTU Reactivity Additions: 0.00 4.08 PCM As of (Date & Time) 10/2/2013 1:00 Total Reactivity Addition: 4.08 PCM Calculated Burnup 10596 MWD/MTU Net RCS Temperature Effect: 1.01 °F As Of 9/23/14 1133 Net Rx Power Effect: 0.23 %
Assumes constant power since Last Power history update Boron Worth -8.34 PCM/PPM RCS Boron 1340 PPM Power Defect 70 PCM BAT Concentration 7350 PPM MTC -4.05 PCM/°F Current Bank Boric Acid Required for Power reduction Delta Rod Position: 164 Steps With no Control rod movement Power Acid Defect Required Rod Worth DeltaPower (PCM) Delta PPM (Gallons)
Steps Out 1.00% 18 2.07 17 One 6 PCM 2.00% 35 4.14 34 Two 12 PCM 5.00% N/A N/A N/A Five 30 PCM 10.00% N/A N/A N/A Ten 64 PCM 20.00% N/A N/A N/A Twenty 140 PCM 25.00% N/A N/A N/A Fifty 410 PCM 50.00% N/A N/A N/A 75.00% N/A N/A N/A Steps In 100.00% N/A N/A N/A One -6 PCM Two -12 PCM Five -29 PCM a/o w/o Ten -56 PCM RCS B-10 ratio 17.98 16.6 Twenty -105 PCM BAT B-10 ratio 20.1 18.6 Fifty -236 PCM NDR B-10 ratio 19.8 18.3 RCS Blended Flow Makeup Requirements Acid to RMW to dilute 1 PPM( Required FK-113 Borate 1 PPM Gal.) Acid flow Pot (Gal.) Rate Setting (GPM)
Values for Normal 8.4 Gal. 37.1 Gal. 22.2 GPM 5.53 Auto M/U (Bat-100 ppm boron)
Values based on 8.3 Gal. 37.1 Gal. 21.9 GPM 5.44 Actual Bat Concentration Valid For Unit One cycle 24 26 Core Physics Curves:
Curve 5 Rev 29 Curve 27 Rev 28 Curve 34 Rev 46 Curve 57 Rev 35 Curve 57A Rev 25 Printed by 9/23/2014 @ 11:34 AM Copy of U1 reactivity sheet Version 5.2
Scenario #1 FA2014301 Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-37 NRC EXAM SCENARIO #1 Validation time: 100 minutes Validated by: Sorrell, Newell, Smith TRN Supervisor Approval: Billy Thornton Date: 9/24/14 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3
Appendix D Scenario #1 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 1 Op-Test No.: FA2014-301 Examiners: Operators: SRO RO BOP Initial Conditions: 4% power, UOP-1.2, v110, completed thru step 5.65. Ready to perform step 5.66. MOL, 1340ppm Cb; 1BSGFP on service. Aux steam from U-2.
Turnover:
1B SGFP is on service, MFR bypass valves are on service.
Current Risk Assessment is GREEN and projected to remain GREEN.
A Train O/S, A Train protected.
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia SPLIT TRAIN ALIGNMENT Event Malf. Event Type* Event Description No. No.
1 R (RO) Raise Power to 12% using control rods and steam dumps.
N (BOP) 2 N (BOP) Start 1A CTMT Cooler in Fast 3 Imf C (RO) FK-122 Fails open in Auto(P - CT) fk122-A 4 imf mal- I (BOP) R-35A Fails high, automatic actions do not occur rmsip35 A/ TS (SRO) T.S. 3.3.7 Cond A preset 5 imf I (BOP) PT-508 Fails high(P - CT) pt508 6 imf C (RO) 1A RCP trips(P - CT) crcrcp1
_cc3 T.S. 3.4.4 Cond A TS (SRO) 7 Imf mal- M (ALL) Steam break inside containment, MSIVs will not close, Automatic mss1B /
Preset C (RO) SI is blocked (CT-2) 8 Preset / C (BOP) 1B CS pump does not auto start. (*CT-3) dmf crsh001 MOV 8820A does not open. (*CT-3) c_cc5 *1 CS spray pump required (Orange Path on Z until CS established)
After ECP 2.1 entry and 27psig in containment MSIVs close.
Terminate on transition out of ECP-2.1 to EEP-2 or examiners discretion (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley October 2014 exam Page 2 of 8
Appendix D Scenario 1Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Load in IC-211 and sim IC snap directory 1340 ppm Cb; 1BSGFP on service. Aux steam from U-2 Base IC is IC-33 RUN RUN simulator 0 0 Generic setup:
bat generic_setup_HLT.txt 0 0 Quick setup (all items with
- are included):
bat ILT37_1.txt PRESETS 7 Fail auto SI signals, Manual SI works
- CMFmalf / csftyinj_cc1 / open CMFmalf / csftyinj_cc11 / open 4 3622, 3624 and 3626 will not close on hi rad
- Cmf mal / chvh3622_d_cc3 closed Cmf mal / chvh3624_d_cc3 closed Cmf mal / chvh3626_d_cc3 closed 7 1A MSIVs will not close on the auto or manual closure
- CMFmalf / crsh001a_cc5 / open CMFmalf / cmsh002a_d_cc5 / open CMFmalf / crsh001a_opos3 / open CMFmalf / cmsh002a_d_opos3 / open 7 1B MSIVs will not close on the auto or manual closure
- CMFmalf / crsh001b_cc5 / open CMFmalf / cmsh002b_d_cc5 / open CMFmalf / crsh001b_opos3 / open CMFmalf / cmsh002b_opos3 / open 7 1C MSIVs will not close on the auto or manual closure
- CMFmalf / crsh001c_cc5 / open CMFmalf / cmsh002c_d_cc5 / open CMFmalf / crsh001c_opos3 / open CMFmalf / cmsh002c_opos3 / open 8 1B CS pump does not auto start - will start from MCB
- CMFmalf / cbkp01b_d_cc5/ open MOV 8820A does not open on phase B- will open from MCB
- CMFmalf / cbk8820a_d_cc5 / open Triggers and Commands Farley October 2014 exam Page 3 of 8
Appendix D Scenario 1Booth Operator Guide Form ES-D-1 EXAM MCB setup DEH Clear DEH alarms Select OPS GROUP on MCB monitor IPC Acknowledge computer alarms IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Clear Recorders Caeclearrecorders.cae Remove R35A input to IPC (not modeled on simulator)
Provide a marked up copy of UOP-1.2 v109 completed UOP-1.2 copy thru Section 5.0, Step 65, ready to perform step 66.
FREEZE simulator Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:
Simview / svDataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW / Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE Farley October 2014 exam Page 4 of 8
Appendix D Scenario 1Booth Operator Guide Form ES-D-1 EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and then COLLECT to start collecting data 0 Begin Exam Verify Horns ON: hornflag HORNS ON = TRUE 1 Start of exam Commence Ramp up to 12% power.
2 NRC CUE Start 1A CTMT Cooler per SOP-12.1, Step 4.1 3 NRC CUE FK 122, Charging Flow Controller, Fails HI CNH / FK122-A / 0 / 2 4 NRC CUE R-35A, Control Room Air Intake Radiation Monitor Fails HI MAL / MAL-RMS35A / 1000000 5 NRC CUE PT-508 Fails HI XMT / PT508 / 1400 / 1 6 NRC CUE 1A RCP Trip CMFmalf / cRCRCP1_cc3 / closed 7 Step 3 of ESP- Steam Line Break Inside CTMT 0.1 Malf / MAL-MSS1B / 0.5 Farley October 2014 exam Page 5 of 8
Appendix D Scenario 1Booth Operator Guide Form ES-D-1 EVENT# TIME EVENT DESCRIPTION COMMAND 8 preset 1B CS Pump Does Not Startand MOV-8820A does not open 8 NRC CUE At Step 2 of ECP-2.1, the 1A MSIV (HV-3369A) will shut.
dmf crsh001a_cc5 8 NRC CUE At Step 2 of ECP-2.1, the 1C MSIV (HV-3369C) will shut.
dmf crsh001c_cc5 End of Exam HORNS OFF FREEZE simulator Stop data collection for Simview file svDataCollection.uvl Export data to file with the name of Ensure data file created.
exam2014sen1grpX.txt NOTE: Substitute grpX with grp1, grp2, or grp3 as appropriate.
NOTE: file will be saved in the OPENSIM directory.
When Control board data no longer needed Then Clear recorders for exam security Farley October 2014 exam Page 6 of 8
Appendix D Scenario 1Booth Operator Guide Form ES-D-1 Local operator actions:
EVENT NO. TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 NONE REQUIRED 4 NONE REQUIRED 5 NONE REQUIRED 6 NONE REQUIRED 7 IF REQUESTED 10 minutes after requested, SOP-0.0 actions for a Rx trip/Safety Injection 7 IF REQUESTED 10 Minutes after requested, Isolate TDAFW to SG A, B, or C using the button below (step 5.3 of EEP-2.0) 7 IF REQUESTED 5 Minutes after requested, perform step 2.5 of ECP.2.1 On HSDP F Place TDAFWP STM SUPP from 1C SG HV3235B in LOCAL Place TDAFWP STM SUPP from 1B SG HV3235A/26 in LOCAL ON HSDP D Place TDAFWP STM SUPP from 1C SG HV3235B to STOP and release.
Place TDAFWP STM SUPP from 1B SG HV3235A/26 to STOP and release.
Farley October 2014 exam Page 7 of 8
Appendix D Scenario 1Booth Operator Guide Form ES-D-1 Communications sheet EVENT NO. TIME Communication:
ALL AS REQUIRED SSS, SM and Dispatcher:
(Standard Repeat back failure, procedure entered, plant status, CR in the cue communications to and that type of communications.
inform supervision) 1 IF REQUESTED Disconnect 915 has already been closed FNP-1-STP-42.2 has been performed SAT within the last 30 days FNP-1-STP-151.5, Main Turbine Overspeed Test is not desired to be performed No maintenance has been performed on the main generator voltage regulator/exciter system I will check one cooler group (fans and pumps) operating on each main transformer 2 IF REQUESTED 3 minutes after requested - FK-122 is 100% open with no apparent damage 3 NONE EXPECTED 4 IF REQUESTED 3 minutes after requested - TSC ventilation is aligned in recirculation mode 1 minutes after requested -
R-35A is in high alarm.
R-35A is pegged high with the RED high light LIT.
R-35B is reading normal mid range scale I will verify both Control Room Doors are closed 5 minutes after requested HP survey of MCR area normal 5 NONE EXPECTED 6 NONE EXPECTED 5 minutes after requested DA04 is tripped open with no apparent damage 7/8 IF REQUESTED 10 minutes after requested SOP-0.0 actions for a Rx trip/Safety Injectionare complete I will verify SFP cooling in service per SOP-54.0 10 minutes after requested step 5.3 of EEP-2.0 is complete V017A is closed 5 minutes after requested step 2.5 of ECP-2.1 is complete Farley October 2014 exam Page 8 of 8
Appendix D Scenario #2 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 2 Op-Test No.: FA2014-301 Examiners: Operators: SRO RO BOP Initial Conditions: 25% power, UOP-3.1, v119.0, at step 5.3. Ramping up. MOL, 1340 ppm Cb; 1B SGFP on service. Aux steam from U-2.
Turnover:
Current Risk Assessment is GREEN and projected to remain GREEN.
A Train O/S, A Train protected.
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia SPLIT TRAIN ALIGNMENT Event Malf. Event Type* Event Description No. No.
1 R (RO) Place impulse loop in service and commence ramp to 100%
N (BOP) 2 loa- C (BOP) CST Ruptured by crane cfw001 TS (SRO) TS 3.7.6 Cond A imf 3 I (RO) TK-144 fails high in Auto, TCV-143 fails to auto divert TK144-A 10 /
preset 4 Imf I (RO) LT-459 fails low (P-CT) lt459 TS (SRO) TS 3.3.1 Function 9 Cond M 5 preset N (BOP) During letdown restoration LCV-459 will not open. Requires Excess letdown to be placed in service.
6 Imf I (BOP) PT-464 fails high (P-CT) pt464 7 Imf mal- M (ALL) LOSP eps1 /
preset 1B DG trips after auto start and cannot be started 4 minutes after LOSP Unit 2 SI occurs 1C DG fails to align to unit 1 Loss of ALL AC 8 preset C (BOP) TDAFW pump fails to auto start (CT-23) 9 preset C (RO) Power restored by starting 2C DG (CT- 24)
Unit 2 has no B train service water At least one service water pumps must be manually started prior to the 2C DG tripping(CT-25)
Terminate when 2C diesel running with Service Water supplied (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley October 2014 exam Page 1 of 4
Appendix D Scenario 2 Presets Form ES-D-1 PRESETS 8 Prevent TDAFWP auto start
- CMFmalf / cMS3235B-cc1 / open CMFmalf / cms3235b_cc2 / open CMFmalf / cms3235a_cc1 / open CMFmalf / cms3235a_cc2 / open 7 1B DG trips on AUTO start TRG 2 Malf / mal-eps4b / 30 sec delay / Trg 2 7 Unit 2 SI - 2B DG trips on loadshed TRG 2 CMFmalf / csftyinj_cc21 / closed / 240 sec delay / Trg 2 Malf / mal-eps4c / 245 sec delay / Trg 2 7 1C DG blocked from auto or manual closure
- CMFmalf / cbk1DH07_d_cc18 / open 9 Block D & E SW pumps from starting after 1B DG trips TRG 2 CMFmalf / cNCPsw1F_d_cc5 / 35 sec delay / open CMFmalf / cNCPsw1F_d_cc6 / 35 sec delay / open CMFmalf / cNCPsw1E_d_cc5 / 35 sec delay / open CMFmalf / cNCPsw1E_d_cc6 / 35 sec delay / open 3 Fails TCV-143 from diverting on high temperature.
- CMFmalf / ccvT143_d_cc1 / closed Triggers and Commands 5 Event Trigger 1 - monitors LCV-459 valve position, once TRG 1 closed will not reopen Trgset 1 x13o133c Trg 1 imf rcvl459-m 0 2 7 Event Trigger 2 - 1B DG start lamp. 1B DG will trip after it TRG 2 starts.
Trgset 2 xg1ba02 7 Event Trigger 3 - 1C DG Trips when DF08-2 closes TRG 3 Trgset 3 x4bo007o Trg 3 imf mal-dsg009 Farley October 2014 exam Page 2 of 4
Scenario 2 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 25% power, , UOP-3.1, v119.0, at step 5.3. Ramping up. MOL, 1340 ppm Cb; 1B SGFP on service. Aux steam from U-2.
Turnover:
Current Risk Assessment is GREEN and projected to remain GREEN.
A Train O/S, A Train protected.
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia.
Event 1 Commence Ramp up to 100% power.
Verifiable actions: RO uses rods and boron to maintain Tavg/Tref. BOP will place impulse loop in service, insert ramp target and rate and commence ramp.
Event 2 CST ruptured by crane.
Verifiable actions: BOP aligns Service Water to Auxiliary Feed Pump suction. TS 3.7.6 Condition A Event 3 TK-144 fails high in Auto, TCV-143 fails to auto divert Verifiable Actions: RO take manual control of TK-144 and raise cooling flow to letdown and place TCV-143 in the VCT position.
Event 4 LT-459 fails low. (P-CT)
Verifiable Actions: Take manual control of charging to control PRZR level and deselect the failed channel. TS 3.3.1 Condition M Event 5 During restoration of Letdown, LCV-459 fails to open.
Verifiable Actions: BOP place excess letdown on service.
Event 6 PT-464 fails high. (P-CT)
Verifiable actions: BOP takes manual control of SGFP speed as SGFP speed will increase as will SGWL.
Event 7 Loss of Offsite Power (LOSP). 1B DG trips after auto start and cannot be started. 4 minutes after the LOSP, a Unit 2 SI occurs and 1C DG fails to align to Unit1 causing a loss of all AC.
Event 8 TDAFWP fails to auto start.
Verifiable actions: BOP manually starts the TDAFWP (CT).
Event 9 Power restored by starting 2C DG (CT), Unit 2 has no Service Water (SW) and Unit 1 Service Water pumps do not auto start.
Verifiable actions: RO manually start SW pumps to support 2C DG. (CT)
Terminate when 2C DG is running with SW supplied.
UOP-3.1/ARP/SOP/ARP/AOP-16/AOP-100/SOP/AOP-100/EEP-0/ECP-0.0 Farley June 2014 exam Page 3 of 4
Scenario 2 Critical Task sheet Appendix D Form ES-D-1 Sheet CRITICAL TASK SHEET
- 1. Energize at least one ac emergency bus [before placing safeguards equipment hand switches in the pull-to-lock position] (CT-24)
- 3. Manually start at least one SW pump such that the EDG does not fail because of damage caused by engine overheating. (CT-25)
SCENARIO Low power instrument and component failures with a loss of all AC.
OBJECTIVE/ The team should be able to:
OVERVIEW: ramp up from 25% power, respond to a CST rupture and aligns AFW suction, respond to a letdown cooling valve malfunction ,
respond to a PRZR level instrument malfunction, establish excess letdown as required when letdown cannot be restored, respond to a transmitter malfunction that affect SGFP speed, respond to a LOSP will become a complete loss of all AC, manually start the TDAFWP and SW pumps supplying the 2C DG, Terminate when power is restored on the 2C DG and SW pumps are running.
Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes
- 1. Total malfunctions (5-8) 7
- 2. Malfunctions after EOP entry (1-2) 2
- 3. Abnormal events (2-4) 2
- 4. Major transients (1-2) 1
- 5. EOPs entered/requiring substantive actions (1-2) 0
- 6. EOP contingencies requiring substantive actions (0-2) 1
- 7. Critical tasks (2-3) 5 Farley June 2014 exam Page 4 of 4
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 2 Event # 1 Page 1 of 22 Event
Description:
Ramp up to 100% power Indications Available Annunciators: NA Note to Examiner The turnover sheet directs the crew to place the IMP PRESS LOOP in service per UOP-3.1 section 5.3. When simulator is taken to run the crew is expected to increase Reactor power to at least 30% IAW UOP-3.1. At 30% the NRC will evaluate going to the next event. This evolution will take approx. 15 -20 minutes UOP-3.1, Startup of Unit from Hot Standby to Minimum Load, version 119, Section 5 Time Pos. Expected Actions/Behavior Comments RO/BOP Begin to increase reactor power to 100% Manual adjustment of rods with following controls. (not more than 3 steps at a Manual adjustment of control rods time)
Turbine Control - Place and Boron Impulse Loop in service and Main Turbine with impulse insert ramp target/rate and pressure loop in service commence the ramp.
Dilutions Dilutions should be performed per SOP-2.3 (see page 3 for dilution, page 4 for repetitive dilution)
SRO Monitor reactor power, main turbine ramp, and reactivity adjustments as reactor power rises.
BOP (Step 3 and Following) (Step 2.b ) On DEH check that (Step 3.a) Verify Turbine on HOLD. the student :
(Step 3.b) Check that the DEH computer point PIA, FIRST STAGE Depresses Point Data Entry PRESSURE #1 has stable indication. Types PIA (Step 3.c) On the FEEDBACK STATUS Depresses select button DISPLAY, move the cursor to IMP PRESS LOOP OUT.
(Step 3.d) Depress the SELECT key.
(Step 3.e) Verify IMP PRESS LOOP is highlighted in reverse video.
(Step 3.f) Depress the START key (Step 3.g) Verify FEEDBACK STATUS indicates IMP PRESS LOOP IN.
RO (step 1) Begin raising turbine load to 50% Ramp Rate should be limited power, using the appropriate DEH to less than or equal to 2 Controls MW/min per UOP-1.2 Section 2.1.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 2 Event # 1 Page 2 of 22 Event
Description:
Ramp up to 100% power BOP (step 4) As load increases to 30% power, perform the following:
(step 4.a) Monitor SGFP suction Pressure (step 4.b) Verify proper SGFP speed control and maintain proper DP (step 4.c) Check that the IR HI LEVEL ROD STOP drawer lights are illuminated when reactor power exceeds 25%
(step 4.d) Verify that the main turbine drain vales close at approximately 170 MW.
(step 4.d.1) Check on the Secondary Valve Indication Panel for the following indication illuminated.
TURB 518, 521, 524, 519, 522, 525, 520, 523, and 526 Closed (step 4.d.2) If any turbine drain valve indicate open perform the following:
Place Turb DRN VLVS SEL Switch in MAN (step 4.e) Align FWH Extraction Line Drains and Startup vents per SOP-20.0 when turbine power exceeds 15-20%
(step 4.f) Verify FWH condensate bypass valves fully closed.
(step 4.g) When reactor power exceeds 30%, verify on the Bypass and Permissive panel that the Low Power Low Flow Trip Block P-8, permissive light NOT illuminated.
When 30% power is reached or at the discretion of the Lead Examiner move to next event.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 2 Event # 1 Page 3 of 22 Event
Description:
Ramp up to 100% power SOP-2.3, CVCS RX Makeup Control System, Dilution, Appendix C, v60.1 Time Pos. Expected Actions/Behavior Comments RO 2.0 Dilution 2.1 IF necessary, THEN set the total batch integrator to the desired quantity.
2.2 IF necessary, THEN adjust LTDN TO VCT FLOW LK 112 setpoint as desired.
2.3 Position the MKUP MODE CONT SWITCH to STOP.
2.4 Position the MKUP MODE SEL SWITCH to DIL or ALT DIL.
2.5 IF using ALT DIL AND it is desired to bypass the VCT, THEN place the MKUP TO VCT valve Q1E21FCV114A in close.
2.6 Position the MKUP MODE CONT SWITCH to START.
2.7 Verify proper dilution operation by observing the following:
- IF using ALT DIL, MAKEUP TO CHG PUMP SUCTION HDR FCV113B opens.
- FCV-114A opens, unless bypassing VCT.
- RMW TO BLENDER Q1E21FCV114B opens.
- Reactor makeup flow displayed on FI-168 MAKEUP FLOW TO CHG/VCT.
Verify the dilution automatically stops when the total flow batch integrator reaches setpoint:
- Reactor makeup flow returns to zero as displayed on FI-168
- MKUP TO VCT , FCV114A closes.
- RMW TO BLENDER, FCV114B closes.
- IF ALT DIL was used, THEN FCV-113B closes.
2.9 IF VCT was bypassed, THEN verify MKUP TO VCT valve Q1E21FCV114A (Q1E21V339) in AUTO.
2.10 Position the MKUP MODE SEL SWITCH to AUTO.
2.11 Position the MKUP MODE CONT SWITCH to START.
2.12 IF LK 112 setpoint was adjusted per Step 2.2, THEN return setpoint to that required for current conditions.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 2 Event # 1 Page 4 of 22 Event
Description:
Ramp up to 100% power RO Repetitive Dilutions 2.1 IF necessary, THEN set FIS-168 Total Flow Batch Integrator to the desired quantity.
2.2 The Reactor Makeup Control system has been previously aligned for Dilution or Alternate Dilution.
2.3 Position the MKUP MODE CONT SWITCH to START.
2.4 Verify proper dilution operation by observing the following:
-IF using ALT DIL, MAKEUP TO CHG PUMP SUCTION HDR FCV113B opens.
MKUP TO VCT FCV114A opens, unless bypassing VCT.
RMW TO BLENDER FCV114B opens.
Reactor makeup flow is displayed on FI-168 MAKEUP FLOW TO CHG/VCT.
2.5 Verify the dilution automatically stops when the total flow batch integrator reaches its setpoint by observing the following:
Reactor makeup flow returns to zero as displayed on FI-168 MAKEUP FLOW TO CHG/VCT.
MKUP TO VCT FCV114A closes or is closed if bypassing theVCT.
RMW TO BLENDER FCV114B closes.
IF ALT DIL was used, THEN MAKEUP TO CHG PUMP SUCTION HDR FCV113B closes.
2.6 IF repetitive dilutions are no longer required THEN verify the system is aligned for Automatic makeup per Steps 2.8 through 2.11 of Appendix B.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 2 Event # 2 Page 5 of 22 Event
Description:
CST rupture -base plate crack from bottom to top Indications Available Annunciators: Recognize indications of CST LEVEL
- CST LVL HI-LO (JE5) Decreasing:
- CST LVL LO-LO A TRN and B TRN (JD4 - LI-4005 B decreasing and JE4) - Computer alarms Note to Examiner CST level will decrease over a 5 min time frame to 14 feet. The first alarm comes in at 16 feet so if the crew does not notice the decreasing level, the first alarm will be at about the 4 minute mark.
The DBSO will be sent out to look for the problem and then a report will be given about a crane accident. The CST level will continue to fall to 0 feet.
150,000 gallons = 12 feet CST Level ARP-1.9, JE5, JD4, JE4, ver 49.0 Time Pos. Expected Actions/Behavior Comments SRO Direct ARP reference (JE5) and a call to the DBSO to look for problems.
BOP (JE5 step 2) manually close CP-4055F HOTWELL FILL CONTROLLER, to avoid collapsing tank diaphragm.
BOP (JE5 step 3) IF CST level is low, and SGBD Call Radside SO and have is on service, THEN secure SGBD. SGBD secured (JE5 step 4) IF a system rupture is indicated, DBSO will provide report.
THEN notify appropriate personnel to locate and isolate the leaking piping.
BOP (JE5 step 7) Direct DBSO to commence filling the tank (Unless report of rupture has come in)
SRO (JE4.JD4 step 1) Monitor condensate storage tank level on LI-4005B, LI-4132A and LI-4132B to verify validity of alarm Direct BOP to monitor this issue SRO (JE4, JD4 step 2) Make a decision to do the See page 7 for SOP-22, following: version 71.0, section 4.10 IF Auxiliary Feedwater is required and Tank actions Level if < 5.3 feet, THEN shift Auxiliary Feed Pump Suctions to the Service Water System per SOP-22.0, AUXILIARY FEEDWATER SYSTEM.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 2 Event # 2 Page 6 of 22 Event
Description:
CST rupture -base plate crack from bottom to top ARP-1.9, JE5, JD4, JE4, ver 49.0.
Time Pos. Expected Actions/Behavior Comments SRO (JE4, JD4 step 9) Evaluate Tech Specs 3.7.6 condition A Verify by administrative means OPERABLILITY of backup water supply w/i 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> and restore the CST to OPERABLE status w/I 7 days TECHNICAL SPECIFICATION 3.7.6, Condensate Storage Tank (CST)
The CST shall be OPERABLE. (> 150,000 GAL)
SRO CONDITION REQUIRED ACTION COMPLETION TIME A. CST A.1 Verify by administrative 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> inoperable. means OPERABILITY of AND backup water supply. Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> AND thereafter A.2 Restore CST to OPERABLE status. 7 days SRO Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report.
SRO Inform the SM of the failure and Tech Spec entry
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 2 Event # 2 Page 7 of 22 Event
Description:
CST rupture -base plate crack from bottom to top SOP-22.0, AUXILIARY FEEDWATER SYSTEM, version 71.0 section 4.10 Time Pos. Expected Actions/Behavior Comments BOP (step 4.10.1) Notify Shift Chemist that SW will be added to the SGs.
BOP (step 4.10.2) Verify service water is in operation per SOP-24.0, SERVICE WATER SYSTEM maintaining proper SW pressure.
BOP (step 4.10.3) Open MDAFWP SW SUPP: BOP (2504-N) or Back panel (BOP key operated switches) handswitches
[] MOV3209A
[] MOV3209B BOP (step 4.10.4) Open: (BOP) BOP (2504-N) or Back panel
[] MDAFWP SW SUPP MOV3210A handswitches
[] TDAFWP SW SUPP MOV3216.
BOP (step 4.10.4.1) IF necessary to align This step is N/A TDAFWP suction from B Train service water, THEN perform the following:
When SW is aligned to the AFW pumps and Tech Specs have been evaluated or at the discretion of the Lead Examiner move to next event.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 2 Event # 3 Page 8 of 22 Event
Description:
TK-144 fails HIGH and TCV-143 fails to AUTO Divert Indications Available Annunciators: Recognize indications of TK-144 failing high
- LTDN TO DEMIN DIVERTED-TEMP HI - TI-143 indicating off scale high (>200°F)
(DF1) - TI-144 indicating off scale high (>200°F)
- Possible boration and RCS temperature decrease if prolonged ARP-1.4, DF1, rev 54.2 Time Pos. Expected Actions/Behavior Comments SRO Direct entry into DF1 ARP RO (step 1) Verify Q1E21TCV143 has diverted Operator will have to place letdown flow to VCT to bypass demins TCV-143 to the VCT position
- TCV-143 white light LIT (VCT) on MCB manually.
NOTE: TCV-143 may not (step 2) Monitor charging and letdown flows require transfer to VCT and temperatures. position if prompt operator FI 122, FI 150, TI 140, TI 144 and 143 action prevents high temperature condition.
(step 3) Try to take manual control of TCV 144 (step 4) Adjust charging or letdown flow as required to reduce the letdown flow temperature. Operator will take manual control of TCV-144 SRO (step 5) When letdown temperature is This step may be directed but returned to normal direct removing returning the next event should begin TCV-143 to DEMIN IAW SOP-2.1 prior to execution.
When letdown temperature has returned to normal or at the discretion of the Lead Examiner then move to the next event
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 2 Event # 4 Page 9 of 22 Event
Description:
LT-459, PZR LVL TRANSMITTER Fails LOW Indications Available Annunciators: Recognize indications of LT-459 failing low:
- CHG HDR FLOW HI-LO (EA2) - FT-122, CHG FLOW
- PZR LVL LO HTRS OF LTDN SEC (HA3) - LT-112/115, VCT level
- PRZR LVL DEV LO (HB2) - LT-459, 460, 461, Actual Przr level
- PRZR HTR CONT TRBL (HD4)
Note to Examiner Based upon the component malfunction AOP-100 is the expected entry procedure but AOP-16.0 may be entered if crew determines event is a CVCS malfunction. AOP-16.0 entry will be directed by step 5 of AOP-100 when normal letdown cannot be established due to failure of LCV-459.
AOP-100 actions begin on this page.
AOP-16.0 actions begin on page 7.
TS 3.3.1 is on page 8.
AOP-100, Instrumentation Malfunction, section 1.2, v13.0 Time Pos. Expected Actions/Behavior Comments RO (step 1) Check pressurizer level is on or trending to program value RO (step 1 RNO) Take Manual control of FK-122, CHG FLOW controller, and lower the demand to 0 gpm.
RO (step 2) Check RCP Seal Injection 6-13 gpm
[] Adjust as necessary using HIK 186, RCP SEAL INJECTION FLOW CONTROLLER SRO (step 3) Determine if a pressurizer level NOTE:
transmitter/indicator loop has failed LT-459 has failed.
(step 3.1) Failed or erroneous reading on LI459, LI460 or LI461 Operators should select CH (step 3.2) Select unaffected PZR level III/II (461/460) on LS-459Z and channel on LS-459Z CH II or CH III on LS-459Y (Step 3.3) Select unaffected channel on recorder control switch LS/459Y RO (step 4) Check letdown in service TK-144 has failed and should
- Verify Orifice Isolations closed not be returned to service.
- Place TK-144 on Service
- Verify LCV-115A in Auto w/ VCT Lit TCV-143 may be delayed in
- Verify TCV-143 in VCT w/ VCT Lit order to re-establish letdown.
- Open HV-8157A/B, HV-8152, LCV-459, and LCV-460 Letdown will not be available since LCV-459 will fail to open SRO (step 5) Check Letdown flow established Since letdown flow is not established then crew will transition to AOP-16.0
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 2 Event # 4 Page 10 of 22 Event
Description:
LT-459, PZR LVL TRANSMITTER Fails LOW AOP-16.0, CVCS Malfunction, v20.0 Time Pos. Expected Actions/Behavior Comments RO (Step 1) Verify CHG flow adequate to cool Already closed due to letdown previous failure.
CHG FLOW - FI-122A LTDN HX OUTLET FLOW - FI-150 REGEN HX OUTLET TEMP - TI-140 BOP (Step 2) Stop any load change in progress RO (Step 3) If charging line rupture occurs then goto attachment 2 (Step 4) Monitor VCT level (Step 5) Observe CHG HDR PRESS and MOTOR AMPS to ensure proper charging pump operation
- PI-121 and ammeter for chg pump RO (Step 6) Check charging pump - RUNNING RO (Step 7) Check Charging flow FK-122, CHG NOTE: There will be no flow FLOW controller, controlling in AUTO with indicated and FK-122 flow indicated should be maintained shut.
FK- 122, CHG FLOW controller, is taken to manual control -RNO POTENTIAL CRITICAL TASK Adjust SEAL WTR INJECTION HIK-186 as If operators fail to take manual required to maintain RCP seal injection control of FK-122 there may flow 6-13 gpm be a Rx Trip based upon PZR high level.
RO (Step 8) Check DE3 clear Since normal letdown is not available AOP-16.0 will (Step 9) Determine Status of Normal direct placing excess Letdown: letdown on service.
- Manually close charging FK-122, CHG FLOW controller.
- Minimize seal injection between 6-13 gpm
- Direct Chemistry to shutdown the zinc addition system (ZAS)
- If desired due to plant conditions then establish excess Letdown per SOP-2.7
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 2 Event # 4 Page 11 of 22 Event
Description:
LT-459, PZR LVL TRANSMITTER Fails LOW TECHNICAL SPECIFICATION 3.3.1, Reactor Trip System Instrumentation Function 9. Pressurizer Water Level - High Applicable MODES - MODE 1 above the P-7 (Low Power Rx Trip Block) interlock (10%)
Required Channels - 3 SRO CONDITION REQUIRED ACTION COMPLETION TIME M. One Channel M.1 Place Channel in Trip 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Inoperable OR 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> M.2 Reduce THERMAL POWER to < P-7.
When decision made to establish excess letdown move to next event.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 2 Event # 5 Page 12 of 22 Event
Description:
Place Excess Letdown in service SOP-2.7, CVCS Excess Letdown, v12.0 Time Pos. Expected Actions/Behavior Comments CAUTION: Do not exceed 165 F excess letdown heat exchanger outlet temperature.
Excess letdown flow will be limited to approximately 10-15 gpm.
BOP (step 4.1.1/.2) Verify the RCDT system in Will call Radside SO and operation per SOP-50.0, LIQUID WASTE check on status and notify the PROCESSING SYSTEM SO to expect an increase in RCDT level due to excess letdown being placed on service.
BOP (step 4.1.3/.4/.5) Verify the following valves open:
- HV3095
- HV3443
- HV3067 (step 4.1.6) Verify HV-137 is closed (step 4.1.7/.8) Open HV 8153 and 8154 (step 4.1.9) Place excess letdown divert valve Q1E21HV8143 control switch in the RCDT position (step 4.1.10) Slowly throttle open the excess LTDN HX discharge valve Q1E21HCV137 to establish excess letdown flow not to exceed 165 F excess letdown heat exchanger outlet temperature
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 2 Event # 5 Page 13 of 22 Event
Description:
Place Excess Letdown in service SOP-2.7, CVCS Excess Letdown, ver 12.0 Time Pos. Expected Actions/Behavior Comments SRO Should read the Caution in the procedure CAUTION and speak to reactivity changes associated A small portion of excess with placing excess letdown on service. letdown piping can not be flushed to the RCDT (calculated to be approx. one gallon) and there are Should decide and brief the crew on aligning uncertainties associated with excess letdown to the VCT/Charging pump achieving a complete flush.
suction and the expectations on this. This is Therefore, the reactivity affects not required to be done since it will take a associated with directing significant amount of time to do this excess letdown to the evolution. VCT/Charging pump suction must be considered and contingencies established for mitigating the consequences.
SRO Direct crew back to AOP -16.
SRO AOP-16 (Step 9) Determine if normal letdown should be re-established: Normal letdown is still not Check normal letdown malfunction(s) - available.
CORRECTED RO (step 10) Determine status of letdown Excess letdown established flow: Check letdown flow - established SRO (step 10.2) Go to procedure and step in effect When Excess letdown is in service or at the discretion of the Lead Examiner move to next event.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 2 Event # 6 Page 14 of 22 Event
Description:
PT-464, Stm header pressure transmitter, fails HIGH Indications Available Annunciators: Indications of PT-464 failure:
- 1A SG LVL DEV (JF1) - PI-464A increasing to 1200 psig
- 1B SG LVL DEV (JF2) - Rx power increasing
- 1C SG LVL DEV (JF3) - SGFP speed increasing
- SGFP SUCT PRESS LO (KB4)
AOP-100, Instrument Malfunction, Section 1.4, v13.0 Time Pos. Expected Actions/Behavior Comments SRO Directs RO or BOP to address ARPs as time permits 1A, 1B, & 1C SG LVL DEV SRO Directs entry into AOP-100, section 1.4, and performance of immediate actions, then directs subsequent actions BOP (step 1) Maintain SG level at the referenced Step 1 is an Immediate level of 65%. Operator action Take manual control of SGFP speed control NOTE: Step 1 is a continuing SK-509A taken to manual and decreases action step speed POTENTIAL CRITICAL TASK If operators fail to take manual control of SK-509A there may be a Rx Trip based upon SG high level that causes SGFP trip.
SRO (step 1.3) IF a loss of main feedwater has occurred, THEN perform the actions required by AOP-13.0, LOSS OF MAIN FEEDWATER.
SRO (step 2) Set manual trip criteria on SG level (high and low trip setpoints are 82% & 28%
respectively)
BOP (step 3) IF a ramp is in progress, THEN place turbine on HOLD.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 2 Event # 6 Page 15 of 22 Event
Description:
PT-464, Stm header pressure transmitter, fails HIGH AOP-100, Instrument Malfunction, Section 1.4, v13.0 Time Pos. Expected Actions/Behavior Comments BOP (step 4) Adjust speed of SGFPs to maintain approximate DP for the existing power level Unit 1 NO LOAD P is 54 psid for 30%.
Approximate P can be determined from the following MCB indications.
o SGFP DISCH PRESS PI-4003 o SG Pressure indications:
S/G CH II CH III CH IV A S/G PI-4 4 PI-475 PI-476 B S/G PI-484 PI-485 PI-486 C S/G PI-494 PI-495 PI-496 Unit 1 NO LOAD P is 50 psid from 0-28.1%. PROGRAM P is linear from 50-190 psid from 28.1% to 100%. TABLE 1 provides approximate P values for varying power levels.
% POWER DP 30 54 psid 40 73 psid 50 93 psid 60 112 psid 70 132 psid 80 151 psid 90 171 psid BOP (step 5) Check Stm Dumps in the Tavg mode SRO (step 6) Notifies Shift Manager SRO (step 8) Submits a CR & Notifies the Work Week Coordinator At the discretion of the Lead Examiner move to next event.
Op Test No.: FA2014301 Scenario # 2 Event # 7 Page 16 of 22 Event
Description:
Loss of All AC Indications Available Annunciators: Recognize indications of Loss of ALL AC
- Many and various power
- EPB power indication lights not LIT - RCPs tripped
- Components not running Note to Examiner Event will begin with an LOSP and entry into EEP-0 (This page). 1B DG will trip after auto start and A Train DGs will be lost after an SI on the opposite unit (the SI on U-2 will occur 4 minutes after the LOSP). A Loss of All AC will result and ECP-0.0 entry will be required (Page 14)
Events 8 and 9 are incorporated into the response to a loss of all AC power and will occur as the crew progresses through ECP-0.0. Operators may take early actions to start the TDAFWP any time after completion of immediate operator actions.
Event 8 - TDAFWP failure to auto start (Page 15)
Event 9 - Restoration of power with the 2C DG (Page 16)
EEP-0, Reactor Trip or Safety Injection, v45 Time Pos. Expected Actions/Behavior Comments RO/ Immediate Operator actions of EEP-0 Immediate Action steps of BOP (step 1) Check reactor trip. EEP-0 Check all reactor trip breakers and reactor trip bypass breakers - OPEN.
Check nuclear power - FALLING.
Check rod bottom lights - LIT.
(step 2) Check turbine - TRIPPED.
TSLB2 14-1 thru 4 lit (step 3) Check power to 4160 V ESF busses.
4160 V ESF busses - AT LEAST ONE ENERGIZED A Train (F 4160V bus) power available lights lit OR B Train (G 4160V bus) power available lights lit Verify operating diesel generators are being supplied from at least one SW pump
Op Test No.: FA2014301 Scenario # 2 Event # 7 Page 17 of 22 Event
Description:
Loss of All AC EEP-0, Reactor Trip or Safety Injection, rev 45 Time Pos. Expected Actions/Behavior Comments RO/ (step 4) Check SI Status. Transition to ESP-0.1 may BOP (step 4.1) Check any SI actuated indication. occur but entry to ECP-0.0, BYP & PERMISSIVE SAFETY INJECTION Loss of All AC will occur near
[] ACTUATED status light lit the transition out of EEP-0.0 (a
[] MLB-1 1-1 lit U-2 SI will occur 4 minutes
[] MLB-1 11-1 lit after the LOSP and this will cause 1-2A DG to swap to U-2 (step 4.2) Verify both trains of SI- and 1C DG to trip. U-1 will have ACTUATED. no power. U-2 Reactor Trip and
[] MLB-1 1-1 lit AND [] MLB-1 11-1 lit SI will be announced by the Booth Operator 2 minutes after the U-2 SI.).
Op Test No.: FA2014301 Scenario # 2 Event # 7 Page 18 of 22 Event
Description:
Loss of All AC ECP-0.0, Loss of ALL AC Power, version 26 Time Pos. Expected Actions/Behavior Comments SRO Recognize Loss of all AC and direct IOAs of ECP-0.0.
RO/ (step 1) Check reactor tripped. Immediate Operator actions of BOP ECP-0 are steps 1 and 2
[] Check reactor trip and reactor trip bypass No power breakers - OPEN.
[] Nuclear power - FALLING (step 1.1 RNO) Manually trip reactor.
(step 1.2) IF reactor can NOT be tripped, THEN trip both MG set supply breakers.
[] N1C11E005A
[] N1C11E005B YES (step 2) Check turbine tripped.
[] TSLB2 14-1 lit
[] TSLB2 14-2 lit
[] TSLB2 14-3 lit
[] TSLB2 14-4 lit
Op Test No.: FA2014301 Scenario # 2 Event # 7 Page 19 of 22 Event
Description:
Loss of All AC ECP-0.0, Loss of ALL AC Power, version 26 Time Pos. Expected Actions/Behavior Comments RO (step 3) Verify RCS isolated.
(step 3.1) Verify normal letdown isolated.
3.1.1 Verify all letdown line orifice isolation valves - CLOSED.
LTDN ORIF ISO 45 GPM
[] Q1E21HV8149A LTDN ORIF ISO 60 GPM
[] Q1E21HV8149B
[] Q1E21HV8149C OR 3.1.2 Verify letdown line isolation valves -
CLOSED.
LTD LINE ISO
[] Q1E21LCV459
[] Q1E21LCV460 (step 3.2) WHEN RCS pressure less than 2335 psig, THEN verify both PRZR PORVs closed.
(step 3.3) Verify excess letdown line -
ISOLATED.
[] Q1E21HV8153 closed
[] Q1E21HV8154 closed (step 3.4) Verify all reactor vessel head vent valves - CLOSED.
RX VESSEL HEAD VENT OUTER ISO
[] Q1B13SV2213A
[] Q1B13SV2213B RX VESSEL HEAD VENT INNER ISO
[] Q1B13SV2214A
[] Q1B13SV2214B The next event will occur when operators take action to restore AFW flow
Op Test No.: FA2014301 Scenario # 2 Event # 8 Page 20 of 22 Event
Description:
TDAFWP Fails to Auto Start ECP-0.0, Loss of ALL AC Power, version 26 Time Pos. Expected Actions/Behavior Comments RO (step 4) Verify total AFW flow GREATER CRITICAL TASK THAN 395 gpm. Establish > 395 gpm AFW AFW TOTAL FLOW flow before SG dryout
[] FI 3229 occurs.
RNO (step 4) Verify TDAFWP running.
TDAFWP STM SUPP FROM 1B(1C) SG
[] MLB-4 1-3 lit
[] MLB-4 2-3 lit
[] MLB-4 3-3 lit TDAFWP SPEED
[] SI 3411A > 3900 rpm TDAFWP SPEED CONT
[] SIC 3405 adjusted to 100%
Place TDAFWP STM SUPP FROM 1B SG HV3235A/26 AND TDAFWP STM SUPP FROM 1C SG to the START position The next event will begin when operators reach step 5 of ECP-0.0
Op Test No.: FA2014301 Scenario # 2 Event # 9 Page 21 of 22 Event
Description:
Restoration of AC Power with the 2C DG ECP-0.0, Loss of ALL AC Power, version 26 Time Pos. Expected Actions/Behavior Comments BOP (step 5) [CA] Restore power to any emergency bus.
(step 5.1) Verify supply breakers for major loads on emergency 4160 V busses - OPEN. On EPB
[] BKR DF01 (1A S/U XFMR TO 1F 4160 V BUS)
[] BKR DF15 (1B S/U XFMR TO 1F 4160 V BUS)
[] BKR DF-13-1 (1F 4160 V BUS TIE TO 1H 4160 V BUS)
[] BKR DG01 (1A S/U XFMR TO 1G 4160 V BUS)
[] BKR DG15 (1B S/U XFMR TO 1G 4160 V BUS BOP/ [] 1C CCW PUMP BKR DF-04-1 Load shed list continued from RO [] 1B CCW PUMP BKR DF-05-1 above
[] 1B CCW PUMP BKR DG-05-1 Components on MCB and may
[] 1A CCW PUMP BKR DG-04-1 be verified by RO
[] 1A SW PUMP BKR DK-03-1
[] 1B SW PUMP BKR DK-04-1
[] 1C SW PUMP BKR DK-05-1
[] 1C SW PUMP BKR DL-05-1
[] 1D SW PUMP BKR DL-03-1
[] 1E SW PUMP BKR DL-04-1
[] #4 RW PUMP BKR DJ-03-1
[] #5 RW PUMP BKR DJ-04-1
[] #8 RW PUMP BKR DH-03-1
[] #9 RW PUMP BKR DH-04-1
[] #10 RW PUMP BKR DH-05-1
[] 1B CRDM CLG FAN BKR ED-11-1
[] 1A CRDM CLG FAN BKR EE-13-1
[] 1A CS PUMP BKR DF-11-1
[] 1B CS PUMP BKR DG-11-1
[] 1A RHR PUMP BKR DF-09-1
[] 1B RHR PUMP BKR DG-09-1
[] 1A CHG PUMP BKR DF-06-1
[] 1B CHG PUMP A TRN BKR DF-07-1
[] 1B CHG PUMP B TRN BKR DG-07-1
[] 1C CHG PUMP BKR DG-06-1
[] 1A MDAFWP BKR DF-10-1
[] 1B MDAFWP BKR DG-10-1
Op Test No.: FA2014301 Scenario # 2 Event # 9 Page 22 of 22 Event
Description:
Restoration of AC Power with the 2C DG ECP-0.0, Loss of ALL AC Power, version 26 Time Pos. Expected Actions/Behavior Comments BOP Check 1-2A, 1C or 1B diesel generator NO running for Unit 1.
Perform 2C DG SBO start: CRITICAL TASK o MSS in MODE 1 Energize at least on AC o USS in UNIT 1 emergency bus before o When load shed has been removing DC control power competed then depress START PB from ESF equipment 2C DG will start breakers.
o Check Unit 1 2C DG output breaker YES DJ06 closes.
o Verify breaker DG13 closed. (1G 4160 V bus tie to 1J 4160 V BUS) YES o Verify breaker DG02 closed. (1G 4160 V bus tie to 1L 4160 V bus) o IF 1G 4160V bus energized, THEN YES proceed to step 5.7 BOP Verify adequate SW flow.
o Verify two SW PUMPS in energized CRITICAL TASK train - RUNNING. Start at least one SW pump
[] A Train (1A, 1B or 1C) prior to the 2C DG tripping.
[] B Train (1D, 1E or 1C)
Start 1D and/or 1E SW o IF A train energized, THEN verify pump(s)
SW TO/FROM DG BLDG - A HDR Q1P16V519/537 open. YES o IF B train energized, THEN verify SW TO/FROM DG BLDG - B HDR Q1P16V518/536 open. YES BOP Check no running diesel generator lube oil Will call DB SO to check 2C temperature annunciator in alarm. (155 ft, DG DG BLDG local control panel)
SRO IF 1F OR 1G 4160 V bus energized THEN go to procedure and step in effect and implement function restoration procedures as necessary.
End the scenario when power is restored with the 2C DG or at the discretion of the Lead examiner
Appendix D Crew Briefing sheet Form ES-D-3 Op-Test No.: FA2014301 Page 1 of 2 Brief This simulator performance scenario is performed in the EVALUATION MODE. You should not direct questions to the evaluators. Otherwise, you should perform as if you were in the MCR.
Your ability to maintain a log is not being graded, but maintaining a rough log is recommended to help during briefs.
If you need to communicate with the Unit 2 operator, call Unit 2 at 2434 or page the Unit 2 Unit Operator.
Respond to what you see. If there is a problem with the simulation, the session will be terminated or adjusted as appropriate based on the specific problem.
Assign operating positions.
Ask for and answer questions.
Appendix D Turnover sheet Form ES-D-3
[ X ] Unit 1 [ ] Unit 2 Shift: Date Off-going SS Oncoming SS [ ]N [X]D Today Part I - To be reviewed by the oncoming Supervisor prior to assuming the shift.
Security Keys A, S, D, SW, X on key ring . SS Unit 25% power, 1303 ppm Cb, MOL 10000 MWD/MTU Status TARGET ZERO STPs/Evolutions: Every Day, Every Job Safely A Train On-Service - A Train Protected 1.0 ; 109.1 No adj. ; 63.7 ; FSP-20,0 ;
Status of Special Testing General Information
- 1. Shift Goal is to place impulse loop in service and raise power to 100%
- 3. Current Risk Assessment is GREEN and projected is GREEN
- 4. Aux steam is being supplied from Unit 2
- 6. UOP-3.1, V119.0 in progress at step 5.3, Ramping up
- 7. Unit 2 is at 100% power with no major issues.
8.
9.
10.
11.
Equipment Status Maintain VCT gas pressure 25-30 psig Reactivity Plan Waste Management Status 100 gallon dilutions every 15 minutes #3 RHT - On Service WGS - secured LCO Status Night Orders No New Night Orders Part II Review Shift Complement LCOs Reviewed SS (initials) reviewed as early in shift as possible Part III: STP-1.0 Operator Logs Cond. Report Autolog ELDS & GEN Keys Reviewed/Signed Reviewed Queue Reviewed Spreadsheet Turned Reviewed verified Over
[ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes
Unit One Reactivity Briefing Sheet RCS Temp 552.0 °F Current RCS Borations / Dilutions:
RX PWR 25.0 % Borate Dilute Current Xenon Concentration 3812 PCM 0 Gal. 100 Gal.
Burnup 10000 MWD/MTU Reactivity Additions: 0.00 19.70 PCM As of (Date & Time) 10/2/2013 1:00 Total Reactivity Addition: 19.70 PCM Calculated Burnup 13723 MWD/MTU Net RCS Temperature Effect: 3.88 °F As Of 9/23/14 1144 Net Rx Power Effect: 0.96 %
Assumes constant power since Last Power history update Boron Worth -8.30 PCM/PPM RCS Boron 1303 PPM Power Defect 515 PCM BAT Concentration 7436 PPM MTC -5.07 PCM/°F Current Bank Boric Acid Required for Power reduction Delta Rod Position: 168 Steps With no Control rod movement Power Acid Defect Required Rod Worth DeltaPower (PCM) Delta PPM (Gallons)
Steps Out 1.00% 21 2.44 20 One 6 PCM 2.00% 41 4.89 40 Two 13 PCM 5.00% 103 12.22 99 Five 33 PCM 10.00% 206 24.45 198 Ten 69 PCM 20.00% 412 48.89 398 Twenty 151 PCM 25.00% 515 61.12 498 Fifty 410 PCM 50.00% N/A N/A N/A 75.00% N/A N/A N/A Steps In 100.00% N/A N/A N/A One -6 PCM Two -12 PCM Five -30 PCM a/o w/o Ten -58 PCM RCS B-10 ratio 17.98 16.6 Twenty -110 PCM BAT B-10 ratio 20.1 18.6 Fifty -243 PCM NDR B-10 ratio 19.8 18.3 RCS Blended Flow Makeup Requirements Acid to RMW to dilute 1 PPM( Required FK-113 Borate 1 PPM Gal.) Acid flow Pot (Gal.) Rate Setting (GPM)
Values for Normal 8.2 Gal. 38.1 Gal. 21.3 GPM 5.31 Auto M/U (Bat-100 ppm boron)
Values based on 8.1 Gal. 38.1 Gal. 21.0 GPM 5.23 Actual Bat Concentration Valid For Unit One cycle 24 26 Core Physics Curves:
Curve 5 Rev 29 Curve 27 Rev 28 Curve 34 Rev 46 Curve 57 Rev 35 Curve 57A Rev 25 Printed by 9/23/2014 @ 11:44 AM Copy of U1 reactivity sheet Version 5.2
Scenario #2 FA2014301 Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-37 NRC EXAM SCENARIO #2 Validation time: 100 Minutes Validated by: Sorrell, Newell, Smith TRN Supervisor Approval: Billy Thornton Date: 9/24/14 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3
Appendix D Scenario #2 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 2 Op-Test No.: FA2014-301 Examiners: Operators: SRO RO BOP Initial Conditions: 25% power, UOP-3.1, v119.0, at step 5.3. Ramping up. MOL, 1303 ppm Cb; 1B SGFP on service. Aux steam from U-2.
Turnover:
Current Risk Assessment is GREEN and projected to remain GREEN.
A Train O/S, A Train protected.
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia SPLIT TRAIN ALIGNMENT Event Malf. Event Type* Event Description No. No.
1 R (RO) Place impulse loop in service and commence ramp to 100%
N (BOP) 2 loa- C (BOP) CST Ruptured by crane cfw001 TS (SRO) TS 3.7.6 Cond A imf 3 I (RO) TK-144 fails high in Auto, TCV-143 fails to auto divert TK144-A 10 /
preset 4 Imf I (RO) LT-459 fails low (P-CT) lt459 TS (SRO) TS 3.3.1 Function 9 Cond M 5 preset N (BOP) During letdown restoration LCV-459 will not open. Requires Excess letdown to be placed in service.
6 Imf I (BOP) PT-464 fails high (P-CT) pt464 7 Imf mal- M (ALL) LOSP eps1 /
preset 1B DG trips after auto start and cannot be started 4 minutes after LOSP Unit 2 SI occurs 1C DG trips Loss of ALL AC 8 preset C (BOP) TDAFW pump fails to auto start (CT-23) 9 preset C (RO) Power restored by starting 2C DG (CT- 24)
Unit 2 has no B train service water At least one service water pumps must be manually started prior to the 2C DG tripping (CT-25)
Terminate when 2C diesel running with Service Water supplied (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley October 2014 exam Page 2 of 9
Appendix D Scenario 2 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Load in IC-212 and sim IC snap directory 1303 ppm Cb; 1B SGFP on service. Aux steam from U-2 Base IC is IC-37 RUN 0 0 Generic setup:
bat generic_setup_HLT.txt 0 0 Quick setup (all items with
- are included):
bat ILT37_2.txt PRESETS 8 Prevent TDAFWP auto start
- CMFmalf / cMS3235B-cc1 / open CMFmalf / cms3235b_cc2 / open CMFmalf / cms3235a_cc1 / open CMFmalf / cms3235a_cc2 / open 7 1B DG trips on AUTO start TRG 2 Malf / mal-eps4b / 30 sec delay / Trg 2
- 7 Unit 2 SI - 2B DG trips on loadshed TRG 2 CMFmalf / csftyinj_cc21 / closed / 240 sec delay / Trg 2
- Malf / mal-eps4c / 240 sec delay / Trg 2 7 1C DG blocked from auto or manual closure
- CMFmalf / cbk1DH07_d_cc18 / open 9 Block D & E SW pumps from starting after 1B DG trips TRG 2 CMFmalf / cNCPsw1F_d_cc5 / 35 sec delay / open
- CMFmalf / cNCPsw1F_d_cc6 / 35 sec delay / open CMFmalf / cNCPsw1E_d_cc5 / 35 sec delay / open CMFmalf / cNCPsw1E_d_cc6 / 35 sec delay / open 3 Fails TCV-143 from diverting on high temperature.
- CMFmalf / ccvT143_d_cc1 / closed Triggers and Commands 5 Event Trigger 1 - monitors LCV-459 valve position, once TRG 1 closed will not reopen
- Trgset 1 x13o133c Trg 1 imf rcvl459-m 0 2 7 Event Trigger 2 - 1B DG start lamp. 1B DG will trip after it TRG 2 starts.
- Trg 3 imf mal-dsg009 Farley October 2014 exam Page 3 of 9
Appendix D Scenario 2 Booth Operator Guide Form ES-D-1 EXAM MCB setup DEH Clear DEH alarms DEH Ensure Impulse loop is NOT IN SERVICE Select OPS GROUP on MCB monitor IPC Acknowledge computer alarms IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Clear Recorders Cae clearrecorders.cae Provide a marked up copy of UOP-3.1, v117.0 completed UOP-3.1 copy thru step 5.3, Ready to perform step 5.4.
FREEZE simulator Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:
Simview / sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW / Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 Seconds: clock(1) = 0 Farley October 2014 exam Page 4 of 9
Appendix D Scenario 2 Booth Operator Guide Form ES-D-1 EXAM VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and then COLLECT to start collecting data 0 Begin Exam Verify Horns ON: hornflag HORNS ON = TRUE 1 Start of exam Commence Ramp up to 100% power.
2 NRC CUE CST Ruptured by crane Remote / N21 / LOA-CFW001 / 0 / 600 3 NRC CUE TK-144 fails high in auto, TCV-143 fails to auto divert CNH / TK144-A / 10 / 1 4 NRC CUE LT-459 fails low XMT / LT459 / 0 / 1 5 preset During letdown restoration LCV-459 will not open.
Requires Excess letdown to be placed on service.
6 NRC CUE PT-464 fails high XMT / PT464 / 1200 / 45 Farley October 2014 exam Page 5 of 9
Appendix D Scenario 2 Booth Operator Guide Form ES-D-1 EVENT# TIME EVENT DESCRIPTION COMMAND 7 NRC CUE LOSP, 1B DG Trips after auto start and cannot be started. 4 minutes after LOSP U2 SI occurs. 1C DG fails to align to Unit 1. Loss of All AC Malf / MAL-EPS1 / 1 / 1 8 Preset TDAFW pump fails to auto start 9 Preset Power restored by starting the 2C DG and manual restoration of SW End of Exam HORNS OFF FREEZE simulator Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of Ensure data file created.
exam2014sen2grpX.txt NOTE: Substitute grpX with grp1, grp2, or grp3 as appropriate.
NOTE: file will be saved in the OPENSIM directory.
When Control board data no longer needed Then Clear recorders for exam security Farley October 2014 exam Page 6 of 9
Appendix D Scenario 2 Booth Operator Guide Form ES-D-1 Local operator actions:
EVENT NO. TIME ACTIONS 1 NONE REQUIRED 2 IF REQUESTED Place RCDT on recirc Three (3) Minutes after requested 3 NONE REQUIRED 4 NONE REQUIRED 5 NONE REQUIRED 6 NONE REQUIRED 7 When REQUIRED Announce Unit 2 Reactor Trip and Safety Injection 2 Minutes after Unit-Two Safety Injection.
8 NONE REQUIRED Farley October 2014 exam Page 7 of 9
Appendix D Scenario 2 Booth Operator Guide Form ES-D-1 Communications sheet EVENT NO. TIME Communication:
ALL AS REQUIRED SSS, SM and Dispatcher:
(Standard Repeat back failure, procedure entered, plant status, CR in the cue communications to and that type of communications.
inform supervision)
If recommendation/direction requested then tell crew to Use their own judgment 1 NONE EXPECTED ROVER:
Called to Monitor 1A CNDS Pump Amps Report 1A Condensate Pump AMPS 3 (THREE) minutes after request Turbine SO:
Called to perform step 4.1.5 of SOP-20.0 I will perform step 4.1.5 of SOP-20.0 2 WHEN REQUESTED Diesel BLDG SO:
Called to check CST due to level dropping rapidly. After 1 minute report the following:
A Crane moving a large load has ruptured the CST at ground level.
SM:
Called to Evaluate EALs I will evaluate EALs RAD SIDE SO:
Called to Secure SGBD per SOP-16.1. After 5 minutes report the following:
SGBD is secured.
Acknowledge SGBD Process Panel Alarms as required 3 NONE EXPECTED 4 NONE EXPECTED Farley October 2014 exam Page 8 of 9
Appendix D Scenario 2 Booth Operator Guide Form ES-D-1 Communications sheet EVENT NO. TIME Communication:
5 NONE EXPECTED Chemistry:
Called to secure Zinc Addition System I will secure the Zinc Addition System Rad Side SO:
Called to place RCDT on Recirc: After 3 minutes report the following:
The RCDT is on Recirc.
After 5 minutes of flush to the RCDT report:
300 gallons have been flushed to the RWST during the flush 6 NONE EXPECTED 7 WHEN REQUESTED Diesel BLDG SO:
Called to check 1B DG. After 5 minutes report the following:
1B DG is not running.
Local annunciator window 35 ESSENTIAL GENERATOR PROTECTION GEN DIFF is in alarm.
Local annunciator window 43 EMRGENCY ENGINE SHUTDOWN is in alarm.
No other problems are apparent with 1B DG.
Called to check the status of the 1C DG. After 1 minute report:
1C DG has tripped Called to check 2C DG Lube oil alarm status. After 1 minute report the following:
2C DG lube oil alarm is clear 7 2 Minutes after Unit 2 SI:
Walk into control room and announce Unit 2 Rx Trip and Safety Injection, Unit 2 Rx Trip and Safety Injection Farley October 2014 exam Page 9 of 9
Appendix D Scenario #4 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 4 Op-Test No.: FA2014-301 Examiners: Operators: SRO RO BOP Initial Conditions: 85% power, UOP-3.1, v119.0, at step 5.20. Ramping up. MOL, 900 ppm Cb Turnover:
Current Risk Assessment is GREEN and projected to remain GREEN.
A Train O/S, B Train protected.
1A MDAFW pump tagged out for bearing replacement.
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia.
SPLIT TRAIN ALIGNMENT Event Malf. Event Type* Event Description No. No.
1 Imf I (BOP) CP-4055K, H2 temperature controller fails low in auto cp4055 K-A 2 Imf mal- R (RO) Turbine Vibration requires ramp down tur4f N (BOP) 3 Imf I (BOP) LT-475 fails high (P-CT) lt475 TS (SRO) TS 3.3.1. Cond E Imf mal- 5 minutes later when cabinet is inspected (IC person), MSS fails on mss1 A SGWLC when rack cab door is opened 4 Imf C (RO) PT-444 fails high; PORV-444B leaks by the seat - requires block pt444 /
preset valve closure (P-CT)
TS (SRO) TS 3.4.11 Cond A, TS 3.4.1 Cond A 5 Imf mal- C (RO) Reactor Vessel Inner O-Ring leakage increases to 1 GPM rcs3 6 Imf mal- M (ALL) Turbine Vibrations requires RX trip tur4f 7 preset C (RO) Reactor will not trip FRP-S.1 entry (CT-52)
Manual Turbine Trip is required Rods fail to move in AUTO after turbine trip 8 preset M (ALL) Two minutes after Turbine is tripped 500GPM steam space break in the Pressurizer C (BOP) 3318A/B Containment Isolations fail to auto close and must be closed at BOP (CT-11)
Terminate in EEP-1 after decision not to terminate SI at step 7.5 (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley October 2014 exam Page 1 of 4
Appendix D Scenario 4 Presets Form ES-D-1 PRESETS 7 1a crdm set fails to trip:
- CMFmalf / c52MGA_cr3 7 RTBs fail to open
- CMFmalf / cBKRXTRP_cc21 / closed CMFmalf / cbkrxtrp_cc22 closed 0 Tag 1A MDAFW pump
- irf cafp01a_d_cd1 open 3 Fail 1A SG MSS Card when Prot CH II cabinet open TRG 3 Imf mal-mss1 (3 20) 4 PORV 444B sticks at 10% after being demanded closed: TRG 1 imf rrc444b-m (1 0) 10 1 7 Blocks rods from moving in Auto TRG 2 Imf mal-crf2 (2 0) 1 8 Steam Space Break in the Pressurizer TRG 2 Imf mal-prs1 (2 120) 500 300 8 Block 3318 valves auto isolation
- CMFmalf / ccb3318A_d_cc5 / open CMFmalf / ccb3318B_d_cc5 / open Triggers and Commands 4 Event Trigger 1 - monitors PORV444B HS closed position TRG 1 trgset 1 x30i115c 7/8 Event Trigger 2 - monitors for turbine trip TRG 2 Trgset 2 x30O144g 3 Event Trigger 3 - monitors bistable light for Protection CH II TRG 3 cabinet door open Farley October 2014 exam Page 2 of 4
Scenario 4 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 85% power, UOP-3.1, v119.0 at step 5.20 ramping up. MOL, 900 ppm Cb.
Turnover:
Current Risk Assessment is GREEN and projected to remain GREEN.
A Train O/S, A Train protected.
1A MDAFW pump tagged out for bearing replacement.
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia.
Event 1 CP-4055K, H2 temperature controller fails low.
Verifiable actions: BOP takes manual control of CP-4055K and raise demand to increase cooling flow.
Event 2 Turbine vibrations require the unit to be ramped down.
Verifiable actions: RO uses rods and boron to maintain Tavg/Tref. BOP will insert ramp rate and target.
Event 3 LT-475 fails high along with the 1A SG Median Selector Card failure. Causes the 1A FRV to close. (P-CT)
Verifiable actions: BOP takes manual control of 1A FRV and restores SGWL.
Event 4 PT-444 fails high. PORV-444B leaks by the seat after being shut. (P-CT)
Verifiable actions: Take manual control of spray valves, and PORVs and shut them, MOV8000B must be shut due to leaking PORV.
Event 5 Reactor Vessel Inner O-Ring leakage increases to 1 GPM.
Verifiable Actions: RO evaluates leakoff temperature closes Rx vessel flange leakoff valve.
Event 6 Turbine vibrations increase requiring a Rx trip.
Event 7 Reactor will not trip (CT). Rods fail to move in AUTO after turbine trip.
Verifiable Actions: RO drives rods in manual inserting negative reactivity Event 8 Two minutes after Turbine is tripped 500 GPM steam space break in the Pressurizer.
MOV-3318A/B will not shut on Phase A Isolation.(CT)
Verifiable Actions: BOP closes one of the MOV-3318 valves completing isolation.
Terminate in EEP-1 after decision not to terminate SI at step 7.5.
UOP-3.1/ AOP-100/ARP/SOP/UOP-3.1/AOP-100/AOP-100/ARP/EEP-0/FRP-S.1/
EEP-0/EEP-1 Farley June 2014 exam Page 3 of 4
Scenario 4 Critical Task sheet Appendix D Form ES-D-1 Sheet CRITICAL TASK SHEET
- 1. Insert negative reactivity into the core by at least one of the following methods prior to dispatching operators to locally trip the reactor and/or the turbine:
De-energize the control rod drive MG sets Insert control rods Establish emergency boration flow to the RCS (CT-52)
- 2. Close containment isolation valves such that at least one valve is closed on each critical Phase A penetration before the end of the scenario. (CT-11)
SCENARIO Component failures, ramp down, ATWT and PZR steam space break.
OBJECTIVE/ The team should be able to:
OVERVIEW: respond to H2 controller malfunction, turbine vibrations require a ramp down, respond to a SGWL ,malfunction and control SGWL, respond to a pressure transmitter failure and stop RCS pressure reduction.
respond to a Rx vessel O-ring leak, turbine vibrations rise requiring a Rx trip, Rx fails to trip and FRP-S.1 is entered, Diagnose and respond to a Pressurizer steam space break Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes
- 1. Total malfunctions (5-8) 9
- 2. Malfunctions after EOP entry (1-2) 2
- 3. Abnormal events (2-4) 3
- 4. Major transients (1-2) 2
- 5. EOPs entered/requiring substantive actions (1-2) 1
- 6. EOP contingencies requiring substantive actions (0-2) 1
- 7. Critical tasks (2-3) 4 Farley June 2014 exam Page 4 of 4
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 1 Page 1 of 36 Event
Description:
Hydrogen Temperature controller CP-4055K fails LOW Indications Available Annunciators: TI-4067, HYDROGEN TEMP, increasing H2 TEMP HIGH (LJ3) DEH screen alarm comes in DEH TRBL (LB1)
ARP-1.11, MCB Annunciator Panel L, v51 LJ3 Time Pos. Expected Actions/Behavior Comments BOP (step 1) Check H2 TEMP controller (CP-4055K on MCB) to insure proper setpoint.
BOP (step 2) Verify validity of alarm from computer point indication.
NOTE: The MCB indication (TI4067) comes from DEH computer point G1CGAVG, which is an average of points HCOUT21R and HCOUT22R.
Historically, there has been a 5-7ºC difference between the MCB indication and the point feeding the alarm, such that the alarm may be in with a MCB indication of 42-43ºC.
SRO (step 4) Enter AOP-100, section 1.9 AOP-100 Actions on next page
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 1 Page 2 of 36 Event
Description:
Hydrogen Temperature controller CP-4055K fails LOW AOP-100, Instrumentation Malfunction, v13.0 Section 1.9 Time Pos. Expected Actions/Behavior Comments BOP (step 1) Check main generator hydrogen IOA step temperature controller functioning properly in AUTO.
[ ] HYDROGEN TEMP, CP-4055K SRO (step 1 RNO) Maintain main generator Take manual control of hydrogen temp < 46°C using manual control HYDROGEN TEMP, CP-of hydrogen temperature controller. 4055K and open valve.
(step 2) If hydrogen temperature cannot be maintained < 46C then Trip the Rx if reactor power is > 35% or Trip the turbine if Rx power is < 35%.
(step 3) If main generator hydrogen temperature is high due to a condition other than SW flow, then reduce turbine load as necessary to control hydrogen temperature <
46°C SRO (step 4) Notify the Shift Manager.
SRO (step 5) Direct appropriate personnel to determine and correct the cause of the high hydrogen temperature alarm.
SRO Write a CR and call dispatcher to plan work order When Hydrogen temperature is under manual control or at the discretion of the Lead Examiner move to next event.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 2 Page 3 of 36 Event
Description:
HI Main Turbine Vibrations on #6 Bearing and Turbine Ramp Indications Available Annunciators: Recognize indications of High Vibrations:
- MAIN TURB GEN VIB ALARM (KD4) - Vibration Display Monitor will show high out of spec readings on #6 Bearing
- DEH Turbine bearing page will show high readings
- IPC Main Turbine page will show high readings Note to examiner:
Turbine vibrations will reach the alarm level about 5 minutes after the event is inserted.
ARP 1.10, MCB Annunciator Panel K, v72 KD4 Time Pos. Expected Actions/Behavior Comments SRO Direct actions of KD4 BOP KD4 (step 1) Check indications on BN TURB VIB MCR DISPLAY to determine the cause of the alarm Or On DEH Or On IPC SRO (step 2) IF shaft vibration exceeds 7 mils, THEN investigation is necessary if vibration is continuous.
BOP (step 3) IF shaft vibration for #9 bearing is > Shaft vibrations will be >7 mils 7 mils, THEN go to Step 11. on #6 Bearing. SRO should direct Turbine Ramp down at (step 4) IF shaft vibration is > 7 mils but less less than or equal to 5 MW/min than 14 mils, THEN reduce turbine speed or load to reduce vibration.
At the discretion of the Lead Examiner then go to the next event.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 3 Page 4 of 36 Event
Description:
LT-475, 1A SG NR LVL, fails high with concurrent 1A SG Median Selector Card Failure Indications Available Annunciators: Indications of LT-475 failure
- 1A SG HI-HI LVL ALERT (JD1) - LI-475 Indicates top of scale
- 1A SG LVL DEV (JF1) Indications of 1A SG Median Selector Failure Additional Annunciators w/ MSS failure: - TSLB 1, 5-2 CAB 6 Power Failure Light Lit
- 1A SG STM FLOW > FEED FLOW - FK-478 Demand lowers (JB1) - LI-474 and 476 lowers
- PROC CAB PWR FAILURE (EC1) - 1A FRV Closes Note to examiner The initial failure of LT-475 will not affect the SGWL control system due to the operation of the Median Selector Switch. A subsequent MSS failure due to action within the control cabinet will initiate a response by the control system.
AOP-100, Section 1.6 actions for failure of LT-475 alone are on page 5.
AOP-100, Section 1.6 actions for failure of LT-475 and MSS are on page 6.
ARP-1.9, MAIN CONTROL BOARD ANNUCIATOR PANEL J, v49 JD1 Time Pos. Expected Actions/Behavior Comments SRO May direct RO or BOP to address ARP if SRO May direct entry to AOP-instrument failure is not initially diagnosed. 100 without referencing JD1
- 1A SG HI-HI LVL ALERT (JD1)
- (Step 1) Check 1A SGWL IF SRO directs entry into JD1
- (Step 2) If turbine trip and feedwater then transition to AOP-100 isolation occur THEN should occur at step 3 of the o If > P-9 then Trip Reactor ARP and enter EEP-0 o If < P-9 then refer to AOP-13 AOP-100 Actions are on the
- (Step 3) If and instrument failure has next page.
occurred, THEN go to AOP-100
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 3 Page 5 of 36 Event
Description:
LT-475, 1A SG NR LVL, fails high with concurrent 1A SG Median Selector Card Failure AOP-100, Instrumentation Malfunction, v13.0 Section 1.6 (LT-475 failure)
Time Pos. Expected Actions/Behavior Comments SRO Directs entry into AOP-100, section 1.6, and performance of immediate actions, then directs subsequent actions BOP (step 1) Maintain SG level at the referenced Due to the proper operation of level of 65%. the MSS these actions will not Take manual control of SGFP speed control be taken.
SK-509B taken to manual This controller will shift to manual IF required, THEN, take manual control of SGFP speed control as necessary to restore SG level to 65%
1.1 SGFP master controller SK-509 IF required, THEN take manual control of the affected feedwater regulating valves.
[ ] 1C SG FW FLOW FK-498 SRO (step 1.3) IF a loss of main feedwater has occurred, THEN perform the actions required by AOP-13.0, LOSS OF MAIN FEEDWATER.
SRO (step 2) Set manual trip criteria on SG level is adverse trend exists (high and low trip setpoints are 82% & 28% respectively)
BOP (step 3) IF a ramp is in progress, THEN place turbine on HOLD.
BOP (step 4) Determine affected SG and failed SG Level indicator.
BOP (step 5) Refer to TS 3.3.1 and 3.3.2 See page 7 for TS information SRO (step 6) Notify Shift Manager (step 7) Restore components to automatic when plant conditions permit.
(step 8) Initiate Condition Report
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 3 Page 6 of 36 Event
Description:
LT-475, 1A SG NR LVL, fails high with concurrent 1A SG Median Selector Card Failure AOP-100, Instrumentation Malfunction, v13.0 Section 1.6 (LT-475 failure w/ MSS failure)
Time Pos. Expected Actions/Behavior Comments SRO Directs entry into AOP-100, section 1.6, and performance of immediate actions, then directs subsequent actions BOP (step 1) Maintain SG level at the referenced Step 1 Is An Immediate level of 65%. Operator Action Take manual control of SGFP speed control SK-509B taken to manual NOTE: Step 1 Is A Continuing This controller will shift to manual Action Step IF required, THEN, take manual control of Operators Should Take SGFP speed control as necessary to restore Manual Control Of FK-478 To SG level to 65% Maintain 1A SGWL 1.1 Approximantely 65%.
SGFP master controller SK-509 POTENTIAL CRITICAL TASK IF required, THEN take manual control of the If SGWL is improperly affected feedwater regulating valves. controlled a Rx Trip may
[ ] 1A SG FW FLOW FK-478 occur.
[ ] 1C SG FW FLOW FK-498 SRO (step 1.3) IF a loss of main feedwater has occurred, THEN perform the actions required by AOP-13.0, LOSS OF MAIN FEEDWATER.
SRO (step 2) Set manual trip criteria on SG level is adverse trend exists (high and low trip setpoints are 82% & 28% respectively)
BOP (step 3) IF a ramp is in progress, THEN place turbine on HOLD.
BOP (step 4) Determine affected SG and failed SG Level indicator.
BOP (step 5) Refer to TS 3.3.1 and 3.3.2 See next page SRO (step 6) Notify Shift Manager (step 7) Restore components to automatic when plant conditions permit.
(step 8) Initiate Condition Report
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 3 Page 7 of 36 Event
Description:
LT-475, 1A SG NR LVL, fails high with concurrent 1A SG Median Selector Card Failure TECHNICAL SPECIFICATION 3.3.1, Reactor Trip System Instrumentation Table 3.3.1-1 Reactor Trip System Instrumentation Function 14 - SG Water Level - Low Low Applicable in Modes 1 and 2 required channels 3 per stm line CONDITION E CONDITION REQUIRED ACTION COMPLETION TIME E. One ------NOTE--------
channel The inoperable channel inoperable. may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels.
E.1 Place channel in trip. 72 hrs OR E.2 Be in MODE 3. 78 hrs TECHNICAL SPECIFICATION 3.3.2, Engineered Safety Feature Actuation System Instrumentation Table 3.3.2-1 Engineered Safety Feature Actuation System Instrumentation Function 5.b - SG Water Level - High High (P-14)
Applicable in MODES 1 and 2, Required channels - 3 per SG, CONDITION I Function 6.b - SG Water Level - LOW LOW Applicable in MODES 1-3, Required Channels - 3 per SG, CONDITION D CONDITION REQUIRED ACTION COMPLETION TIME I. One ------NOTE--------
channel The inoperable channel inoperable. may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels.
I.1 Place channel in trip. 72 hrs OR I.2 Be in MODE 3. 78 hrs D. One -------------NOTE-----------
channel The inoperable channel inoperable. may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels.
D.1 Place channel in trip. 72 hrs OR D.2.1 Be in MODE 3. 78 hrs AND D.2.2 Be in MODE 4. 84 hrs Begin next event when AOP-100 is complete or at the discretion of the lead examiner
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 4 Page 8 of 36 Event
Description:
PT-444, PZR Press Control Channel, Fails HI Indications Available Annunciators: Recognize indications of PT-444 failing HIGH:
- PRZR PORV TEMP HI (HA5) PK-444A demand
- PRZR SAFETY VLV TEMP HI (HA4) PORV 444B open
- REL VLV 444B\445A OPEN (HE1) - PIs 455;456;457, RCS Press
- PRZR PRESS RELVLV 445A OR BU HTRS - Pressurizer B/U heaters energizing ON (HD1) - TI-463 PORV Tailpiece temps
- PRZR PRESS HI-LO (HC1) TI-465; TI-467; TI-469 Code Safety Tailpiece temps PT-444, PRZR Press control channel, fails HIGH. The PORV closes in manual, PZR pressure control will be in manual.
AOP-100, Instrumentation Malfunction, v13.0 section 1.1 Time Pos. Expected Actions/Behavior Comments SRO Direct entry into AOP-100 RO (step 1) Take manual control of the Steps 1 and 2 are IOAs following equipment as necessary:
- PORV 444B, PRZR PORV. POTENTIAL CRITICAL TASK
- ALL Pzr heaters If RCS pressure is
- PK-444C & D, 1A& 1B LOOP SPRAY improperly controlled a RX VLV Trip may occur.
- PK-444A, PRZR PRESS reference Controller (step 2)
- IF pressurizer pressure is *Spray valves verified decreasing due to a mechanically stuck functioning properly (closed) open spray valve PCV444C or PCV444D No actions required RO (step 3) If the PORV is open then close the PORV 444B will close with the PORV when RCS pressure is < 2310 psig. handswitch but the PORV will leak by.
RO (step 4) IF an alarm was caused by a CONTROL instrument (PT-444/445) OR component failure, THEN perform the following as required to restore RCS pressure to desired value.
- Take manual control of PORVs, Block valves, Pressurizer heaters and spray.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 4 Page 9 of 36 Event
Description:
PT-444, PZR Press Control Channel, Fails HI AOP-100, Instrumentation Malfunction, v10.1 section 1.1 (CONT)
Time Pos. Expected Actions/Behavior Comments SRO (step 5) Determine NO protection instrument failure occurred.
RO (step 6) References required Technical Specifications :
3.4.1 for DNBR limits RCS pressure < 2209 psig CONDITION A TECHNICAL SPECIFICATION 3.4.1, RCS Pressure, Temperature, and Flow DNB Limits RCS DNB parameters for pressurizer pressure, RCS average temperature, and RCS total flow rate shall be within the limits specified in the COLR. The minimum RCS total flow rate shall be 263,400 GPM when using the precision heat balance method, 264,200 GPM when using the elbow tap method, and the limit specified in the COLR SRO CONDITION REQUIRED ACTION COMPLETION TIME A. One or more RCS DNB A.1 Restore RCS DNB parameters not within parameter(s) to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> limits. within limit.
TECHNICAL SPECIFICATION 3.4.11, Pressurizer Power Operated Relief Valves (PORVs)
Each PORV and associated block valve shall be OPERABLE Applicable in Modes 1, 2, and 3.
CONDITION REQUIRED ACTION COMPLETION TIME A. One or A.1 Close and maintain 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> more PORVs power to the associated inoperable block valve.
and capable of being manually cycled.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 4 Page 10 of 36 Event
Description:
PT-444, PZR Press Control Channel, Fails HI AOP-100, Instrumentation Malfunction, v10.1 section 1.1 (CONT)
Time Pos. Expected Actions/Behavior Comments SRO (step 7)
Notify the Shift Manager SRO (step 9) Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report.
SRO (step 10) IF the pressurizer PORVs operated, THEN perform the following:
Refer to SOP-1.2, Reactor Coolant Pressure Relief System, for cooldown of the PRT Refer to SOP-0.0, General Instructions To Operations Personnel, for reporting requirements.
After Shift Manager Notification or at the discretion of the Lead Examiner move to next event
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 5 Page 11 of 36 Event
Description:
Reactor Vessel O-Ring Leakage Indications Available Annunciators: Indications of an RCS leak:
RX VESSEL FLANGE LKOF TEMP HI TI-401, RX VESSEL LEAKOFF Rising (HH5) FI-122A Slowly Rising Reactor Vessel Inner O-Ring leakage increases to 1 GPM.
ARP-1.8, MAIN CONTROL BOARD ANNUNCIATOR PANEL H, v35.6 HH5 Time Pos. Expected Actions/Behavior Comments SRO Directs performance of ARP HH5, RX VESSEL FLANGE LKOF TEMP HI RO (step 1) Determine the actual reactor vessel flange leakoff temperature as indicated by TI-401, on the MCB.
RO (step 2) Compare the indicated flange leakoff temperature with containment temperature to verify flange leakage RO (step 3) IF Reactor Vessel flange leakage is RO should evaluate that flange indicated, THEN close RX VESSEL LKOF leakage exists and close HV-ISO HV-8032 8032 SRO (step 4) Refer to Technical Specifications No LCO required, only 1 gpm 3.4.13 for LCO requirements on operational of identified leakage.
leakage.
Once HV-8032 has been shut and TS condition determined or at the discretion of the Lead Examiner then move to next event.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 6 Page 12 of 36 Event
Description:
High Main Turbine Vibrations on #6 Bearing prompting Reactor Trip Note to examiner Vibrations will increase rapidly on the Main Turbine. ARP KD4 will direct the crew to trip the Reactor. The Rx will fail to trip and initiate the next event (FRP-S.1 Entry).
Indications Available Annunciators: Recognize indications of High Vibrations:
- MAIN TURB GEN VIB ALARM (KD4) - Vibration Display Monitor will show in RED high out of spec readings
- DEH Turbine bearing page will show high readings
- IPC Main Turbine page will show high readings ARP 1.10, MCB Annunciator Panel K, v72 KD4 Time Pos. Expected Actions/Behavior Comments SRO Direct actions of KD4 BOP KD4 (step 1) Check indications on BN TURB VIB MCR DISPLAY to determine the cause of the alarm Or On DEH Or On IPC SRO (step 2) IF shaft vibration exceeds 7 mils, THEN investigation is necessary if vibration is continuous.
BOP (step 3) IF shaft vibration for #9 bearing is >
7 mils, THEN go to Step 11.
(step 4) IF shaft vibration is > 7 mils but less than 14 mils, THEN reduce turbine speed or load to reduce vibration.
SRO (step 5) IF shaft vibration exceeds 14 mils, Shaft vibrations will be 15-17 OR thrust bearing wear exceeds 40 mils mils on #6 bearing. SRO THEN perform the following: should direct tripping the IF Reactor Power is > 35%, THEN Trip the Reactor and take actions of Reactor and refer to EEP-0, Reactor Trip or EEP-0 (next page)
Safety Injection.
Reactor will fail to trip and initiate the next event
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 7 Page 13 of 36 Event
Description:
FRP-S.1 Entry Indications Available Annunciators: Recognize indications of ATWT event
- Various and many - RTBs still closed
- Nis indicate full power
- Conditions warrant a reactor trip and one is not received When the crew tries to trip the reactor, the reactor trip breakers will not open and one of the CRDM MG set breakers will not open.
Enter EEP-0, Reactor Trip or Safety Injection, v45 Time Pos. Expected Actions/Behavior Comments SRO Reactor trip Direct the reactor trip and enter EEP-0.
RO/ Immediate Operator actions of EEP-0 RNO BOP (step 1) Check reactor trip. 1.1 Manually trip reactor.
Check all reactor trip breakers and reactor 1.2 IF reactor can NOT be trip bypass breakers - OPEN. tripped, THEN trip both MG set Check nuclear power - FALLING. supply breakers.
check rod bottom lights - LIT. N1C11E005A N1C11E005B 1.3 IF reactor will NOT trip, THEN go to FNP-1-FRP-S.1 SRO Should direct entry into FRP-S.1 (Actions on next Page.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 7 Page 14 of 36 Event
Description:
FRP-S.1 Entry FRP-S.1, RESPONSE TO NUCLEAR POWER GENERATION ATWT, v27.0 Time Pos. Expected Actions/Behavior Comments RO (step 1) IF reactor still NOT tripped, THEN Steps 1 and 2 are Immediate perform the following: Operator Actions Insert control rods in manual control. Critical task OR Insert negative Verify rods insert in AUTO at greater reactivity into the core than 48 steps per minute.
by inserting control rods or establishing emergency boration flow prior to dispatching operators to open Rx Trip breakers BOP (step 2) Check Main Turbine tripped Note: A PZR Steam Space RNO step 2.1 - Place main turbine LOCA (Event 8) will begin to emergency trip switch to TRIP for at least 5 ramp in ~ 2 minute after the seconds. turbine is tripped.
Note to examiner Any time beyond this point crew may elect to take Early Action for Step 7 and direct an SO to locally open the RTBs.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 7 Page 15 of 36 Event
Description:
FRP-S.1 Entry FRP-S.1, RESPONSE TO NUCLEAR POWER GENERATION ATWT, v27.0 CONT Time Pos. Expected Actions/Behavior Comments BOP (step 3) Verify AFW pumps running Both MDAFWPs amps > 0 TDAFWP speed > 3900 rpm RO (step 4) Initiate Emergency Boration of the RCS.
Verify at least one CHG PUMP -
RUNNING.
Start a BAT pump Open MOV 8104 Establish normal letdown flow - 8149A and either 8149B or C open Establish normal charging flow > 40 gpm Verify adequate emergency boration flow of > 30 gpm on FI-110 Check RCS pressure less than 2335 psig
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 7 Page 16 of 36 Event
Description:
FRP-S.1 Entry FRP-S.1, RESPONSE TO NUCLEAR POWER GENERATION ATWT, v27.0 CONT Time Pos. Expected Actions/Behavior Comments BOP (step 5) Verify containment ventilation isolation.
Verify containment purge dampers -
CLOSED.
3197 3198D 3198C 3196 3198A 3198B Verify containment mini purge dampers -
CLOSED.
CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D 2866C 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C 2866D 2867D Stop MINI PURGE SUPP/EXH FAN.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 7 Page 17 of 36 Event
Description:
FRP-S.1 Entry FRP-S.1, RESPONSE TO NUCLEAR POWER GENERATION ATWT, v27.0 CONT Time Pos. Expected Actions/Behavior Comments BOP (step 6) Check SI actuated -
6.1 BYP & PERMISSIVE SAFETY INJECTION ACTUATED status light lit MLB-1 1-1 lit MLB-1 11-1 lit (IF SI has actuated) 6.2 Initiate ATTACHMENT 1, Go to page 24 for ATT 1 AUTOMATIC SAFETY INJECTION actions.
VERIFICATION.
RO (step 7) Check ALL RTBs open RNO Dispatch an operator to locally trip the reactor trip and bypass breakers.
Check Main Turbine tripped Note to Examiner Transition to EEP-0 will be made when requirements of step 8 are met. EEP-0 actions are incorporated into event 8 (see next page)
RO (step 8) Check if reactor still critical. NOTE: [CA] step If power range indication is GREATER RNO Go to procedure and step THAN OR EQUAL TO 5%. in effect.
OR Check any intermediate range startup rate -
POSITIVE.
Move to the next event when the actions of FRP-S.1 are complete.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 8 Page 18 of 36 Event
Description:
Pressurizer Steam Space LOCA Indications Available:
Annunciators: Indications of SB LOCA
- Containment Rad monitors in alarm - RCS Pressure Decreasing
- PRZR LO Press Rx Trip SI (GB4) - SI Actuation
- RMS HI RAD (FF1) - Containment Pressure Increasing
- Numerous CTMT Rad Monitors alarming 3318A/B Containment Isolations fail to auto close and must be closed at BOP.
EEP-0, Reactor Trip or Safety Injection, v45.0 Time Pos. Expected Actions/Behavior Comments ALL Immediate Operator actions of EEP-0 Immediate Action steps of Check reactor trip. EEP-0 Check all reactor trip breakers and reactor trip bypass breakers - OPEN.
Check nuclear power - FALLING.
check rod bottom lights - LIT.
Check turbine - TRIPPED.
TSLB2 14-1 thru 4 lit Check power to 4160 V ESF busses. NOTE: 3 DGs will be running 4160 V ESF busses - AT LEAST ONE since an SI has occurred.
ENERGIZED A Train (F 4160V bus) power available lights lit OR B Train (G 4160V bus) power available lights lit Verify operating diesel generators are being supplied from at least one SW pump.
Check SI Status.
Check any SI actuated indication.
BYP & PERMISSIVE SAFETY INJECTION
[] ACTUATED status light lit
[] MLB-1 1-1 lit
[] MLB-1 11-1 lit
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 8 Page 19 of 36 Event
Description:
Pressurizer Steam Space LOCA EEP-0, Reactor Trip or Safety Injection, v45.0 CONT Time Pos. Expected Actions/Behavior Comments SRO, Announces EEP-0 Fold out Page items in RO, effect, directs/takes actions required OR Subcooling <16ºF [45}, stop all BOP RCPs RCS Press < 1300 psig, close chg mini-flows Ctmt pressure > 4 psig, use adverse numbers SRO (step 5) Directs continuing into EEP-0 at step See Tab at end of scenario for
- 5. Attachment 2 and 4 actions.
Directs the BOP to perform Attachment 2. Page 32 RO (step 6) Check containment pressure- HAS Ctmt pressure will be pre-REMAINED LESS THAN 27 psig event RO (step 7) Announce "Unit 1 reactor trip and safety injection".
Check secondary heat sink Available o Check total AFW flow > 395 gpm
[] FI 3229A
[] FI 3229B
[] FI 3229C o Total Flow FI 3229 OR Check any SG NR level > 31% {48%}
WHEN all SG narrow range levels less than 31%{48%}, THEN maintain total AFW flow greater than 395 gpm.
WHEN at least two SG narrow range levels greater than 28% AND TDAFWP NOT required, THEN stop TDAFWP.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 8 Page 20 of 36 Event
Description:
Pressurizer Steam Space LOCA EEP-0, Reactor Trip or Safety Injection, v45.0 CONT Time Pos. Expected Actions/Behavior Comments RO (step 8.4) WHEN SG narrow range level greater than 31%{48%}, THEN maintain SG NOTE: [CA] step -
narrow range level 31%-65%{48%-65%}.
Control MDAFWP flow.
[] A TRN reset
[] B TRN reset MDAFWP TO 1A/1B/1C SG B TRN
[] FCV 3227 in MOD Control TDAFWP flow.
TDAFWP FCV 3228
[] RESET reset TDAFWP SPEED CONT
[] SIC 3405 adjusted RO (step 9) Check RCS temperature.
IF any RCP running, THEN check RCS average temperature - STABLE AT OR APPROACHING 547°F.
[] TI 412D
[] TI 422D
[] TI 432D
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 8 Page 21 of 36 Event
Description:
Pressurizer Steam Space LOCA EEP-0, Reactor Trip or Safety Injection, v45.0 CONT Time Pos. Expected Actions/Behavior Comments RO (step 9 RNO) IF RCS temperature less than NOTE: RNO column is not 547°F and falling, THEN perform the expected to be used for this following. scenario (step 9.1.1) Verify steam dumps closed.
STM DUMP INTERLOCK
[] A TRN in OFF RESET
[] B TRN in OFF RESET (step 9.1.2) Verify atmospheric reliefs closed on MCB
[] Demand at 0 and minimum red light LIT (step 9.1.3) Control total AFW flow to minimize RCS cooldown, AFW FLOW TO 1A(1B,1C) SG
[] FI 3229A
[] FI 3229B
[] FI 3229C AFW TOTAL FLOW
[] FI 3229 IF MSIVs are closed THEN proceed to step 9.1.8 NOTE: Will call TBSO to IF MSIVs are open, THEN isolate steam accomplish this task loads in the turbine building while continuing with RNO step 9.1.5.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 8 Page 22 of 36 Event
Description:
Pressurizer Steam Space LOCA EEP-0, Reactor Trip or Safety Injection, v45.0 CONT Time Pos. Expected Actions/Behavior Comments RO (step 10) Check pressurizer PORVs and NOTE: [CA] step -
spray valves.
WHEN pressurizer pressure less than 2335 psig, THEN verify both PRZR PORVs closed.
Verify both PRZR PORVs indicate CLOSED Check PRZR PORV temperature STABLE OR FALLING.
[] PORV Temp TI-463 Check PRT parameters STABLE or FALLING.
[] PRT LVL LI-470
[] PRT TEMP TI-471 WHEN pressurizer pressure less than 2260 psig, THEN verify normal pressurizer spray NOTE: [CA] step -
valves closed OR in the process of closing.
[] PK 444C
[] PK 444D Check any PRZR PORV ISO - OPEN RO (step 11) Check RCP criteria. Examiner note: This is a Check SUB COOLED MARGIN MONITOR foldout page item, verify indication - GREATER THAN 16°F{45°F} applicants trip RCPs SUBCOOLED IN CETC MODE RO (step 12) Monitor charging pump miniflow Examiner note: This is a criteria. foldout page item, verify Control charging pump miniflow valves applicants close miniflow based on RCS pressure. isolation valves 1C(1A) LOOP RCS WR PRESS
[] PI 402A
[] PI 403A
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 8 Page 23 of 36 Event
Description:
Pressurizer Steam Space LOCA EEP-0, Reactor Trip or Safety Injection, v45.0 CONT Time Pos. Expected Actions/Behavior Comments Diagnostics The SRO will direct the parameters to be reviewed and will determine appropriate procedure to transition to.
SRO (step 13) Check SGs not faulted.
[] Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.
(step 14) Check SGs not ruptured
- Check secondary radiation indication NORMAL.
- No SG rising in an uncontrolled manner SRO (step 15) Check RCS intact SRO should transition to EEP-
- Check containment radiation - NORMAL 1.0. See next page.
- Check CTMT pressure < 3 psig
- Check ECCS sump level <0.4 feet
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 8 Page 24 of 36 Event
Description:
Pressurizer Steam Space LOCA EEP-1.0, Loss of Reactor or Secondary Coolant, v31.0 Time Pos. Expected Actions/Behavior Comments RO (step 1) Checks RCP stopped due to insufficient subcooling (SCMM<16{45}°F)
BOP (step 2) Check SGs not faulted
- no press falling uncontrolled
- none less than 50 psig BOP (step 3) Checks intact SG levels Verifies any intact SG NR level > 31{48%}
Controls MDAFW & TDAFW flows as necessary to maintain levels 31-65%{48%-
65%}
Stops TDAFW pump WHEN at least 2 SGs
>28%
BOP (step 4) Check SGs not ruptured
- Check secondary radiation indication -
NORMAL.
(step 5) Checks PORVs
- Iso valves open with power
- PORVs closed with no leakage
- no evidence of leak by via downstream temps & PRT parameters SRO (step 6) directs step 6 be performed 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from start of event
- Close recirc disconnects requirements - not available to
- Establish 1A & 1B post LOCA H2 perform in simulator-SRO calls analyzer on service per ATT 2 for SSS or an extra to perform
- Plot H2 on Fig 1
- Check and control H2 concentration in Ctmt SRO (step 7) Checks for SI termination criteria SI termination criteria may be RO and continues on without terminating SI due met but transition to ESP-1.1 to inadequate RCS pressure & Pzr level is incorrect due to existence of known LOCA.
End scenario when SI Termination decision has been made or at the discretion of the Lead Examiner
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 7 Page 25 of 36 Event
Description:
FRP-S.1 ATTACHMENT 1 Attachment 1 of FRP-S.1 AUTOMATIC SAFETY INJECTION VERIFICATION Time Pos. Expected Actions/Behavior Comments BOP (step 1) Check power to 4160 V ESF busses.
4160 V ESF busses - AT LEAST ONE ENERGIZED A Train (F & K) power available lights lit OR B Train (G & L) power available lights lit Verify operating diesel generators are being supplied from at least one SW pump.
(step 2) Check SI Status.
Check any SI actuated indication.
BYP & PERMISSIVE SAFETY INJECTION
[] ACTUATED status light lit
[] MLB-1 1-1 lit
[] MLB-1 11-1 lit BOP (step 3) Verify MFW status Verify main FRVs and bypass valves - valves CLOSED.
1A(1B,1C) SG STOP VLVFW FLOW FCV 478 FCV 488 FCV 498 Verify both SGFPs - TRIPPED.
Verify SGBD isolated - HV 7614A, B C - closed Verify SGBD sample valves closed by MLB-4 6-4, 7-4 and 8-4 LIT BOP (step 4) Verify Phase A actuated -
MLB-2 1-1 and 11-1 Lit All MLB-2 lights LIT BOP (step 5) Verify one CHG PUMP in each train - STARTED.
A train (1A or 1B) amps > 0 B train (1C or 1B) amps > 0
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 7 Page 26 of 36 Event
Description:
FRP-S.1 ATTACHMENT 1 Attachment 1 of FRP-S.1 (CONT)
AUTOMATIC SAFETY INJECTION VERIFICATION Time Pos. Expected Actions/Behavior Comments BOP (step 6) Verify RHR PUMPs - STARTED.
RHR PUMP 1A and 1B amps > 0 (step 7) Verify each train of CCW - STARTED.
BOP Verify one CCW PUMP in each train- STARTED.
A train HX 1C or 1B CCW FLOW FI 3043CA > 0 gpm OR FI 3043BA > 0 gpm B train HX 1A or 1B CCW FLOW FI 3043AA > 0 gpm OR FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM 1A(1B, 1C) CCW HX Q1P16FI3009AA > 0 gpm Q1P16FI3009BA > 0 gpm Q1P16FI3009CA > 0 gpm (step 8) Verify each SW train - HAS TWO SW PUMPs STARTED.
A train (1A,1B or 1C)
B train (1D,1E or 1C)
BOP (step 9) Verify containment fan cooler alignment.
Verify at least one containment fan cooler per train -
STARTED IN SLOW SPEED.
CTMT CLR FAN SLOW SPEED A train 1A 1B B train 1C 1D Verify associated emergency service water outlet valves - OPEN.
EMERG SW FROM 1A(1B,1C,1D) CTMT CLR Q1P16MOV3024A Q1P16MOV3024B Q1P16MOV3024C Q1P16MOV3024D
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 7 Page 27 of 36 Event
Description:
FRP-S.1 ATTACHMENT 1 Attachment 1 of FRP-S.1 AUTOMATIC SAFETY INJECTION VERIFICATION Time Pos. Expected Actions/Behavior Comments BOP (Step 10) Check no MSL isolation actuation signal present.
Signal Setpoint coincidence TSLB LO SG PRESS < 585 psig 2/3 TSLB4 19-2,3,4 Hi stm flow >40% 1/2 on 2/3 TSLB4 16-3,4 and and 17-3,4 18-3,4 Lo-Lo Tavg <543°F 2/3 TSLB2 10-1,2,3 HI-HI ctmt press >16.2 psig 2/3 TSLB1 2-2,3,4 If a MSLI signal is present then close ALL MSIVs BOP (step 11) Check containment pressure - HAS REMAINED LESS THAN 27 psig.
End of attachment 1 of FRP-S.1
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 7 Page 28 of 36 Event
Description:
Attachments 2 and 4 of EEP-0.0 EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments (Step 1) Verify one CHG PUMP in each train - STARTED.
BOP [] A train (1A or 1B) amps > 0
[] B train (1C or 1B) amps > 0 BOP (Step 2) Verify RHR PUMPs - STARTED.
RHR PUMP
[] 1A amps > 0
[] 1B amps > 0 BOP (Step 3) Verify Safety Injection Flow.
(Step 3.1) Check HHSI flow - GREATER THAN 0 gpm.
[] FI 943 BOP (Step 3.2) Check RCS pressure - LESS THAN 275 psig{435 psig}.
BOP (step 3.3) Check LHSI flow - greater than 1.5 X103 gpm
[] 1B RHR HDR FLOW FI-605B BOP (Step 4) Verify each SW train - HAS TWO SW PUMPs STARTED.
[] A train (1A,1B or 1C)
[] B train (1D,1E or 1C)
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 7 Page 29 of 36 Event
Description:
Attachments 2 and 4 of EEP-0.0 EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments BOP (Step 5) Verify each train of CCW -
STARTED.
(Step 5.1) Verify one CCW PUMP in each train- STARTED.
[] FI 3043CA > 0 gpm OR
[] FI 3043BA > 0 gpm B train HX 1A or 1B CCW FLOW
[] FI 3043AA > 0 gpm OR
[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM 1A(1B, 1C) CCW HX
[] Q1P16FI3009AA > 0 gpm
[] Q1P16FI3009BA > 0 gpm
[] Q1P16FI3009CA > 0 gpm (Step 5.3) Check instrument air available.
Verify at least one air compressor started.
AIR COMPRESSOR
[] 1A
[] 1B
[] 1C Check INST AIR PRESS PI 4004B greater than 85 psig.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 7 Page 30 of 36 Event
Description:
Attachments 2 and 4 of EEP-0.0 EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments BOP (step 6) Verify containment ventilation isolation.
Verify containment purge dampers -
CLOSED.
[] 3197
[] 3198D
[] 3198C
[] 3196
[] 3198A
[] 3198B Verify containment mini purge dampers -
CLOSED.
CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D
[] 2866C
[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C
[] 2866D
[] 2867D Stop MINI PURGE SUPP/EXH FAN. Mini Purge will not be running BOP (step 7) Verify containment fan cooler alignment.
Verify at least one containment fan cooler per train - STARTED IN SLOW SPEED.
CTMT CLR FAN SLOW SPEED A train
[] 1A [] 1B B train
[] 1C [] 1D Verify associated emergency service water outlet valves - OPEN.
EMERG SW FROM 1A(1B,1C,1D) CTMT CLR
[] Q1P16MOV3024A
[] Q1P16MOV3024B
[] Q1P16MOV3024C
[] Q1P16MOV3024D
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 7 Page 31 of 36 Event
Description:
Attachments 2 and 4 of EEP-0.0 EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments BOP (step 8) Verify AFW Pumps - STARTED.
Verify both MDAFW Pumps - STARTED
[] 1A MDAFW Pump amps > 0
[] 1B MDAFW Pump amps > 0 AND
[] FI-3229A indicates > 0 gpm
[] FI-3229B indicates > 0 gpm
[] FI-3229C indicates > 0 gpm (Step 8.2) Check TDAFW Pump start required.
Condition TSLB Setpoint Coincidence RCP Bus TSLB2 1-1 2680 V 1/2 Detectors Undervoltage 1-2 1-3 on 2/3 Busses Low Low SG TSLB4 28% 2/3 Detectors Water Level 4-1,4-2,4-3 on 2/3 SGs In Any 5-1,5-2,5-3 2/3 SGs 6-1,6-2,6-3 BOP (step 8.3) Verify TDAFWP started.
[] MLB-4 1-3 lit
[] MLB-4 2-3 lit
[] MLB-4 3-3 lit TDAFWP SPEED
[] SI 3411A > 3900 rpm TDAFWP SPEED CONT
[] SIC 3405 adjusted to 100%
Verify TDAFW flow path to each SG.
TDAFWP TO 1A(1B,1C) SG
[] Q1N23HV3228A in MOD
[] Q1N23HV3228B in MOD
[] Q1N23HV3228C in MOD TDAFWP TO 1A(1B,1C) SG FLOW CONT
[] HIC 3228AA open
[] HIC 3228BA open
[] HIC 3228CA open
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 7 Page 32 of 36 Event
Description:
Attachments 2 and 4 of EEP-0.0 EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments BOP (step 9) Verify main feedwater status.
Verify main feedwater flow control and bypass valves - CLOSED.
[] FCV 478
[] FCV 488
[] FCV 498 Verify both SGFPs - TRIPPED.
Verify SG blowdown - ISOLATED.
[] Q1G24HV7614A closed
[] Q1G24HV7614B closed
[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample -
ISOLATED MLB lights lit.
1A(1B,1C) SGBD SAMPLE STEAM GEN ISO
[] MLB1 19-2 lit Q1P15HV3328 closed
[] MLB1 19-3 lit Q1P15HV3329 closed
[] MLB1 19-4 lit Q1P15HV3330 closed BOP (Step 10) Check no MSL isolation actuation signal present.
Signal Setpoint coincidence TSLB LO SG PRESS < 585 psig 2/3 TSLB4 19-2,3,4 Hi stm flow >40% 1/2 on 2/3 TSLB4 16-3,4 and and 17-3,4 18-3,4 Lo-Lo Tavg <543°F 2/3 TSLB2 10-1,2,3 HI-HI ctmt press >16.2 psig 2/3 TSLB1 2-2,3,4 (Step 11) Verify PHASE A CTMT ISO. HV 3318 A and B lights will (Step 11.1) Verify PHASE A CTMT ISO - not be lit. Attachment 3 ACTUATED. performance is required BOP [] MLB-2 1-1 lit
[] MLB-2 11-1 lit 11.2 Check all MLB-2 lights - LIT.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 7 Page 33 of 36 Event
Description:
Attachments 2 and 4 of EEP-0.0 EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments BOP (step 12) Check all reactor trip and reactor trip bypass breakers - OPEN Reactor trip breaker A Reactor trip breaker B Reactor trip bypass breaker A Reactor trip bypass breaker B BOP (step 13) Trip CRDM MG set supply breakers.
1A(1B) MG SET SUPP BKR
[] N1C11E005A
[] N1C11E005B BOP (step 14) Secure secondary components.
Stop both heater drain pumps.
HDP
[] 1A
[] 1B Check any condensate pump started.
IF started, THEN stop all but one condensate pump.
[] 1A
[] 1B If NO condensate pumps are started then place all HSs to STOP 14.3 IF condensate pump operating, THEN verify backup cooling aligned to condensate pumps per FNP-0-SOP-0.0, APPENDIX B, Will call TBSO to TB SO Actions Following A Reactor Trip Or accomplish this.
Safety Injection.
BOP (step 15) Verify both CRACS mode selector switches in the ON position.
CRACS Mode Selector Switch
[] A TRAIN
[] B TRAIN Will call BOOTH to have this accomplished since this is not in the simulator
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 7 Page 34 of 36 Event
Description:
Attachments 2 and 4 of EEP-0.0 EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments BOP (step 16) WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.
230 KV BKR
[] 810 - OPEN
[] 914 - OPEN BOP (step 17) Verify two trains of ECCS equipment aligned.
Perform ATTACHMENT 4, Two Train ECCS Alignment Verification.
End of Attachment 2
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 7 Page 35 of 36 Event
Description:
Attachments 2 and 4 of EEP-0.0 EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 3 Time Pos. Expected Actions/Behavior Comments BOP (Step 1) Check all the following MLB-2 If light not lit then verify indicating lights lit. associated component status.
Circled components below must be manually closed CRITICAL TASK Close MOV-3318 A or B before the end of the scenario.
End of Attachment 3
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 4 Event # 7 Page 36 of 36 Event
Description:
Attachments 2 and 4 of EEP-0.0 EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 4 Time Pos. Expected Actions/Behavior Comments (Step 1) Verify both ECCS trains aligned.
[] Check DF01 closed
[] Verify DF02 closed
[] Check DG15 closed
[] Verfiy DG02 closed
[] Verify two trains of battery chargers -
energized Amps > 0 (Step 1.6) Verify two trains of ESF equipment aligned.
[] Check all MLB-1 lights LIT Verify charging pump suction and discharge valves - OPEN.
[] Q1E21MOV8132A
[] Q1E21MOV8132B
[] Q1E21MOV8133A
[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO
[] Q1E21MOV8130A
[] Q1E21MOV8130B
[] Q1E21MOV8131A
[] Q1E21MOV8131B (Step 1.7) Verify all post accident containment air mixing system fans - STARTED. (BOP)
POST ACCIDENT MIXING FAN
[] 1A
[] 1B
[] 1C
[] 1D RX CAV H2 DILUTION FAN
[] 1A
[] 1B (Step 1.8) WHEN power restored to any de-energized emergency bus, THEN verify alignment of associated equipment.
BOP (Step 1.9) Verify SFP Cooling in service per Call Radside SO SOP-54.0, Spent Fuel Pit Cooling And Purification System.
End of Attachment 4
Appendix D Crew Briefing sheet Form ES-D-3 Op-Test No.: FA2014301 Page 1 of 2 Brief This simulator performance scenario is performed in the EVALUATION MODE. You should not direct questions to the evaluators. Otherwise, you should perform as if you were in the MCR.
Your ability to maintain a log is not being graded, but maintaining a rough log is recommended to help during briefs.
If you need to communicate with the Unit 2 operator, call Unit 2 at 2434 or page the Unit 2 Unit Operator.
Respond to what you see. If there is a problem with the simulation, the session will be terminated or adjusted as appropriate based on the specific problem.
Assign operating positions.
Ask for and answer questions.
Appendix D Turnover sheet Form ES-D-3
[ X ] Unit 1 [ ] Unit 2 Shift: Date Off-going SS Oncoming SS [ ]N [X]D Today Part I - To be reviewed by the oncoming Supervisor prior to assuming the shift.
Security Keys A, S, D, SW, X on key ring . SS Unit 85% power, 899 ppm Cb, MOL 10000 MWD/MTU Status TARGET ZERO STPs/Evolutions: Every Day, Every Job Safely A Train On-Service - B Train Protected 1.0 ; 109.1 No adj. ; 63.7 ; FSP-20,0 ;
Status of Special Testing General Information
- 1. Shift Goal is to continue raising power to 100%
- 2. 1A MDAFW Pump is tagged out for bearing replacement
- 4. Current Risk Assessment is GREEN and projected is GREEN
- 5. UOP-3.1 is complete through step 5.19
- 6. Unit 2 is at 100% power with no major issues.
- 7. I & C Personnel are performing visual inspections in 7300 protection and control cabinets.
8.
9.
Equipment Status Maintain VCT gas pressure 25-32 psig Reactivity Plan Waste Management Status 100 gallon dilutions every ten minutes #3 RHT - On Service WGS - secured LCO Status 3.7.5 Condition B (1A MDAFW Pump)
Night Orders No New Night Orders Part II Review Shift Complement LCOs Reviewed SS (initials) reviewed as early in shift as possible Part III: STP-1.0 Operator Logs Cond. Report Autolog ELDS & GEN Keys Reviewed/Signed Reviewed Queue Reviewed Spreadsheet Turned Reviewed verified Over
[ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes
Unit One Reactivity Briefing Sheet RCS Temp 567.0 °F Current RCS Borations / Dilutions:
RX PWR 85.0 % Borate Dilute Current Xenon Concentration 2277 PCM 0 Gal. 100 Gal.
Burnup 10000 MWD/MTU Reactivity Additions: 0.00 14.34 PCM As of (Date & Time) 10/2/2013 1:00 Total Reactivity Addition: 14.34 PCM Calculated Burnup 22658 MWD/MTU Net RCS Temperature Effect: 0.81 °F As Of 9/23/14 1156 Net Rx Power Effect: 0.57 %
Assumes constant power since Last Power history update Boron Worth -8.75 PCM/PPM RCS Boron 899 PPM Power Defect 2,148 PCM BAT Concentration 7436 PPM MTC -17.73 PCM/°F Current Bank Boric Acid Required for Power reduction Delta Rod Position: 206 Steps With no Control rod movement Power Acid Defect Required Rod Worth DeltaPower (PCM) Delta PPM (Gallons)
Steps Out 1.00% 23 2.62 20 One 16 PCM 2.00% 47 5.25 40 Two 33 PCM 5.00% 117 13.11 100 Five 78 PCM 10.00% 233 26.23 200 Ten 145 PCM 20.00% 466 52.45 400 Twenty 214 PCM 25.00% 583 65.56 501 Fifty
- 50.00% 1,215 136.77 1050 75.00% 1,881 211.73 1636 Steps In 100.00% N/A N/A N/A One -16 PCM Two -32 PCM Five -82 PCM a/o w/o Ten -164 PCM RCS B-10 ratio 17.98 16.6 Twenty -313 PCM BAT B-10 ratio 20.1 18.6 Fifty -634 PCM NDR B-10 ratio 19.8 18.3 RCS Blended Flow Makeup Requirements Acid to RMW to dilute 1 PPM( Required FK-113 Borate 1 PPM Gal.) Acid flow Pot (Gal.) Rate Setting (GPM)
Values for Normal 7.7 Gal. 55.2 Gal. 14.7 GPM 3.64 Auto M/U (Bat-100 ppm boron)
Values based on 7.6 Gal. 55.2 Gal. 14.5 GPM 3.60 Actual Bat Concentration Valid For Unit One cycle 24 26 Core Physics Curves:
Curve 5 Rev 29 Curve 27 Rev 28 Curve 34 Rev 46 Curve 57 Rev 35 Curve 57A Rev 25 Printed by 9/23/2014 @ 11:58 AM Copy of U1 reactivity sheet Version 5.2
Scenario #4 FA2014301 Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-37 NRC EXAM SCENARIO #4 Validation time: 85 minutes Validated by: Sorrell, Newell, Smith TRN Supervisor Approval: Billy Thornton Date: 9/24/14 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3
Appendix D Scenario #4 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 4 Op-Test No.: FA2014-301 Examiners: Operators: SRO RO BOP Initial Conditions: 85% power, UOP-3.1, v119.0, at step 5.20. Ramping up. MOL, 900 ppm Cb Turnover:
Current Risk Assessment is GREEN and projected to remain GREEN.
A Train O/S, B Train protected.
1A MDAFW pump tagged out for bearing replacement.
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia.
SPLIT TRAIN ALIGNMENT Event Malf. Event Type* Event Description No. No.
1 Imf I (BOP) CP-4055K, H2 temperature controller fails low in auto cp4055 K-A 2 Imf mal- R (RO) Turbine Vibration requires ramp down tur4f N (BOP) 3 Imf I (BOP) LT-475 fails high (P-CT) lt475 TS (SRO) TS 3.3.1. Cond E, 3.3.2 Cond D, I Imf mal- 5 minutes later when cabinet is inspected (IC person), MSS fails on mss1 A SGWLC when rack cab door is opened 4 Imf C (RO) PT-444 fails high; PORV-444B leaks by the seat - requires block pt444 /
preset valve closure (P-CT)
TS (SRO) TS 3.4.11 Cond A 5 Imf mal- C (RO) Reactor Vessel Inner O-Ring leakage increases to 1 GPM rcs3 6 Imf mal- M (ALL) Turbine Vibrations requires RX trip tur4f 7 preset C (RO) Reactor will not trip FRP-S.1 entry (CT-52)
Manual Turbine Trip is required Rods fail to move in AUTO after turbine trip 8 preset M (ALL) Two minutes after Reactor is tripped 500GPM steam space break in the Pressurizer C (BOP) 3318A/B Containment Isolations fail to auto close and must be closed at BOP (CT-11)
Terminate in EEP-1 after decision not to terminate SI at step 7.5 (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley October 2014 exam Page 2 of 9
Appendix D Scenario 4 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Load in IC-214 and sim IC snap directory 900 ppm Cb Base IC is IC-58 RUN 0 0 Generic setup:
bat generic_setup_HLT.txt 0 0 Quick setup (all items with
- are included):
bat ILT37_4.txt PRESETS 7 1a crdm set fails to trip:
- CMFmalf / c52MGA_cr3 7 RTBs fail to open
- CMFmalf / cbkrxtrp_cc21 / closed CMFmalf / cbkrxtrp_cc22 closed 0 Tag 1A MDAFW pump
- irf cafp01a_d_cd1 open 3 Fail 1A SG MSS Card when Prot CH II cabinet open TRG 3 Imf mal-mss1 (3 20) 4 PORV 444B sticks at 10% after being demanded closed: TRG 1 imf rrc444b-m (1 0) 10 1 7 Blocks rods from moving in Auto TRG 2 Imf mal-crf2 (2 0) 1 8 Steam Space Break in the Pressurizer TRG 2 Imf mal-prs1 (2 120) 500 300 8 Block 3318 valves auto isolation
- CMFmalf / ccb3318A_d_cc5 / open CMFmalf / ccb3318B_d_cc5 / open Triggers and Commands 4 Event Trigger 1 - monitors PORV444B HS closed position TRG 1 trgset 1 x30i115c 7/8 Event Trigger 2 - monitors for turbine trip TRG 2 Trgset 2 x30O144g 3 Event Trigger 3 - monitors bistable light for Protection CH II TRG 3 cabinet door open Farley October 2014 exam Page 3 of 9
Scenario 4 Booth Operator Appendix D Form ES-D-1 Guide EXAM MCB setup Place Unit 1 Bypass and inoperable panel lights to the up position Unit 1 A-Train (Auxiliary Feed water System)
Place HOLD Tag on 1A MDAFW pump H/S 1 HOLD TAG DEH Clear DEH alarms Select OPS GROUP on MCB monitor IPC Acknowledge computer alarms IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Clear Recorders Cae clearrecorders.cae Provide a marked up copy of UOP-3.1, v116.0 completed UOP-3.1 copy thru step 5.19, Ready to perform step 5.20.
Place Simulator in Freeze Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:
Simview / sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW / Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE Farley October 2014 exam Page 4 of 9
Scenario 4 Booth Operator Appendix D Form ES-D-1 Guide EVENT# TIME EVENT DESCRIPTION COMMAND Prior to RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and then COLLECT to start collecting data Begin Exam Verify Horns ON: hornflag HORNS ON = TRUE 1 Start CP-4055K, H2 temperature controller fails low in auto of exam CNH / CP4055K-A / 0 / 1 2 NRC Turbine Vibration requires ramp down CUE Malf / MAL-TUR4F / 9 / 600 3 NRC LT-475 fails high CUE XMT / LT475 / 100 / 1 MSS Fails when SGWLC rack door opened NRC STL / S1B07 / 1 CUE 4 NRC PT-444 fails high; PORV-444B leaks by the seat -
CUE requires block valve closure XMT / PT444 / 2500 / 1 5 NRC Reactor Vessel Inner O-Ring leakage increases to 1 CUE GPM Malf / MAL-RCS3 / 1 / 1 6 NRC CUE Turbine Vibrations requires RX trip Malf / MAL-TUR4F / 17 / 300 7 NRC Reactor will not trip FRP-S.1 entry (CT-52)
CUE Rods fail to move in AUTO after turbine trip 8 Preset Two minutes after Turbine is tripped 500GPM steam Farley October 2014 exam Page 5 of 9
Scenario 4 Booth Operator Appendix D Form ES-D-1 Guide space break in the Pressurizer 3318A/B Containment Isolations fail to auto close and must be closed at BOP (CT-11)
Terminate in EEP-1 after decision not to terminate SI at step 7.5 End of Exam HORNS OFF FREEZE simulator Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of Ensure data file exam2014sen4grpX.txt created.
NOTE: Substitute grpX with grp1, grp2, or grp3 as appropriate.
NOTE: file will be saved in the OPENSIM directory.
When Control board data no longer needed Then Clear recorders for exam security Farley October 2014 exam Page 6 of 9
Scenario 4 Booth Operator Appendix D Form ES-D-1 Guide Local operator actions:
EVENT NO. TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 NONE REQUIRED 4 NONE REQUIRED 5 NONE REQUIRED 6 NONE REQUIRED 7 WHEN REQUESTED Locally Open Rx Trip Breakers 3(THREE) MINUTES AFTER REQUEST using the buttons below.
CMFmalf / cbkrxtrp_cc21 / open CMFmalf / cbkrxtrp_cc22 / open 8 IF REQUESTED Close ECCS Disconnects (step 6 EEP-1.0) 5(FIVE) MINUTES AFTER REQUEST using the button below CAE eccs_disc_delayed.cae Farley October 2014 exam Page 7 of 9
Scenario 4 Booth Operator Appendix D Form ES-D-1 Guide Communications sheet EVENT NO. TIME Communication:
ALL AS REQUIRED SSS, SM and Dispatcher:
(Standard Repeat back failure, procedure entered, plant status, CR in communications to the cue and that type of communications.
inform supervision) 1 NONE EXPECTED 2 When Requested Turbine Bldg SO:
Called to walkdown the turbine:
There are abnormal vibrations on the turbine deck. No other abnormal conditions are apparent If #6 Bearing temperature is requested:
The #6 Bearing temperature is: Report temperature on the Main turbine screen for the #6 Bearing 3 When Requested If asked about I&C maintenance:
I will investigate 4 NONE EXPECTED 5 When Requested Radside SO:
Called to Check RCDT parameters for any change. After 2 minutes report the following:
There has been no change in RCDT level or pressure.
6 NONE EXPECTED 7 When Requested ROVER:
Called to locally open RX Trip Breakers, After 3 minutes report the following:
I have locally opened Unit one Reactor Trip breakers 8 When Requested SM:
I will make the classifications and notifications.
SM / SSS:
I will get someone to perform step 6 of EEP-1.
ANY CALL TO SHIFT CHEMIST:
Acknowledge to requirement for sampling.
Farley October 2014 exam Page 8 of 9
Scenario 4 Booth Operator Appendix D Form ES-D-1 Guide Communications sheet EVENT NO. TIME Communication:
Farley October 2014 exam Page 9 of 9
Appendix D Scenario #5 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 5 Op-Test No.: FA2014-301 Examiners: Operators: SRO RO BOP Initial Conditions: 95% power, AOP-2 step 16.1. MOL, 894 ppm Cb; Turnover:
Current Risk Assessment is GREEN and projected to remain GREEN.
A Train O/S, B Train protected.
1A MDAFW pump tagged out for bearing replacement.
7gpd tube leak.
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia.
Maintain current power level for SG Tube Leakage evaluation SPLIT TRAIN ALIGNMENT Event Malf. Event Type* Event Description No. No.
1 N (BOP) Adjust R-70 setpoint 2 Imf I (BOP) PT-476 fails low (P-CT) pt476 TS (SRO) TS 3.3.2 Cond D Imf 3 pk444a-a C (RO) PK-444A fails low. (P-CT) 4 Imf C BOP Main Generator Seal oil pressure decreases due to air side seal oil sgs508 pump trip and regulator malfunction - automatic actions are 7a_cc3 blocked 5 Irf loa- R (RO) Tube leak increases to 160GPD, ramp unit offline rds001 TS (SRO) TS 3.4.13 Cond B 6 Preset C (RO) Selected BAT pump will not Auto start during Auto makeup or borations Imf 7 M (ALL) A loop spray valve drifts open in manual control pk444c-m Reactor is tripped due to stuck open spray valve C (BOP) Main Turbine will not trip automatically or manually. GV closure is required (CT-13) 1B MDAFW will not auto start and cannot be started After start TDAFW pump speed slows to idle speed 8 Restore feed water in FRP H.1 (CT-43)
Terminate on exit of FRP H.1 (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley October 2014 exam Page 1 of 4
Appendix D Scenario 5 Presets Form ES-D-1 PRESETS 0 Tag 1A MDAFW pump
- irf cafp01a_d_cd1 open 0 Insert Initial Tube Leak in A SG
- Irf loa-rds001 7 5 4 Prevents selected BAT pump from working in AUTO
- Imf ccvp005a_cc2 open 5 Simulates back up seal oil regulator malfunction
- Set ctga26 = 117.0 5 Prevents Air Side DC seal oil pump auto start
- Imf cgs5085_cc10 open 7 Prevents auto closure of all MSIVs
- imf crsh001a_cc5 open imf cmsh002a_d_cc5 open imf crsh001b_cc5 open imf cmsh002b_d_cc5 open imf crsh001c_cc5 open imf cmsh002c_d_cc5 open 7 Prevent AUTO trip of main turbine
- MALF / T / MAL-TUR2 7 Prevent MANUAL trip of main turbine
- MALF / T / MAL-TUR24 7 Prevent start of B MDAFW Pump
- Imf cafp01b_d_cc18 open Triggers and Commands 7 Trigger 1 monitors for TDAFW Pump Start TRG 1 Trgset 1 x21o135o Trg 1 imf sic3405-o 4 20 Farley October 2014 exam Page 2 of 4
Scenario 5 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 95% power, AOP-2 step 16.1. MOL, 894 ppm Cb Turnover:
Current Risk Assessment is GREEN and projected to remain GREEN.
A Train O/S, B Train protected.
1A MDAFW pump tagged out for bearing replacement.
7 gpd tube leak Thunderstorm warnings in effect for Southeast Alabama & Western Georgia.
Event 1 Adjust R-70 setpoint.
Verifiable Actions: BOP operates various R-70 controls to change setpoint.
Event 2 PT-476 fails low. (P-CT)
Verifiable Actions: BOP takes manual control of SGFP speed as it slows down and 1A FRV closes and then opens. TS 3.3.2 Cond D.
Event 3 PK-444A fails low. (P-CT)
Verifiable Actions: Close both PORVs and spray valves.
Event 4 Seal oil pressure decreases due to air side seal oil pump trip and regulator malfunction, automatic actions are blocked.
Verifiable Actions: BOP starts DC air side oil pump and Seal oil backup pump.
Event 5 SGTL increases to 160 gpd. Ramp off line.
Verifiable Actions: RO uses rods/boron to control Tavg/Tref. TS 3.4.13 Cond B.
Event 6 Selected BAT pump will not Auto start during Auto makeup or borations.
Verifiable Actions: RO will start BAT pump as required for boration/dilution and auto makeup. May use SOP to switch to the other BAT pump.
Event 7 Reactor is tripped due to a spray valve drifting open in manual. Main Turbine will not trip automatically or manually. GV closure is required. 1B MDAFW will not auto start and cannot be started. After start TDAFW pump speed slows to idle speed.
Verifiable Actions: Main Turbine GV closure is required. (CT-13)
Event 8 Restore feedwater in FRP-H.1.
Verifiable Actions: Restore feed using SGFP or Condensate Pump. (CT-43)
Terminate on exit from FRP-H.1.
SOP/AOP-100/AOP-2/UOP-3.1/SOP/ARP/AOP-100/EEP-0/FRP-H.1/EEP-0 Farley October 2014 exam Page 3 of 4
Scenario 5 Critical Task sheet Appendix D Form ES-D-1 Sheet CRITICAL TASK SHEET
- 1. Manually trip the main turbine before a severe (ORANGE path) challenge develops to either the subcriticality or the integrity CSF or before transition to ECA-2.1, whichever happens first. (CT-13).
(CT-43).
SCENARIO Power operation with instrument and component failures with a loss of Heat Sink.
OBJECTIVE/ The team should be able to:
OVERVIEW: Adjust R-70 setpoint, respond to a steam pressure transmitter failure, respond to a Pressurizer pressure controller failure requires manual valve operation, respond to a reduction in seal oil pressure requiring manual start of the backup pumps, respond to increase in SGTL requiring ramp, operate BAT pump during boration/dilution/auto makeup, respond to a spray valve drifting open in manual that requires a Rx trip, manually close turbine governor valves when required, respond to a loss of feedwater requiring entry into FRP-H.1.
terminate at exit of FRP-H.1 Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes
- 1. Total malfunctions (5-8) 7
- 2. Malfunctions after EOP entry (1-2) 2
- 3. Abnormal events (2-4) 3
- 4. Major transients (1-2) 1
- 5. EOPs entered/requiring substantive actions (1-2) 0
- 6. EOP contingencies requiring substantive actions (0-2) 1
- 7. Critical tasks (2-3) 4 Farley October 2014 exam Page 4 of 4
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 1 Page 1 of 40 Event
Description:
R-70 Setpoint Adjustment Indications Available Annunciators: R-70 reading 7.0 GPD SG TUBE LEAK ABOVE SETPT (FG1)
AOP-2.0, Steam Generator Tube Leakage, v35.0 Time Pos. Expected Actions/Behavior Comments BOP (step 16.1) Monitor R-70 and R-15 radiation [CA] Step monitors leak rate once every 15 minutes BOP (step 16.2) Clear the FG1 alarm by raising the affected SG R-70 channel alert setpoint to a value above the current baseline value, but not over 30 gpd per SOP-69.0.
SOP-69.0, N-16 Primary to Secondary Leak Detection System, v6.0 Section 4.3 - Changing Alarm Setpoints Time Pos. Expected Actions/Behavior Comments BOP (step 1 ) Press CODE key BOP (step 2) Enter 1111 If operator enters the wrong value pressing the VAL key and returning to step 1 will allow the correct value to be entered.
BOP (step 3) Press VAL key BOP (step 4) Press ALRT Key BOP (step 5) Check existing setpoint displayed BOP (step 6) Press MOD key BOP (step 7) Enter desired setpoint using numeric Value entered will be in keys scientific notation and should not exceed 30 GPD BOP (step 8) When desire setpoint is displayed MCB Alarm FG1 will also clear press the VAL key if step 7 is done correctly.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 1 Page 2 of 40 Event
Description:
R-70 Setpoint Adjustment SOP-69.0, N-16 Primary to Secondary Leak Detection System, v6.0 Section 4.3 - Changing Alarm Setpoints (CONT)
Time Pos. Expected Actions/Behavior Comments BOP (step 9) Press MEAS key to return to measurement mode BOP (step10) Check display indicates AV and leak rate BOP (step 11) Press ALRT key BOP (step 12) Check setpoint was changed to correct, desired value BOP (step 13) Press MEAS key to return to measurement mode BOP (step 14) Place a status tag stating new Operator may direct SSS to setpoint on channel modified prepare a status tag.
When status tag preparation has been directed or at the discretion of the Lead Examiner move to the next event.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 2 Page 3 of 40 Event
Description:
PT-476, CH IV, 1A SG Steam Pressure Transmitter, fails LOW Indications Available:
Annunciators: Recognize indications of PT-476 failing:
- 1A SG LVL DEV (JF1) - 1A SG water level decreasing
- 1A SG STM LINE HI DP ALERT (JE1) - 1A FRV going full closed
- 1A SG FEED FLOW > STM FLOW (JG1)
AOP-100, Instrumentation Malfunction, version 13 Section 1.5 Time Pos. Expected Actions/Behavior Comments SRO Direct AOP-100 entry and IOAs taken.
BOP (step 1) Maintain SG Level at the reference Immediate Operator Action level of 65%. [CA]
IF required take manual control of:
- SGFP Master Controller SK-509A POTENTIAL CRITICAL TASK
- 1A Feed Reg Valve FK-478 Improper SGWL control may cause a RX Trip.
SRO (step 2) If adverse trend in SG level exists then establish trip criteria BOP (step 3) Place ramp on HOLD BOP (step 4) Determine the instrument failure BOP (step 4.3) Select out the controlling channel by placing the following handswitches to the appropriate channel III OR IV position as required:
A SG STM FLOW SEL SW - FS/478Z A SG FW FLOW SEL SW - FS/478Y SRO (step 5) See TS 3.3.2 on the next page Refer to Tech Specs 3.3.2 Function 1, e(2) cond D; Place channel in trip in 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in mode 3 in 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> and mode 4 in 84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br />.
Steam Flow INDICATION failing low based on PT-476 failing is NOT a TS action since the STEAM FLOW protection channel is NOT density compensated (i.e. not affected by the Pressure Transmitter failure).
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 2 Page 4 of 40 Event
Description:
PT-476, CH IV, 1A SG Steam Pressure Transmitter, fails LOW AOP-100, Instrumentation Malfunction, version 13 Section 1.5 (CONT)
TECHNICAL SPECIFICATION 3.3.2, ESFAS Instrumentation The ESFAS instrumentation for each Function in Table 3.3.2-1 shall be OPERABLE Table 3.3.2-1 ESFAS Instrumentation Function 1, e(2) - High Differential Pressure Between Steam Lines Applicable in Modes 1, 2 and 3 required channels 3 per stm line CONDITION D CONDITION REQUIRED ACTION COMPLETION TIME D. One D.1 ------NOTE--------
channel The inoperable channel inoperable. may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels.
Place channel in trip. 72 hrs OR D.2.1 Be in MODE 3. 78 hrs AND D.2.2 Be in MODE 4. 84 hrs Time Pos. Expected Actions/Behavior Comments SRO (step 6) Notify the Shift Manager SRO (step 7) WHEN plant conditions permit, THEN return systems to automatic control.
SRO (step 8) Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report.
Move to next event when SM notification complete and CR report directed or at the discretion of the lead examiner
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 6 Page 5 of 40 Event
Description:
PK-444A, Pressurizer Pressure Controller, fails LOW Indications Available:
Annunciators: Recognize indications of PK-444A failing LOW
- PRZR PRESS HI-LO (HC1)
- PK-444A controller reading 0% output
- PRZR HI-LO PRESS ALERT (HC2)
- BOTH Spray valves open
- PRZR PRESS REL VLV 445A OR B/U
- PORV-444B open HTRS ON (HD1)
- RCS pressure falling AOP-100, Instrumentation Malfunction, v13, section 1.1 Time Pos. Expected Actions/Behavior Comments SRO Directs AOP-100 section 1.1 immediate actions to be performed RO (step 1) Take manual control to raise RCS Immediate Operator Action pressure:
- PORVs PCV444B POTENTIAL CRITICAL TASK
- Sprays PK-444C & D If RCS pressure is not
- Heaters 1A, 1B, 1C, 1D, 1E controlled correctly a RX Trip
- PK-444A PRZR PRESS could occur.
REFERENCE controller RO (step 2) IF pressurizer pressure is Immediate Operator Action decreasing due to a mechanically stuck open spray valve PCV444C or PCV444D, THEN Both Spray valves will shut and perform the following: a reactor trip will not be
- IF the reactor trip breakers are closed, required THEN trip the reactor prior to pressure reaching 2100 PSIG.
- WHEN the reactor is tripped, THEN go to EEP-0, REACTOR TRIP OR SAFETY INJECTION.
Start the next event after operators have verified immediate operator actions and RCS Pressure is stable > 2200 psig or at the discretion of the Lead Examiner
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 5 Page 6 of 40 Event
Description:
Air Side Seal Oil Pump trip and Seal Oil Pressure Regulator Fails LOW Indications Available Annunciators: MCB Indication:
SEAL OIL PRESSURE LO (LF5) Air Side Seal Oil Pump Amber Trip Light Lit AIR SIDE SEAL OIL PUMP OFF (LF4)
Note to Examiner:
Operators may choose to respond using LF5 or LF4.
LF5 actions start on this page.
LF4 actions start on page 7.
ARP-1.11, Main Control Board Annunciator Panel L, v51.0 LF5 Time Pos. Expected Actions/Behavior Comments BOP (step 1 ) Notify appropriate plant personnel BOP (step 2) Verify the DC AIR SIDE Operator should start this EMERGENCY SEAL OIL PUMP is running pump since it failed to auto start.
BOP (step 3) Start the SEAL OIL BACKUP PUMP Operator should start pump.
BOP (step 4) If the DC Air Side Emergency Seal Oil Attached oil pump is supplying Pump is supplying the seal oil pressure (and the sufficient pressure through the attached Oil Pump is not available), Then start the Seal Oil Backup Pump and reduce hydrogen backup regulator.
pressure to 45 psig or less by the following:
(step 4.1) Reduce Generator Loading with appropriate UOPs and SOPs (step 4.2) When ready to reduce hydrogen pressure then reduce the pressure with SOP-27.0.
BOP (step 5) Actions Required if the Seal Oil Seal Oil Backup Pump will Backup Pump cannot be started start and the actions of this
- Reduce Generator Loading step will not be required
- Reduce Generator Pressure to 2 PSIG BOP (step 6) Correct the cause of the alarm BOP (step 7) Return the Hydrogen Seal Oil System to normal BOP (step 8) Return Hydrogen Pressure to normal At the discretion of the Lead Examiner move to the next event.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 5 Page 7 of 40 Event
Description:
Air Side Seal Oil Pump trip and Seal Oil Pressure Regulator Fails LOW ARP-1.11, Main Control Board Annunciator Panel L, v51.0 LF4 Time Pos. Expected Actions/Behavior Comments BOP (step 1 ) Verify Seal oil is being supplied by Operator will start DC air side either the turbine backup regulator or the DC emergency seal oil pump.
air side emergency seal oil pump BOP (step 2) Determine the cause of the alarm BOP (step 3) If the DC Air Side Emergency Seal The Seal Oil Backup Pump Oil Pump is supplying the seal oil pressure should be started (and the attached Oil Pump is not available),
Then start the Seal Oil Backup Pump and reduce hydrogen pressure to 45 psig or less by the following:
- Reduce generator load with applicable UOPs and SOPs
- When ready to reduce hydrogen pressure then reduce generator pressure IAW SOP-27.0, Generator Gas and Monitoring System.
BOP (step 4) Actions Required if the Seal Oil Seal Oil Backup Pump will Backup Pump cannot be started start and the actions of this step will not be required
- Reduce Generator Loading
- Reduce Generator Pressure to 2 PSIG BOP (step 5) If necessary to reduce hydrogen pressure then refer to SOP-27.0 BOP (step 6) Correct the cause of the alarm BOP (step 7) Return the Hydrogen Seal Oil System to normal BOP (step 8) Return Hydrogen Pressure to normal At the discretion of the Lead Examiner move to the next event.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 3 Page 8 of 40 Event
Description:
SG Tube leak increases to 160 GPD Indications Available Annunciators: Recognize indications of SG TUBE LEAK
- SG TUBE LEAK ABOVE SETPT (FG1)
- R-15 Levels rising
- R-70A READING 160 GPD ARP-1.6, Main Control Board Annunciator Panel F, v72.1 FG1 Time Pos. Expected Actions/Behavior Comments SRO Direct FG1 actions BOP (step 1)Check N1D11RISH0070A, B, & C to determine the magnitude of the leak and the generator indicating leakage.
BOP (step 3) Notify chemistry of the alarm condition (step 4) Take appropriate measures to return any OOS SG RMS equipment (step 5) Perform qualitative confirmation for the existence of a SG tube leak by checking two independent rad monitors.
SRO (step 6) IF this annunciator will not clear due to actual SG tube leakage OR an increase in existing tube leak is indicated, THEN go to FNP-1-AOP-2.0, STEAM GENERATOR AOP-2.0 actions on page 9.
TUBE LEAKAGE.
SRO (step 7) Refer to Technical Specifications T.S. Listed on page 12.
section 3.4.13 for limiting conditions for operation.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 3 Page 9 of 40 Event
Description:
SG Tube leak increases to 160 GPD Note to Examiner:
If operators exited AOP-2.0 at the end of event 1 then they should enter the procedure at step 1.
If operators remained in AOP-2.0 at the end of event 1 then they may enter this procedure at step 1 or continue from step 7.
AOP-2.0, Steam Generator Tube Leakage Ver. 35 Time Pos. Expected Actions/Behavior Comments RO (step 1) Maintain pressurizer level stable at NOTE: [CA] step normal programmed value by: FK-122 adjusted as required
- Control charging close one or more orifice isol.
- Reduce letdown close HV-8149 A, B, C valves RO (step 1.3) Determine leak rate, if possible (use STP-9.0, RCS leakage)
(RNO step 1.3) Determine leak rate based on flow balance
___________(charging flow)
+___________(seal injection flow)
-___________(letdown flow)
-___________(#1 seal leakoff flow)
=___________(RCS leak rate)
RO (step 2) Maintain VCT level greater than NOTE: [CA] step 20%. by: RNO is to trip the Rx and Verify RMW system in AUTO actuate an SI OR Manually control makeup as required by using SOP-2.3, CVCS Rx makeup system BOP (step 3) Check Unit in Mode 1 or Mode 2.
SRO (step 4) Check reactor power conditions:
- Check NO power ascension in progress
- Check NO power reduction in progress
- Check reactor power greater than 20%
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 3 Page 10 of 40 Event
Description:
SG Tube leak increases to 160 GPD AOP-2.0, Steam Generator Tube Leakage Ver. 35 (CONT)
Time Pos. Expected Actions/Behavior Comments BOP (step 5) Monitor primary to secondary NOTE: [CA] step leakage Check R-70s or R-15 for increasing count rate Chemistry will acknowledge Begin trending R-70A, SG TUBE LEAK, and CCP-31 app C R-15, SJAE EXH, using the plant computer and Data sheet 1.
BOP (step 6) Call TBSO to place SJAE filtration on service.
SRO (step 7) Direct chemistry to perform grab samples and leak rate determinations.
CCP-201 Table 55 (step 8) Notify SM of leak rate NOTE: [CA] step (step 9) Continue to monitor R-70s, R-15 or NOTE: [CA] step CHM/HP leak rate input for primary to secondary leak rate and rate of change using Data sheet 1.
SRO (Step 10) Monitor the Continuous Radiation NOTE: [CA] step Monitoring System operation.
[ ] R-70s - OPERABLE (step 11) Evaluate Table to determine AOP-2.0 will direct the crew to appropriate response: ramp to 50% power within 1
- ACTION LEVEL 3 Condition 1 hour. This will require entry 160 GPD into AOP-17.1, Rapid Power Reduction (See Page 13)
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 3 Page 11 of 40 Event
Description:
SG Tube leak increases to 160 GPD AOP-2.0, Steam Generator Tube Leakage Ver. 35 (CONT)
Time Pos. Expected Actions/Behavior Comments BOP (Step 12.1) Check any two of the following rad monitors trending in the same direction:
- R-70s/R-15 OR
- R-70s/R-23A(B) OR
- R-15/R-23A(B) trending in the same direction with the same order of magnitude SRO (step 12.2) Reduce power to less than or Begin ramping offline as RO equal to 50% within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> directed by the SM BOP (step 12.3) MODE 3 within 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> SRO (step 12.4)Identify the correct leaking SG 1A SG has a 160 gpm tube Using R-70s, R-60s and level rise in any SG leak BOP (step 12.6) Have Chemistry convert R-15 readings to gpd within 15 minutes.
SRO (step 12.7) Call SM to evaluate emergency classifications per NMP-EP-110 and EIP 8.0 SRO (step 17) Direct Chemistry to monitor the Step 12.8 directs operators to turbine building sump for activity step 17 SRO (step 18) Refer to FNP-0-AOP-2.1; Contingency Plan For Minimizing And Controlling Contaminated Secondary Condensate.
BOP (step 19) Verify affected SG(s) identified.
Check any SG level - RISING IN AN UNEXPLAINED MANNER.
OR Check any SG radiation indication - HIGH R-70 A, B, C and R-60 A, B, C
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 3 Page 12 of 40 Event
Description:
SG Tube leak increases to 160 GPD AOP-2.0, Steam Generator Tube Leakage Ver. 35 (CONT)
Time Pos. Expected Actions/Behavior Comments BOP (Step 20) Verify affected SG(s) atmospheric relief valve-ALIGNED
- 3371A 8.25 and in AUTO BOP (Step 21) Check affected SG atmospheric relief valve 3371A - CLOSED (Step 22) if TDAFWP is running or required TDAFWP not running or then direct the counting room to perform required CCP-645 (STEP 23) Check 1B or 1C SG(s) - Not affected AFFECTED.
BOP (Step 24) Verify SGBD isolated from the 1A SG- 7614A closed (Step 25) Check AS supplied from Unit 2 It is aligned from Unit 2 TECHNICAL SPECIFICATION 3.4.13, RCS Operational LEAKAGE RCS operational LEAKAGE shall be limited to:
- d. 150 gallons per day primary to secondary LEAKAGE through any one SG.
CONDITION REQUIRED ACTION COMPLETION TIME B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Action and AND associated B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> Completion Time of Condition A not met.
OR Pressure boundary LEAKAGE exists.
OR Primary to secondary LEAKAGE not within limit.
The next event (BATP fails to start in Auto) will occur when crew attempts boration.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 3 Page 13 of 40 Event
Description:
SG Tube leak increases to 160 GPD AOP-17.1, Rapid Turbine Power Reduction, v5.0 Time Pos. Expected Actions/Behavior Comments SRO (step 1) Perform a rapid ramp briefing Attachment 1 is on page 31 (step 1.1) Perform attachment 1 as time permits to aid the operating crew during rapid load reduction (step 1.2) Contact Reactor Engineering as soon as practical for fast ramp recovery recommendation.
(step 1.3) If power reduction will result in greater than 15% Rx power change within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. Then notify Shift Radiochemist of the change to plant load and to sample RCS per STP-746 (SR 3.4.16.2)
BOP (step 2) Reduce turbine load at desired rate in OPERATOR AUTO RO (step 3) Maintain Tavg within 5F of Tref Control rods should not be (step 3.1) If AUTO rod control desired for withdrawn with Tavg/Tref rapid load reduction, THEN verify control mismatch greater than 3F.
rods in AUTO When temp mismatch is 3F or (step 3.2) If required then initiate a manual less then rods can be boration. withdrawn for a maximum of 3 (step 3.3) Maintain Delta I within limits of the step per withdrawal.
COLR (step 3.4) If load rejection is great enough. A boration of 1Gallon per MW Check proper operation of the Steam rejected will limit control rod Dumps. insertion and assist in maintaining Delta I.
BOP (step 4) Control RCS/Secondary parameters (step 4.1) Check SG Narrow range levels trending to or maintained at ~65%
(step 4.2) Check PZR level trending to or maintained on program.
(step 4.3) Check PZR pressure maintained approximately 2235psig
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 3 Page 14 of 40 Event
Description:
SG Tube leak increases to 160 GPD RO (step 5) Check parameters within limits for continued operation
- PZR Level > 15%
- PZR Press > 2100 psig
- SGNR Level 35%-75%
- Tavg 541F-580F
- FE2 Clear
- Delta I w/in limits of COLR RO (step 6) When power reduction completed then restore Tavg to the programmed values (step 7) Check Loss of Load Interlock C-7A not illuminated (step 8) check plant stable.
(step 9) Check that power reduction was <
15% in an hour. If greater than 15% within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> then notify Shift Radiochemist to sample RCS per STP-746.
(step 10) Refer to SOP-72.0 for DEH Console Operations (Step 11) Go to procedure and step in effect.
The next event (BATP fails to start in Auto) will occur when crew attempts boration.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 4 Page 15 of 40 Event
Description:
BATP fails to start in AUTO Indications Available Annunciators: Recognize BATP fails to auto start during
- BA FLOW DEV HI-LO (DK2) - Auto Makeup
- Boration Note to Examiner:
Failure may become apparent during Boration required for ramp down or during auto makeup. If auto makeup fails to occur operators may respond using DK2 response procedure.
Operators may choose to swap the on service BATP due to the failure.
Operator actions for boration are in SOP-2.3 Appendix B (This page)
Operator actions for Auto makeup are in SOP-2.3 Figure 7 (Page 16)
Operator actions for DK2 (Page 17)
Operator actions for BATP swap are in SOP-2.3 section 4.6 (Page 18)
SOP-2.3, CVCS Reactor Makeup Control System, v60.1 Appendix B (BORATION)
Time Pos. Expected Actions/Behavior Comments RO (step 1.1) If necessary set the boric acid integrator to the desired quantity RO (step 1.2)If necessary adjust LTDN to VCT FLOW LK 112 setpoint as desired RO (step 1.3) Position MKUP MODE CONT switch to STOP (step 1.4) Position the MKUP MODE SEL SWITCH to BOR (step 1.5) Position the MKUP MODE CONT SWITCH to START RO (step 1.6) Verify proper boration operation by The on service boric acid observing the following: pump will fail to start in auto.
- On service boric acid pump started
- FCV-113B opens The operator should manually
- FCV-113A opens start the 1A or 1B BATP per
- FI-113 displays boric acid flow SOP-0.8.
When makeup is restored or at the discretion of the Lead Examiner move to the next event
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 4 Page 16 of 40 Event
Description:
BATP fails to start in AUTO SOP-2.3, CVCS Reactor Makeup Control System, v60.1 Figure 7 (Auto Makeup)
Time Pos. Expected Actions/Behavior Comments RO (step 1) Verify FI-113 boric acid flow agrees FI-113 will indicate zero flow with the Reactivity Briefing Sheet or the Operator may initiate flow by demand on the pot for FK-113 to prevent a starting the 1A or 1B BATP boric acid deviation alarm RO (step 2) For a Boric Acid Deviation Alarm refer to DK2 (step 3) Verify FI-168 indicates approximately 120 gpm (step 4) If desired to manually secure the makeup at any time during the makeup, place the MKUP MODE CONT SWITCH to STOP (step 5) Monitor VCT level, Tavg, SUR, and Control Rod moion to verify proper reactivity changes.
(step 6) Following makeup if 1B RMW pump is running and not required then secure the 1B RMW pump (Step 7) Refer to SOP-2.3 when time permits When makeup is restored or at the discretion of the Lead Examiner move to the next event
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 4 Page 17 of 40 Event
Description:
BATP fails to start in AUTO ARP-1.4, Main Control Board Annunciator Panel D, v54.2 DK2 Time Pos. Expected Actions/Behavior Comments RO (step 1) Take manual control of makeup in accordance with SOP-2.3 and monitor VCT Tank Level OR perform step 2 Actions for VCT high level not required (step 2) If the cause of the alarm is known and the makeup system is in automatic control then it is permissible to open FCV-114A and FCV-113B to complete the desired makeup RO (step 3) Determine the cause of the alarm (step 4) Notify appropriate personnel (step 5) Return the makeup system to automatic as soon as possible When makeup is restored or at the discretion of the Lead Examiner move to the next event
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 4 Page 18 of 40 Event
Description:
BATP fails to start in AUTO SOP-2.3, CVCS Reactor Makeup Control System, v60.1 Section 4.6 (Align for Auto Make Up)
Time Pos. Expected Actions/Behavior Comments RO (step 4.6.1) Determine the RCS Boron Concentration by sample or estimation RO (step 4.6.2) Verify the following
- Verify FK-113 is in manual and potentiometer set for RCS boron concentration
- (STEP 4.6.2.1/2) IV FK-113 (step 4.6.3) FK-168 controller in Auto RO (step 4.6.4) Position MKUP MODE CONT SWITCH to STOP (step 4.6.5) Verify FCV-113B closed in Auto (step 4.6.6) Verify FCV-113A closed in Auto (step 4.6.7) Verify FCV-114A closed in Auto (step 4.6.8) Verify FCV-114B closed in Auto RO (step 4.6.9) Verify 1A and 1B BATP secure Since the 1A BATP failed to with the on service BATP handswitch in start in auto the 1B BATP AUTO should be placed on service and aligned to automatic RO (step 4.6.10) Verify 1A or 1B RMW pump is supplying the makeup system (step 4.6.11/12) Secure running RMW pumps that are not required by placing hand switch in stop and back to auto RO (step 4.6.13) Place MKUP MODE SEL switch to AUTO (step 4.6.14) Position the MKUP MODE CONT SWITCH to START When makeup is restored or at the discretion of the Lead Examiner move to the next event
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 7 Page 19 of 40 Event
Description:
1A Spray Valve Drifts Open Indications Available:
Annunciators: Recognize indications of A spray valve drifting
- PRZR PRESS HI-LO (HC1) open in manual
- PRZR HI-LO PRESS ALERT (HC2)
- PK-444C at 100% demand
- PRZR PRESS REL VLV 445A OR B/U
- 1A Spray valve open HTRS ON (HD1)
- RCS pressure falling Note to Examiner Operators should trip the plant due to a stuck open spray valve. The turbine will require a manual trip. This series of events may result in an automatic Safety Injection.
Procedural guidance will direct operators to transition to FRP-H.1, Response to Loss of Secondary Heat Sink. The transition to FRP-H.1 will initiate the next event.
AOP-100, Instrumentation Malfunction, v13, section 1.1 Time Pos. Expected Actions/Behavior Comments SRO Directs AOP-100 section 1.1 immediate actions to be performed RO (step 1) Take manual control to raise RCS Immediate Operator Action pressure:
- PORVs PCV444B
- Sprays PK-444C & D
- Heaters 1A, 1B, 1C, 1D, 1E
- PK-444A PRZR PRESS REFERENCE controller RO (step 2) IF pressurizer pressure is Immediate Operator Action decreasing due to a mechanically stuck open spray valve PCV444C or PCV444D, THEN 1A Spray Valve will not close.
perform the following: Operators should trip the RX
- IF the reactor trip breakers are closed, prior to reaching 2100 PSIG THEN trip the reactor prior to pressure reaching 2100 PSIG. (EEP-0 Actions on next page)
- WHEN the reactor is tripped, THEN go to EEP-0, REACTOR TRIP OR SAFETY INJECTION.
BOP WHEN the reactor is tripped, THEN verify 1A BOP will verify the reactor is and 1B RCPs secured. tripped and then secure 1A and 1B RCPs
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 7 Page 20 of 40 Event
Description:
1A Spray Valve Drifts Open EEP-0, Reactor Trip or Safety Injection, v45 Time Pos. Expected Actions/Behavior Comments SRO Reactor trip Direct the reactor trip and enter EEP-0.
RO/ Immediate Operator actions of EEP-0 CRITICAL TASK BOP (step 1) Check reactor trip. Manually Trip the Turbine (step 2) Check Turbine Trip before an Orange path (step 2 RNO) Perform the following challenge develops to the (step 2.1 RNO) Place emergency trip switch subcriticallity or integrity to trip for at least 5 seconds CSF or before transition to (step 2.2 RNO) If turbine cannot be tripped ECP-2.1 then reduce GV position demand to zero
-TURBINE MANUAL depressed
- GV CLOSE depressed
- FAST ACTION depressed (step 3) Verify power to 4160V ESF Busses RO/ (step 4) Check SI Status. If SI is actuated then the BOP (step 4.1) Check any SI actuated indication. operators should continue with BYP & PERMISSIVE SAFETY INJECTION EEP-0.0.
[] ACTUATED status light lit
[] MLB-1 1-1 lit If SI is not actuated the
[] MLB-1 11-1 lit operators should transition out (step 4.1 RNO) Check SI Required of EEP-0 and recognize entry (step 4.1.1 RNO) If any SI setpoint is conditions for FRP-H.1 (Next reached then SI is required. Event, Page 22)
(step 4.1.2 RNO) If SI is required then actuate SI (step 4.1.3 RNO) If SI is not required then go to ESP-0.1 Reactor Trip Response SRO (step 5) Directs the BOP to perform Attachment 2 and 4 actions are Attachment 2 of EEP-0. on Page 31 (step 6) Check containment pressure- HAS [CA] step RO REMAINED LESS THAN 27 psig (checked on IPC or PI950, 951, 952, 953,CNMT PRESSURE)
RO (step 7) Announce "Unit 1 reactor trip and safety injection".
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 7 Page 21 of 40 Event
Description:
1A Spray Valve Drifts Open Enter EEP-0, Reactor Trip or Safety Injection, v45 (CONT)
Time Pos. Expected Actions/Behavior Comments RO (step 8) Check AFW status. The operators should Check secondary heat sink Available recognize FRP-H.1 entry o Check total AFW flow > 395 gpm conditions and transition to
[] FI 3229A FRP-H.1 (See Page 22).
[] FI 3229B
[] FI 3229C o Total Flow FI 3229 OR Check any SG NR level > 31% {48%}
(step 8 RNO)
- Verify all available AFW pumps are started
- Verify total AFW flow is greater than 395 gpm
- If AFW flow < 395 gpm and All SG narrow range levels less than or equal to 31% then go to FRP-H.1 Transition to FRP-H.1 will initiate the next event
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 8 Page 22 of 40 Event
Description:
FRP-H.1 with SGFP or Condensate Pump Recovery FRP-H.1 , Response to Loss of Secondary Heat Sink, v27 Time Pos. Expected Actions/Behavior Comments SRO (step 1) Check secondary heat sink -
REQUIRED.
- Check RCS hot leg temperatures
> 350°F on TR 413 SRO (step 2) Directs monitoring of bleed and feed criteria
- Check at least two SG wide range levels GREATER THAN 12% {31%}.
- Check pressurizer pressure < 2335 psig SRO (step 3) Direct I&C to defeat feedwater NOTE: Calls I&C isolation signal by installing jumpers per ATTACHMENT 1.
BOP (step 4) Check CST level > 5.3 feet and call for makeup to CST as required BOP (step 5) Try to establish AFW flow to at least NOTE: [CA] Step one SG.
(step 5.1) Verifies blowdown isolated from all SGs 1A(1B,1C) SGBD ISO
- Q1G24HV7614A closed
- Q1G24HV7614B closed
- Q1G24HV7614C closed (step 5.2) Verifies SG blowdown sample valves isolated
- MLB4 6-4 lit
- MLB4 7-4 lit
- MLB4 8-4 lit (step 5.3) Recognizes AFW pumps not available and attempt to start from HSP. AFW pumps will not start from any location.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 8 Page 23 of 40 Event
Description:
FRP-H.1 with SGFP or Condensate Pump Recovery FRP-H.1 , Response to Loss of Secondary Heat Sink, v27 (CONT)
Time Pos. Expected Actions/Behavior Comments (step 5.4) Verify at least one flow path to at least one SG ALIGNED Checks OPEN MDAFP to 1A/B/C SG (where x = respective SG A, B or C)
- HIC3227xA MDAFW FCVs adjusted
- HIC3228xA TDAFW FCVs adjusted
- MOV-3350x AFW STOP vlv OPEN
- MOV3764x MDAFW to SG OPEN (step 5.5) [CA] Check total AFW flow to Continue efforts to establish SGs greater than 395 gpm. AFW flow.
WHEN any feed flow established AND at least one SG narrow range level greater than 31%{48%} THEN go to procedure and step in effect RO (step 6) Stops all RCPs SRO (step 7) Try to establish main feedwater flow IF MSIVs are closed SGFPs to intact SGs with one SGFP. will not be available and (step 7.1) Verify at least one CNDS Pump operators should restore Started with backup flow to SGs with condensate (step 7.1.1) Verify backup cooling aligned to condensate pumps per SOP-21.0 pumps. (STEP 9)
(step 7.2) Check intact SGs main steam line isolation valves - OPEN (step 7.3) Check all intact SG pressure greater than 540 psig (step 7.4) Check Condenser Available (step 7.5) Verify EH pump running (step 7.6) Verify SGFP lube oil available (step 7.7) Verify all Main Feed and Bypasses closed (step 7.8) If SI not actuated then reset FW Isolation.
(step 7.9) Check FWI signal defeated per attachment 1 (step 7.10) Verify Phase A CTMT ISO Reset
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 8 Page 24 of 40 Event
Description:
FRP-H.1 with SGFP or Condensate Pump Recovery RO (step 7.11) Verify SW TO TURB BLDG ISO open or throttled.
V515, V516, V517, V514, V540, V542, V543, V541 (step 7.12) Verify SGFP speed control manually adjusted to 0%
(step 7.13) Latch SGFP turbine (step 7.14) Open SGFP Low Press Stop Valve (step 7.15) Open SGFP High Press Stop Valve (step 7.16) Raise SGFP to minimum speed Increase speed depressed until Boiler control light illuminated.
(step 7.17) Open SGFP discharge valve
-V503A or V503B (step 7.18) Verify all intact SGs main feedwater stop valves open.
-MOV 3232A, MOV-3232B, MOV-3232C (step 7.19) Place SGFP speed controller in AUTO.
-SK-509B, SK-509C (step 7.20) Adjust master speed controller to raise feedwater discharge header pressure to 50 psi greater than steam header pressure using PI 464A and PI 508.
(step 7.21) Control Feedwater regulating Critical Task bypass valves to supply main feedwater to Establish feedwater flow to intact SGs (step 7.22) When P-12 light lit then:
at least one S/G before RCS Block Low Steam Line Pressure SI feed and bleed is required.
Verify Blocked indication on BYP and Permissive panel (step 8) Check S/G Levels (step 8.1) Verify feed flow to at least one SG (8.1 RNO) go to step 9 (step 8.2) check at least 1 SG greater than 31% {48%}. IF restoration of SG feed with (step 9) Try to establish condensate flow to a SGFP is unsuccessful or intact SGs. impossible then Step 8.1 RNO 9.1 IF SI has NOT actuated since directs the crew to step 9 for reactor trip, THEN reset FW ISO. Condensate pump recovery.
RNO 9.1 Verify SI RESET.
[] MLB-1 1-1 not lit
[] MLB-1 11-1 not lit
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 8 Page 25 of 40 Event
Description:
FRP-H.1 with SGFP or Condensate Pump Recovery FRP-H.1 , Response to Loss of Secondary Heat Sink, v27 (CONT)
Time Pos. Expected Actions/Behavior Comments NOTE: Step 9.8, Pressurizer pressure reduction, should be performed in conjunction with steps 9.2 through 9.7.
BOP (step 9.2) Check feedwater isolation signal to intact SGs main feedwater regulating bypass valves defeated per ATTACHMENT 1.
BOP (step 9.3) Verify all main feedwater flow control and bypass valves - CLOSED IN MANUAL.
- FK 478
- FK 488
- FK 479
- FK 489
- FK 499 BOP (step 9.4) Verify backup cooling aligned to condensate pumps per FNP-1-SOP-21.0.
BOP (step 9.5) Locally open SGFP BYP N1N21V509. (155 ft, TURB BLDG)
(step 9.6) Locally isolate SGFP miniflow valves. (155 ft, TURB BLDG)
SGFP 1A(1B) RECIRC FCV INLET ISO
- N1N21V502A closed
- N1N21V502B closed
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 8 Page 26 of 40 Event
Description:
FRP-H.1 with SGFP or Condensate Pump Recovery FRP-H.1 , Response to Loss of Secondary Heat Sink, v27 (CONT)
Time Pos. Expected Actions/Behavior Comments BOP (step 9.7) Perform the following.
9.7.1 Dispatch personnel to 1V 600 V MCC.
9.7.2 Place handswitch for main feedwater stop valves to intact SGs to OPEN and hold in that position.
- 3232B
- 3232C 9.7.3 WHEN main feedwater stop valves to intact SGs open, THEN direct personnel to open associated breakers.
- FV-L2 BOP (step 9.7.4) WHEN associated breaker open, THEN allow main feedwater stop valve handswitch to spring return.
RO (step 9.8) Reduce PRZR pressure to less than 1950 psig.
9.8.1 Check either condition for using RNO 9.8.1 Perform the auxiliary spray satisfied. following.
- Normal letdown in service. If normal letdown secured OR and THEN open only one
AND Proceed to step 9.9.
RO (step 9.8.2) Manually open both normal pressurizer spray valves.
- PK 444C
- PK 444D
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 8 Page 27 of 40 Event
Description:
FRP-H.1 with SGFP or Condensate Pump Recovery FRP-H.1 , Response to Loss of Secondary Heat Sink, v27 (CONT)
Time Pos. Expected Actions/Behavior Comments RO (step 9.8.3) Open auxiliary spray valve.
RCS PRZR AUX SPRAY
- Q1E21HV8145 open RO (step 9.8.4) Verify flow path aligned CHG FLOW
- FK 122 manually open CHG PUMPS TO REGENERATIVE HX
- Q1E21MOV8107 open
- Q1E21MOV8108 open RCS NORMAL CHG LINE
- Q1E21HV8147 closed RO (step 9.8.5) Operate the following valves as required to reduce PRZR pressure to less than 1950 psig.
CHG FLOW
- PK 444C manually open/closed
- PK 444D manually open/closed RCS PRZR AUX SPRAY
- Q1E21HV8145 open/closed RCS NORMAL CHG LINE
- Q1E21HV8147 open/closed RO (step 9.9) Maintain PRZR pressure at 1900-1950 psig.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 8 Page 28 of 40 Event
Description:
FRP-H.1 with SGFP or Condensate Pump Recovery FRP-H.1 , Response to Loss of Secondary Heat Sink, v27 (CONT)
Time Pos. Expected Actions/Behavior Comments RO (step 9.9.1) IF using auxiliary spray, THEN RNO 9.9.1 IF using a PRZR operate the following valves as required to PORV, THEN open only one control PRZR pressure. PRZR PORV to control PRZR CHG FLOW pressure.
- PK 444C manually open/closed
- PK 444D manually open/closed RCS PRZR AUX SPRAY
- Q1E21HV8145 open/closed RCS NORMAL CHG LINE
- Q1E21HV8147 open/closed RO (step 9.10) WHEN pressurizer pressure less than 2000 psig, THEN perform the following.
9.10.1 Block low pressurizer pressure SI.
PRZR PRESS SI BLOCK - RESET
- A TRN to BLOCK
- B TRN to BLOCK 9.10.2 Verify blocked indication.
BYP & PERMISSIVE PRZR. SAFETY INJECTION (step 9.11) WHEN P-12 light lit (543F),
THEN perform the following.
9.11.1 Block low steam line pressure SI.
STM LINE PRESS SI BLOCK - RESET
- A TRN to BLOCK
- B TRN to BLOCK 9.11.2 Verify blocked indication.
BYP & PERMISSIVE STM LINE ISOL.
SAFETY INJ.
- TRAIN A BLOCKED light lit
- TRAIN B BLOCKED light lit 9.11.3 Bypass the steam dump interlock.
STM DUMP INTERLOCK
- A TRN to BYP INTLK
- B TRN to BYP INTLK
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 8 Page 29 of 40 Event
Description:
FRP-H.1 with SGFP or Condensate Pump Recovery FRP-H.1 , Response to Loss of Secondary Heat Sink, v27 (CONT)
Time Pos. Expected Actions/Behavior Comments (step 9.12) IF condenser available, RNO 9.12 Dump steam to THEN dump steam to condenser atmosphere. 9.12.1 Direct from intact SGs at maximum counting room to perform attainable rate.
FNP-0-CCP-645, MAIN STEAM ABNORMAL ENVIRONMENTAL RELEASE.
RNO 9.12.2 IF normal air available, THEN control atmospheric relief valves to dump steam from at least one intact SG at maximum attainable rate.
1A(1B,1C) MS ATMOS REL VLV
[] PC 3371A adjusted
[] PC 3371B adjusted
[] PC 3371C adjusted (step 9.13) WHEN SG(s) pressure reduced to less than 540 psig, THEN stop pressure reduction.
(step 9.14) Maintain SG(s) pressure -
STABLE AT EXISTING VALUE.
(step 9.15) Verify at least one CNDS PUMP
- STARTED.
(step 9.16) Check SGFP BYP N1N21V509 -
OPEN. (155 ft, TURB BLDG)
(step 9.17) Initially open feedwater regulating bypass valves just off the closed seat to initiate flow and minimize any water hammer.
- 479 adjusted
- 489 adjusted
- 499 adjusted
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 8 Page 30 of 40 Event
Description:
FRP-H.1 with SGFP or Condensate Pump Recovery FRP-H.1 , Response to Loss of Secondary Heat Sink, v27 (CONT)
Time Pos. Expected Actions/Behavior Comments (step 9.18) Control feedwater regulating bypass valves to supply main feedwater to at least oneintact SG.
(step 10) Check SG levels.
10.1 Verify feed flow to at least one SG.
- Check SG wide range level -
RISING.
OR Check core exit T/C temperature - FALLING.
(step 10.2) Check at least one SG narrow 10.2 Continue feeding SGs to range level - GREATER THAN restore at least one SG narrow 31%{48%}. range level greater than 31%{48%}.
Terminate scenario when FRP-H.1 is exited or at the discretion of the Lead Examiner.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 5 Page 31 of 40 Event
Description:
Attachment 1 of AOP-17.1 AOP-17.1, Rapid Turbine Power Reduction Attachment 1 Time Pos. Expected Actions/Behavior Comments (Step 1) Address any OFF Normal conditions that could adversely effect stable SRO plant operation during the load reduction.
(step 2) Contact appropriate authority of load reduction.
- ACC
- SYSTAT (step 3) Prior to going below 65% power, verify the HP steam supply valve is open to the SGFP which is to remain in operation.
- V501A
- V501B BOP (step 4) WHEN power level is reduced to approximately 60% or less, THEN perform the following:
- Remove a main Teed pump from operation per FNP-1 -SOP-21 .0, CONDENSATE AND FEEDWATER SYSTEM.
THEN transfer Circulating Water make up control valve Q1P16V560 to REMOTE MANUAL per FNP-1 -SOP-26.0, CIRCULATING WATER SYSTEM.
- WHEN Q1P16V560 Circ Water make up control valve i s in REMOTE MANUAL and adjusted to minimum, THEN it may be necessary to control canal level manually using N1P16V748.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 5 Page 32 of 40 Event
Description:
Attachment 1 of AOP-17.1 BOP (step 5)WHEN reactor power is reduced below 35%,
THEN perform the following:
- Place the control switches for the SGFP mini flows to the open position.
- Stop alI but one condensate pump.
- if desired, THEN secure one circulating water pump per FNP-1 -SOP- 26.0, CIRCULATING WATER SYSTEM.
- lf required, THEN at the local control station/panel, cooling tower fans may be stopped as necessary.
- Reference FNP-1 -ARP-1 .10 ann KK2 and monitor condenser pressure. An automatic turbine trip occurs at 4.351 psia.(8.9 in Hga)
- Verify that the turbine trip reactor trip is blocked as indicated by the P9 bistable status Iights are not being iIluminated.
(TSLB3 lights 9.1 through 9.4; 3/4 coincidence required)
BOP (step 6) WHEN reactor power is reduced below 30%, THEN verify that the single loop loss of flow reactor trip is blocked as indicated by the Low Power Low Flow Trip Block permissive status light being illuminated.
BOP (step 7) As power level approaches 20%,
perform the following:
- Monitor steam generator level, TAVG, pressurizer level and pressure.
- Verify proper operation of automatic control systems.
- Verify automatic Turbine Drain valve opening below approximately 170 MW.
BOP (step 8) Ensure 1A, 18 and 1C 4160V busses aligned to the startup transformers per FNP-1-SOP-36.2, 4160 V AC ELECTRICAL DISTRIBUTION SYSTEM
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 5 Page 33 of 40 Event
Description:
Attachment 1 of AOP-17.1 BOP (step 9) If the main generator is tied to the grid, THEN perform the following:
- Notify ACC the generator i s ready for unloading.
- WHEN ACC gives permission to remove the generator from the grid, THEN begin ramping generator load down to approximately 40 MW per FNP-1-SOP-28.1, TURBINE GENERATOR OPERATION.
RO Prior to reducing reactor power below 13%,
check the status of the intermediate range trip bistable Iights TSLB 3 2.1(2.2).
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 8 Page 34 of 40 Event
Description:
1A Spray Valve Drifts Open EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments (Step 1) Verify one CHG PUMP in each train - STARTED.
BOP [] A train (1A or 1B) amps > 0
[] B train (1C or 1B) amps > 0 BOP (Step 2) Verify RHR PUMPs - STARTED.
RHR PUMP
[] 1A amps > 0
[] 1B amps > 0 BOP (Step 3) Verify Safety Injection Flow.
(Step 3.1) Check HHSI flow - GREATER THAN 0 gpm.
[] FI 943 BOP (Step 3.2) Check RCS pressure - LESS THAN 275 psig{435 psig}.
BOP (step 3.3) Check LHSI flow - greater than 3
1.5 X10 gpm
[] 1B RHR HDR FLOW FI-605B BOP (Step 4) Verify each SW train - HAS TWO SW PUMPs STARTED.
[] A train (1A,1B or 1C)
[] B train (1D,1E or 1C)
BOP (Step 5) Verify each train of CCW -
STARTED.
(Step 5.1) Verify one CCW PUMP in each train-STARTED.
[] FI 3043CA > 0 gpm OR
[] FI 3043BA > 0 gpm B train HX 1A or 1B CCW FLOW
[] FI 3043AA > 0 gpm OR
[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM 1A(1B, 1C) CCW HX
[] Q1P16FI3009AA > 0 gpm
[] Q1P16FI3009BA > 0 gpm
[] Q1P16FI3009CA > 0 gpm
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 8 Page 35 of 40 Event
Description:
1A Spray Valve Drifts Open EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments (Step 5.3) Check instrument air available.
Verify at least one air compressor started.
AIR COMPRESSOR
[] 1A
[] 1B
[] 1C Check INST AIR PRESS PI 4004B greater than 85 psig.
BOP (step 6) Verify containment ventilation isolation.
Verify containment purge dampers -
CLOSED.
[] 3197
[] 3198D
[] 3198C
[] 3196
[] 3198A
[] 3198B Verify containment mini purge dampers -
CLOSED.
CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D
[] 2866C
[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C
[] 2866D
[] 2867D Stop MINI PURGE SUPP/EXH FAN.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 8 Page 36 of 40 Event
Description:
1A Spray Valve Drifts Open EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments BOP (step 7) Verify containment fan cooler alignment.
Verify at least one containment fan cooler per train - STARTED IN SLOW SPEED.
CTMT CLR FAN SLOW SPEED A train
[] 1A
[] 1B B train
[] 1C
[] 1D Verify associated emergency service water outlet valves - OPEN.
EMERG SW FROM 1A(1B,1C,1D) CTMT CLR
[] Q1P16MOV3024A
[] Q1P16MOV3024B
[] Q1P16MOV3024C
[] Q1P16MOV3024D BOP (step 8) Verify AFW Pumps - STARTED.
Verify both MDAFW Pumps - STARTED
[] 1A MDAFW Pump amps > 0
[] 1B MDAFW Pump amps > 0 AND
[] FI-3229A indicates > 0 gpm
[] FI-3229B indicates > 0 gpm
[] FI-3229C indicates > 0 gpm (Step 8.2) Check TDAFW Pump start required.
Condition TSLB Setpoint Coincidence RCP Bus TSLB2 1-1 2680 V 1/2 Detectors Undervoltage 1-2 1-3 on 2/3 Busses Low Low SG TSLB4 28% 2/3 Detectors Water Level 4-1,4-2,4-3 on 2/3 SGs In Any 5-1,5-2,5-3 2/3 SGs 6-1,6-2,6-3
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 8 Page 37 of 40 Event
Description:
1A Spray Valve Drifts Open EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments BOP (step 8.3) Verify TDAFWP started.
[] MLB-4 1-3 lit
[] MLB-4 2-3 lit
[] MLB-4 3-3 lit TDAFWP SPEED
[] SI 3411A > 3900 rpm TDAFWP SPEED CONT
[] SIC 3405 adjusted to 100%
Verify TDAFW flow path to each SG.
TDAFWP TO 1A(1B,1C) SG
[] Q1N23HV3228A in MOD
[] Q1N23HV3228B in MOD
[] Q1N23HV3228C in MOD TDAFWP TO 1A(1B,1C) SG FLOW CONT
[] HIC 3228AA open
[] HIC 3228BA open
[] HIC 3228CA open BOP (step 9) Verify main feedwater status.
Verify main feedwater flow control and bypass valves - CLOSED.
[] FCV 478
[] FCV 488
[] FCV 498 Verify both SGFPs - TRIPPED.
Verify SG blowdown - ISOLATED.
[] Q1G24HV7614A closed
[] Q1G24HV7614B closed
[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample -
ISOLATED MLB lights lit.
1A(1B,1C) SGBD SAMPLE STEAM GEN ISO
[] MLB1 19-2 lit Q1P15HV3328 closed
[] MLB1 19-3 lit Q1P15HV3329 closed
[] MLB1 19-4 lit Q1P15HV3330 closed
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 8 Page 38 of 40 Event
Description:
1A Spray Valve Drifts Open EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments BOP (Step 10) Check no MSL isolation actuation signal present.
Signal Setpoint coincidence TSLB LO SG PRESS < 585 psig 2/3 TSLB4 19-2,3,4 Hi stm flow >40% 1/2 on 2/3 TSLB4 16-3,4 and and 17-3,4 18-3,4 Lo-Lo Tavg <543°F 2/3 TSLB2 10-1,2,3 HI-HI ctmt press >16.2 psig 2/3 TSLB1 2-2,3,4 (Step 11) Verify PHASE A CTMT ISO. RNO (Step 11.1) Verify PHASE A CTMT ISO - Step 11.2 Verify PHASE A ACTUATED. CTMT ISO alignment using BOP [] MLB-2 1-1 lit ATTACH 3, PHASE A CTMT
[] MLB-2 11-1 lit ISO 11.2 Check all MLB-2 lights - LIT.
BOP (step 12) Check all reactor trip and reactor trip bypass breakers - OPEN Reactor trip breaker A Reactor trip breaker B Reactor trip bypass breaker A Reactor trip bypass breaker B BOP (step 13) Trip CRDM MG set supply breakers.
1A(1B) MG SET SUPP BKR
[] N1C11E005A
[] N1C11E005B BOP (step 14) Secure secondary components.
Stop both heater drain pumps.
HDP
[] 1A [] 1B Check any condensate pump started.
IF started, THEN stop all but one condensate pump.
[] 1A [] 1B If NO condensate pumps are started then place all HSs to STOP (step 14.3) IF condensate pump operating, THEN verify backup cooling aligned to condensate pumps per FNP-0-SOP-0.0, APPENDIX B, TB SO Actions Following A Will call TBSO to Reactor Trip Or Safety Injection. accomplish this.
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 8 Page 39 of 40 Event
Description:
1A Spray Valve Drifts Open EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 2 Time Pos. Expected Actions/Behavior Comments BOP (step 15) Verify both CRACS mode selector switches in the ON position.
CRACS Mode Selector Switch
[] A TRAIN
[] B TRAIN Will call BOOTH to have this accomplished since this is not in the simulator BOP (step 16) WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.
230 KV BKR
[] 810 - OPEN
[] 914 - OPEN BOP (step 17) Verify two trains of ECCS equipment aligned.
Perform ATTACHMENT 4, Two Train ECCS Alignment Verification.
(See Next Page)
End of Attachment 2
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2014301 Scenario # 5 Event # 8 Page 40 of 40 Event
Description:
1A Spray Valve Drifts Open EEP-0.0, Reactor Trip or Safety Injection, v45 Attachment 4 Time Pos. Expected Actions/Behavior Comments BOP (Step 1) Verify two trains of ECCS equipment aligned.
[] Check DF01 closed
[] Verify DF02 closed
[] Check DG15 closed
[] Verfiy DG02 closed
[] Verify two trains of battery chargers -
energized Amps > 0 (Step 1.6) Verify two trains of ESF equipment aligned.
[] Check all MLB-1 lights LIT Verify charging pump suction and discharge valves - OPEN.
[] Q1E21MOV8132A
[] Q1E21MOV8132B
[] Q1E21MOV8133A
[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO
[] Q1E21MOV8130A
[] Q1E21MOV8130B
[] Q1E21MOV8131A
[] Q1E21MOV8131B BOP (Step 1.7) Verify all post accident containment air mixing system fans - STARTED. (BOP)
POST ACCIDENT MIXING FAN
[] 1A [] 1B [] 1C [] 1D RX CAV H2 DILUTION FAN
[] 1A [] 1B (Step 1.8) WHEN power restored to any de-energized emergency bus, THEN verify alignment of associated equipment.
BOP (Step 1.9) Verify SFP Cooling in service per Call Radside SO SOP-54.0, Spent Fuel Pit Cooling And Purification System.
End of Attachment 4
Appendix D Crew Briefing sheet Form ES-D-3 Op-Test No.: FA2014301 Page 1 of 2 Brief This simulator performance scenario is performed in the EVALUATION MODE. You should not direct questions to the evaluators. Otherwise, you should perform as if you were in the MCR.
Your ability to maintain a log is not being graded, but maintaining a rough log is recommended to help during briefs.
If you need to communicate with the Unit 2 operator, call Unit 2 at 2434 or page the Unit 2 Unit Operator.
Respond to what you see. If there is a problem with the simulation, the session will be terminated or adjusted as appropriate based on the specific problem.
Assign operating positions.
Ask for and answer questions.
Appendix D Turnover sheet Form ES-D-3
[ X ] Unit 1 [ ] Unit 2 Shift: Date Off-going SS Oncoming SS [ ]N [X]D Today Part I - To be reviewed by the oncoming Supervisor prior to assuming the shift.
Security Keys A, S, D, SW, X on key ring . SS Unit 95% power, 894 ppm Cb, MOL 10000 MWD/MTU Status TARGET ZERO STPs/Evolutions: Every Day, Every Job Safely A Train On-Service - B Train Protected 1.0 ; 109.1 No adj. ; 63.7 ; FSP-20,0 ;
Status of Special Testing General Information
- 2. 1A MDAFW Pump is tagged out for bearing replacement
- 4. Current Risk Assessment is GREEN and projected is GREEN
- 5. Unit 2 is at 100% power with no major issues.
- 6. Maintain current power level for SG Tube Leakage Evaluation 7.
8.
9.
Equipment Status Maintain VCT gas pressure 25-30 psig Reactivity Plan Waste Management Status 50 gallon dilutions every ten minutes #3 RHT - On Service WGS - secured LCO Status 3.7.5 Condition B (1A MDAFW Pump)
Night Orders No New Night Orders Part II Review Shift Complement LCOs Reviewed SS (initials) reviewed as early in shift as possible Part III: STP-1.0 Operator Logs Cond. Report Autolog ELDS & GEN Keys Reviewed/Signed Reviewed Queue Reviewed Spreadsheet Turned Reviewed verified Over
[ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes
Unit One Reactivity Briefing Sheet RCS Temp 570.0 °F Current RCS Borations / Dilutions:
RX PWR 95.0 % Borate Dilute Current Xenon Concentration 2277 PCM 0 Gal. 50 Gal.
Burnup 10000 MWD/MTU Reactivity Additions: 0.00 7.07 PCM As of (Date & Time) 10/2/2013 1:00 Total Reactivity Addition: 7.07 PCM Calculated Burnup 24148 MWD/MTU Net RCS Temperature Effect: 0.37 °F As Of 9/23/14 1205 Net Rx Power Effect: 0.28 %
Assumes constant power since Last Power history update Boron Worth -8.67 PCM/PPM RCS Boron 894 PPM Power Defect 2,381 PCM BAT Concentration 7436 PPM MTC -18.86 PCM/°F Current Bank Boric Acid Required for Power reduction Delta Rod Position: 216 Steps With no Control rod movement Power Acid Defect Required Rod Worth DeltaPower (PCM) Delta PPM (Gallons)
Steps Out 1.00% 23 2.65 20 One 10 PCM 2.00% 47 5.29 40 Two 20 PCM 5.00% 117 13.23 101 Five 45 PCM 10.00% 233 26.47 201 Ten 69 PCM 20.00% 466 52.94 404 Twenty
- 25.00% 583 66.17 505 Fifty
- 50.00% 1,182 134.24 1030 75.00% 1,848 209.90 1620 Steps In 100.00% N/A N/A N/A One -13 PCM Two -26 PCM Five -67 PCM a/o w/o Ten -145 PCM RCS B-10 ratio 17.98 16.6 Twenty -309 PCM BAT B-10 ratio 20.1 18.6 Fifty -691 PCM NDR B-10 ratio 19.8 18.3 RCS Blended Flow Makeup Requirements Acid to RMW to dilute 1 PPM( Required FK-113 Borate 1 PPM Gal.) Acid flow Pot (Gal.) Rate Setting (GPM)
Values for Normal 7.7 Gal. 55.5 Gal. 14.6 GPM 3.64 Auto M/U (Bat-100 ppm boron)
Values based on 7.6 Gal. 55.5 Gal. 14.4 GPM 3.60 Actual Bat Concentration Valid For Unit One cycle 24 26 Core Physics Curves:
Curve 5 Rev 29 Curve 27 Rev 28 Curve 34 Rev 46 Curve 57 Rev 35 Curve 57A Rev 25 Printed by 9/23/2014 @ 12:06 PM Copy of U1 reactivity sheet Version 5.2
Scenario #5 FA2014301 Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-37 NRC EXAM SCENARIO #5 Validation time: 90 minutes Validated by: Sorrell, Smith, Jackson TRN Supervisor Approval: Billy Thornton Date: 9/24/14 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3
Appendix D Scenario #5 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 5 Op-Test No.: FA2014-301 Examiners: Operators: SRO RO BOP Initial Conditions: 95% power, AOP-2 step 16.1. MOL, 894 ppm Cb; Turnover:
Current Risk Assessment is GREEN and projected to remain GREEN.
A Train O/S, B Train protected.
1A MDAFW pump tagged out for bearing replacement.
7 gpd tube leak.
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia.
Maintain current power level for SG Tube Leakage evaluation SPLIT TRAIN ALIGNMENT Event Malf. Event Type* Event Description No. No.
1 N (BOP) Adjust R-70 setpoint 2 Imf I (BOP) PT-476 fails low (P-CT) pt476 TS (SRO) TS 3.3.2 Cond D Imf 3 pk444a-a C (RO) PK-444A fails low. (P-CT) 4 Imf C BOP Main Generator Seal oil pressure decreases due to air side seal oil sgs508 pump trip and regulator malfunction - automatic actions are 7a_cc3 blocked 5 Irf loa- R (RO) Tube leak increases to 160GPD, ramp unit offline rds001 TS (SRO) TS 3.4.13 Cond B 6 Preset C (RO) Selected BAT pump will not Auto start during Auto makeup or borations Imf 7 M (ALL) A loop spray valve drifts open in manual control pk444c-m Reactor is tripped due to stuck open spray valve C (BOP) Main Turbine will not trip automatically or manually. GV closure is required (CT-13) 1B MDAFW will not auto start and cannot be started After start TDAFW pump speed slows to idle speed 8 Restore feed water in FRP H.1 (CT-43)
Terminate on exit of FRP H.1 (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley October 2014 exam Page 2 of 10
Appendix D Scenario 5 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Load in IC-215 and sim IC snap directory 894 ppm Cb Base IC is IC-59 RUN 0 0 Generic setup:
bat generic_setup_HLT.txt 0 0 Quick setup (all items with
- are included):
bat ILT37_5.txt PRESETS 0 Tag 1A MDAFW pump
- irf cafp01a_d_cd1 open 0 Insert Initial Tube Leak in A SG
- Irf loa-rds001 7 5 4 Prevents selected BAT pump from working in AUTO
- Imf ccvp005a_cc2 open 5 Simulates back up seal oil regulator malfunction
- Set ctga26 = 117.0 5 Prevents Air Side DC seal oil pump auto start
- Imf cgs5085_cc10 open 7 Prevents auto closure of all MSIVs
- imf crsh001a_cc5 open imf cmsh002a_d_cc5 open imf crsh001b_cc5 open imf cmsh002b_d_cc5 open imf crsh001c_cc5 open imf cmsh002c_d_cc5 open 7 Prevent AUTO trip of main turbine
- MALF / T / MAL-TUR2 7 Prevent MANUAL trip of main turbine
- MALF / T / MAL-TUR24 7 Prevent start of B MDAFW Pump
- Imf cafp01b_d_cc18 open Triggers and Commands 7 Trigger 1 monitors for TDAFW Pump Start TRG 1 Trgset 1 x21o135o Trg 1 imf sic3405-o 4 20 Farley October 2014 exam Page 3 of 10
Scenario 5 Booth Operator Appendix D Form ES-D-1 Guide EXAM MCB setup Place Unit 1 Bypass and inoperable panel lights to the up position Unit 1 A-Train (Auxiliary Feed water System)
Place HOLD Tag on 1A MDAFW pump H/S 1 HOLD TAG DEH Clear DEH alarms Select OPS GROUP on MCB monitor IPC Acknowledge computer alarms IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Clear Recorders Cae clearrecorders.cae Provide a marked up copy of AOP-2.0 completed through AOP-2.0 copy step 16.1 ready to perform step 16.2 Place Simulator in Freeze Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:
Simview / sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW / Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE Farley October 2014 exam Page 4 of 10
Scenario 5 Booth Operator Appendix D Form ES-D-1 Guide EVENT# TIME EVENT DESCRIPTION COMMAND Prior to RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and then COLLECT to start collecting data Begin Exam RUN simulator Verify Horns ON: hornflag HORNS ON = TRUE 1 Start Adjust R-70 Setpoint of exam 2 NRC PT-476 Fails LOW CUE XMT / PT476 / 0 / 1 3 NRC CUE PK-444A fails LOW CNH / PK444A-D /10 / 1 4 NRC Air Side Seal Oil Pump Trips CUE CMFmalf / sGS5087A_cc3 / closed 5 NRC CUE Tube Leak increases to 160 GPD Remote / LOA-RDS001 / 160 / 300 6 NRC Selected BAT Pump will not AUTO Start during Pre-set CUE makeup or borations 7 NRC A loop spray valve drifts open in manual control CUE CNH / PK444C-M / 10 / 30 Reactor is tripped due to stuck open spray valve Farley October 2014 exam Page 5 of 10
Scenario 5 Booth Operator Appendix D Form ES-D-1 Guide Main Turbine will not trip automatically or manually.
GV closure is required (CT-13) 1B MDAFW will not auto start and cannot be started After start TDAFW pump speed slows to idle speed 8 Preset Restore feed water in FRP H.1 (CT-43)
Terminate on Exit of FRP-H.1 End of Exam HORNS OFF FREEZE simulator Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of Ensure data file exam2014sen5grpX.txt created.
NOTE: Substitute grpX with grp1, grp2, or grp3 as appropriate.
NOTE: file will be saved in the OPENSIM directory.
When Control board data no longer needed Then Clear recorders for exam security Farley October 2014 exam Page 6 of 10
Scenario 5 Booth Operator Appendix D Form ES-D-1 Guide Local operator actions:
EVENT NO. TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 NONE REQUIRED 4 NONE REQUIRED 5 NONE REQUIRED 6 NONE REQUIRED 7 NONE REQUIRED 8 NONE REQUIRED Install Jumpers Farley October 2014 exam Page 7 of 10
Scenario 5 Booth Operator Appendix D Form ES-D-1 Guide Communications sheet EVENT NO. TIME Communication:
ALL AS REQUIRED SSS, SM and Dispatcher:
(Standard Repeat back failure, procedure entered, plant status, CR in communications to the cue and that type of communications.
inform supervision) 1 WHEN REQUESTED SSS, SM:
Called to request a status tag for R-70A.
I will create a status tag for R-70A Chemistry:
Called to request samples Repeat back any request for sampling 2 NONE EXPECTED SM:
Called to request permission to return FRVs and SGFP speed control to AUTO.
You have permission to return FRVs and SGFP speed control to AUTO.
3 NONE EXPECTED 5 WHEN REQUESTED CHEMISTRY:
Called to perform sampling: Repeat back any request for sampling I will determine leak rate using CCP-31 I will perform grab samples and leak rate determination per CCP-201 and CCP-31 I will perform STP-746 Rad Side SO:
Called to complete securing SGBD per SOP-16.1. After 5 minutes report the following SGBD is secured.
Farley October 2014 exam Page 8 of 10
Scenario 5 Booth Operator Appendix D Form ES-D-1 Guide Communications sheet EVENT NO. TIME Communication:
4 IF REQUESTED Turbine SO:
Called to check air side seal oil pump and seal oil system:
After 3 Minutes report the following IF AIR SIDE DC SOP NOT RUNNING REPORT:
o Air side SOP has burnt acrid odor.
o Air side seal oil DP is reading 0 psid.
o It appears the backup seal oil regulator is partially open.
IF AIR SIDE DC SOP IS RUNNING REPORT:
o Air side SOP has burnt acrid odor o Air side seal oil DP is reading 12 psid.
TRUE = RUNNING, FALSE = NOT RUNNING 6 NONE EXPECTED 7 If Requested Rover:
Called to check on the 1B MDAFWP and TDAFWP:
After 3 minutes report the following:
1B MDAFWPs supply breaker is tripped TDAFWP operation appears normal but is running at reduced speed.
IF Directed to attempt to start the 1B MDAFWP and/or TDAFWP from the HSDP then after 3 min:
Go to HSDP and place 1B MDAFW in local (this should result in annunciator alarm).
Report that the 1B MDAFWP and TDAFWP failed to start from the HSDP.
Farley October 2014 exam Page 9 of 10
Scenario 5 Booth Operator Appendix D Form ES-D-1 Guide Communications sheet EVENT NO. TIME Communication:
8 IF REQUESTED SSS, SM:
Called to have jumpers installed per attachment 1 of FRP-H.1.
I will contact I & C for Jumper installation per attachment 1.
After 5 minutes report the following:
Jumpers have been installed per attachment 1 of FRP-H.1.
Called to have Make-up aligned to CST.
I will verify Make-up aligned to the CST Called to look at running TDAFW pump locally I will look at the procedures and make preparations for running the TDAFW pump locally.
Called to perform step 5.3 RNO of FRP-H.1 After 5 minutes PERFORM STEP 5.3 RNO on Simulator for the 1B MDAFW pump and Report:
I have attempted to perform step 5.3 RNO of FRP-H.1 and the 1B MDAFW pump will not Start.
ROVER:
Called to Investigate 1B MDAFW & TDAFW Pumps.
After 5 minutes report the following:
1B MDAFW pump breaker appears fine and the closing spring is charged.
1B MDAFW pump appears normal TDAFW pump appears normal except it is only running at 2000 RPM.
Turbine SO:
Called to align back-up cooling to the CNDS Pumps.
After 5 minutes report the following.
Back-up cooling has been aligned to the CNDS Pumps.
Farley October 2014 exam Page 10 of 10