ML043170136

From kanterella
Jump to navigation Jump to search
Draft - Section C Operating (Folder 2)
ML043170136
Person / Time
Site: Indian Point Entergy icon.png
Issue date: 10/22/2004
From: Christman R
Entergy Nuclear Indian Point 2, Entergy Nuclear Northeast
To: Conte R
NRC/RGN-I/DRS/OSB
Conte R
Shared Package
ML041450472 List:
References
ES-D-1, NUREG-1021, R09
Download: ML043170136 (57)
v • d • e


Text

Appendix D Scenario Outline Form ES-D-1 Facility: Indian Point 2 Scenario No.: NRC#1 Op-Test No.: 1 Examiners: Operators:

Initial Conditions: 3% Rated Thermal Power, MOL Turnover: Unit 2 is at 3% power, recovering from a 7 day forced outage to repair body to bonnet leak on PRZR Spray Loop 23 Bypass Valve 524. Shift orders are to continue the startup in accordance with Pop 1.3 Plant Startup, Mode 2 to Mode 1. The previous shift completed POP 1.3 though step 4.23. Operations Manager has directed you to baseload the HP Steam Dumps to approximately 8% prior to placing the unit on line per POP-2.1. The Operations Manager, Reactor Engineering and Power Marketing have authorized a rate of power increase of 200 MWe per hour to 100% RTP.

Event Event Type* Description N Raise reactor power SRO/BOP R

RO 2 XMT- I Pressurizer Level Channel 2 (LT-460) Fails Low (TS RCS020A ALL SRO)

C 22 SG Tube Leak (5 gpm) (TS SRO)

RCSO14B ALL C 23 RCP High Vibration RCP007C SRO/BOP 5 MAL- 21 Main Boiler Feed Pump Trip (Manual reactor trip ATS007A 6 MAL- M SGTR RCSO14B ALL with subsequent MAL-EPS001 I ~ o s of s Offsite Power 7 MOC-SIS001 r- I 21 SI Pump Fails to Auto Start

  • (N)ormal (R)eac ity, (I)nstrument, (C)omponent, (M)ajor NUREG-1021, Draft Revision 9 1 of 19

Simulator Setup Reset to IC-124 Validation time = 105 minutes.

Execute batch file Bat "NRC#l .bat" from Ph.D Expert window:

A MOC-SIS001 SI1 SAFETY INJECTION PUMP 21 MOTOR IMF MOC-SISOO1 (-1 0) 4 XMT-RCS020A FIXED OUTPUT: LT-460 PZR LEVEL CH.2 IMF XMT-RCS020A (1 0) 0.000000 0 40.412601 A MAL-RCS014B STEAM GENERATOR 22 TUBE LEAK (NR)

IMF MAL-RCS014B (2 0) 0.050000 0 0.000000 A MAL-RCP007C RCP 23 HIGH VIBRATION IMF MAL-RCP007C (3 0) 10.000000 7200 4.000000 A MAL-ATS007A MBFP 21 THRUST BEARING FAILURE (NR)

IMF MAL-ATS007A (4 0) TRUE A Loss of Offsite Power when manual SI pushed TRGSET 29 "xaoi610a.eq.l" TRG 29 "IMF MAL-EPS001 (-1 0) TRUE" A SGTR 22 SG gets big when reactor trips TRGSET 30 "JBKRTA.EQ.0" TRG 30 "IMFMAL-RCS014B (-1 0) 5.00000 0 0.050000" Verifv that the following commands amear in the Instructor Station Summarv:

$,I.

?? -1111 X I Desapboo Delay Romp Event Value Fnal InserlTime 030000 OOCOOO hone n:a 3u-c 5 ooonoo

-RCSOZoH FlrED O U T P U LT-460 PZ 000000 000000 1 47 6603 0 000000 RCSOl4B STEAM GENERATOR 22 TUBE LEAK 000000 000000 2 0 005 OD0000 RCW0iC RCP22 H1i;HVlBRATION oooooo 020000 3 0 10 ~1~l0000 ATS007A MBFP 21 THRUST BEARING FAILUF? 000000 000000 4 FALSE FALSE 00 0000 I

2of19

Simulator SetuD Verify that Conditional Trigger 29 & 30 appears on Event Trigger 29 and 30 as follows:

""I f a kj,,

Event# Event Action 130 I

JBKRTA.EQ.0 TI1

i: .: -lolxl Event# Event Action I
  1. Action 1-1 Finish 1 16 Available 17 Available 18 Available 19 Available 20 Available 21 Available 22 Available 23 Available 24 Available 25 Available 26 Available 27 Available 28 Available 1

TRUE FALSE 3of 19

Appendix D Required Operator Actions Form ES-D-2 Prior to start of scenario, brief team on power escalation orders. Allow them to formulate a reactivity plan and do their brief outside the simulator. Provide them required graphs and NUPOP, and turnover sheet.

Op-Test No.: 1 Scenario No.: 1 Event No.: 1 Page 1 of 1 Event

Description:

Raise Reactor Power from 3% reactor power Time Position SRO Directs activities associated with power increase per 2-POP-1.3, Plant Startup, Mode 2 to Mode 1:

- Rod Motion

- Dilution RO Adds Positive reactivity

- Rod Motion

- Dilution SRO Directs activities associated with shifting Feedwater from Auxiliary Feedwater Pumps to Main Feedwater Pumps BOP Shifts Feedwater from Auxiliary Feedwater Pumps to Main Feedwater Pumps per 2-SOP-21.1 Main Feedwater System.

- Checks operation of main feed and bypass feed flow control valves

- Shifts Feedwater control from AFW pumps to Main Feedwater System

- Control SG levels on main Feedwater bypass flow control valves

- Align AFW pumps and flow control valves for automatic operation per 2-SOP-21.3 Auxiliary Feedwater Operation SRO Initiates Turbine Generator startup operations per 2-SOP-26.4, Turbine Generator Startup, Synchronizing, Voltage Control and Shutdown SIMULATOR 0PERATOR:

Activate trigger 1 to start the next event Pressurizer Level Channel 2 (LT-460) Fails Low (TS SRO) when directed by the Lead Evaluator.

4of19 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 2 Page1 o f 3 Event

Description:

Pressurizer Level Channel 2 (LT-460) Fails Low Time Position Applicants Actions or Behavior P -

RO Diagnose Pressurizer Level Channel 2 failed low BOP Refers to Alarm response Procedure

- SAF 3-3 Pressurizer Low Level 18% 5%

- SAF 4-3 Pressurizer Lo Lo Level Channel Trip 5%

- SGF 2-9 RCS Reduced Inventory

- SFF 1-7 PRZR Heater Group Tripped SRO Directs RO to perform immediate operator actions (from memory) of 2-AOP-INST-1, Instrument/Controller Malfunctions RO Places 22 Charging Pump speed controller in manual and adjusts charging flow as necessary to maintain Pressurizer Level on program (per Graph RCS-2, Pressurizer Level vs. Tave)

SRO Directs actions to select operable channels for control and alarm BOP Defeats controlling PRZR Level Channel by placing U460A (Pressurizer Level Defeat Transfer Switch) in DEFEAT CH2 (located in Foxboro rack B-6)

SRO Directs initiation of actions to restore letdown using SOP-3.1, Charging Seal Water and Letdown Control RO Restores letdown:

- Verifies a charging pump is in service

- Verifies HCV-142, Charging Line Flow Controller is throttled open

- Verifies Charging flow established with 204A 22 Hot Leg Alternate Charging Stop is OPEN

- Verifies letdown orifice stops CLOSED (200 A, B, C)

- Verifies that switch Letdown Flow Control Valves ABC in REMOTE

- Verifies Letdown Line Isolation Stops 200A and 2008 are OPEN 50f 19 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Event

Description:

Pressurizer Level Channel 2 (LT-460) Fails Low Position Amlieants Actions or Behavior RO Restores letdown (continued):

- OPENS LCV 459 Letdown Stop and places control switch to AUTO

- Places PCV-135, Low Pressure Letdown Line Controller to manual and adjusts to 50%

- OPENS desired letdown orifice stop to obtain desired letdown flow (200A or 200C excepted to obtain 75 gpm letdown flow)

- ADJUSTS PCV-135 to maintain 225-275 psig Letdown Pressure

- Return PCV-135 to AUTO SRO Direct actions to restore backup heaters to pre-failure configuration (21 AUTO, 22 and 23 ON) (or as desired by SRO)

RO Reset PRZR Backup heaters by taking control switches for each group (21, 22, and 23) to OFF and then returning to AUTO or ON as directed by SRO SRO Direct actions to reset modulating heaters RO Resets Modulating Heaters:

- Place Modulating Heaters control switch in TRIP and then back to neutral.

- Place control switch in CLOSE and then back to neutral SRO Direct actions to place 22 Charging Pump in AUTO (if desired) 6of19 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 2 Page3 o f 3 Event

Description:

Pressurizer Level Channel 2 (LT-460) Fails Low

-Time -Position RO Places 22 Charging Pump to AUTO:

- Place speed control to MAN-BAL

- Adjust bias knob until deviation meter indicates zero

- Place speed controller to AUTO

- Slowly return bias knob to zero

- Verify RCP Seal Injection Flow 6-12 GPM

- Monitor automatic Przr level control per Graph RCS-2, Pressurizer Level vs Tave SRO Refer to Technical Specification 3.3 Instrumentation and Table 3.3.1-1 Reactor Protection System Instrumentation for required actions:

- Determine that TS 3.3.1 Condition A applies

- Determine from table 3.3.1 -1 function 8 directs that Condition K applies

- Determine form TS 3.3.1 Condition K that the bistable must be placed in trip within 72 SRO Direct actions to trip bistable LC-460A (LOOP 2) Hi Level Trip in the White Foxboro Rack A-12 CUE: IF the SM is asked if Bistables should be tripped, direct the team to trip the appropriate bistables.

BOP Place bistable LC-460A (LOOP 2) Hi Level Trip in the White Foxboro Rack A-12 to TRIP SIMULATOR OPERATOR:

Activate Trigger 2 to start the next event (22 SG Tube Leak) when directed by the lead evaluator. (Wait until PRZR level is stable from previous event, else team will have to wait in AOP-SG-1 to determine leak rate) 7of19 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 3p-Test No.: 1 Scenario No.: 1 Event No.: 3 Page 1 of 3 Event

Description:

22 SG Tube Leak (5 GPM)

Time Position Applicants Actions or Behavior BOP Acknowledge alarms and perform ARPs

- SA-1 (3-7) R49 Steam Generator Blowdown Hi RadRrouble (WARN SETPOINT(after about 1 minute))

- SA-1 (3-9) R-45 Air Ejector Radiogas Hi RadRrouble (after about 6 minutes)

TEAM Diagnose steam generator tube leak SRO Enter 2-AOP-SG-1, Steam Generator Tube Leak SRO/RO Verify that Pressurizer level is being maintained by charging flow:

- Checks PRZR level able to be maintained with two charging pumps

- Checks PRZR level > 11%

- Checks RCS Pressure and Subcooling SRO Directs RO to evaluate plant conditions for indication of Gross TubeLeakage EVALUATOR NOTE: The team will not have clear indication of Gross Tube Leakage at this point.

TEAM Initiate determination of affected SG. Checks:

- N-16 Monitor

- Steam Line surveys

- Chemistry results BOOTH OPERATOWCOMMUNICATOR: When chemistry or the NPO are contacted, report back that 22 SG is affected.

RO/BOP Check R-45 operable 8of19 NUREG-1021, Draft Revision 9

_______~

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 3 Page2 of 3 Event

Description:

22 SG Tube Leak (5 GPM)

~

Time Position BOP Initiate attachment 1, R-45 Estimated Leak Rate NOTE: If chemistry is requested, provide the following information:

- Condenser air in leakage = 6 SCFM

- RCS total gaseous activity = 2.5 e-3 uCi/cc BOP Calculates leak rate of approximately 5 gpm SRO Directs Chemistry to perform Primary to Secondary Leak Rate determination BOOTH OPERATOWCOMMUNICATOR: After about 10 minutes, report that Pri to Sec leakrate is 4.3 GPM SRO Notify Health Physics of SGTL

~~

BOP Initiate Attachment 2, SG Leak Rate Data Sheet TEAM Determine primary to secondary leak rate using

- N-16

- Chemistry grab sample results

- Attachment 1 EVALUATOR NOTE: N-16 data is not vz id )elow 30% power.

Team should use Chemistry results and Attachment 1 calculation to determine that leak rate is 3-5 gpm SRO Determine that leak rate is >lo0 gpd SRO Direct chemistry to draw backup samples and re-perform Primary to Secondary Leak Rate calculation.

BOOTH OPERATOWCOMMUNICATOR: When Chemistry is contacted, report that additional samples have been obtained and that the leak rate has been verified at 4.3 gpm 9of 19 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 3 Page3 of 3 Event

Description:

22 SG Tube Leak (5 GPM) t Time Position - Applicants Actions or Behavior P -

Initiate notifications per SAO-124, Oral Reporting of Non-Emergency Events and Items of Interest and Significant Occurrence Reporting SRO Direct Chemistry to calculate leak rate every 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> while shutting down SRO Evaluate attachment 3 and Technical Specification 3.4.13 to determine Shutdown Requirements:

- TS 3.4.1 3 Condition A - reduce leak rate to allowable in 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> (cannot be met)

- Be in mode 3 in additional 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />

- Be in mode 5 in additional 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> Initiate plant shutdown IAW POP-3.1, Plant Shutdown Mode 1 to Mode 3.

SIMULATOR 0PERATOR:

Activate Trigger 3 when directed by the Lead Evaluator to proceed to the next event (23 RCP High Vibration) 10 of 19 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 4 Page 1 of 1 Event

Description:

23 RCP High Vibration x_I P

Time Position Applicants Actions or Behavior

___I BOP Acknowledge alarm and perform ARP:

- SF 4-6 23 RCP HI Vibration SRO Enter 2-AOP-RCP-1, Reactor Coolant Pump Malfunction TEAM Determine immediate reactor trip and RCP trip NOT required:

- Checks Stator winding temp 2 250°F AND Tave 2 547°F

- Stator winding temp 2 270°F AND Tave < 547°F.

- RCS seal 1 AP < 200 psig.

- Sustained RCP vibration > 20 mils

- RCP motor bearing temp 2 200°F

- #1 Seal inlet temp 2 225°F BOP Initiate data collection per Attachment 1, RCP Data Sheet SRO Notify Plant Engineering BOP Check vibration e13 mils (no)

BOP Check vibration spiking (no)

BOP Check vibration trend increasing < 1 mil/hr (no)

Note: Vibration trend is increasing at a rate of 3 mils/hr SRO Continue plant shutdown per POP-3.1 SIMULATOR OPERATOR:

Activate trigger 4 when directed by Lead Evaluator to proceed to the next event (21 MBFP trips) 11 of 19 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No,: 1 Scenario No.: 1 Event No.: 5 Page 1 of 1 Event

Description:

21 Main Boiler Feed Pump Trips

-Time -Position -

Applicants Actions or Behavior P RO Diagnose trip of 21 Main Boiler Feed Pump SRO Diagnose Loss of Feedwater:

- Direct RO to perform immediate operator actions of 2-AOP-FW-1 Loss of Main Feedwater RO Performed from memory:

- Checks any Main Boiler Feed Pump operating (no)

- Checks Reactor power greater than 4% (yes)

- Manually trip the reactor SRO Directs team to perform immediate operator actions of EOP E-0, Reactor Trip or Safety Injection NOTE:

1. The SGTL will increase in size to a SG Tube Rupture (600 gpm) when the reactor is tripped (from conditional trigger 30 which actuates from condition of reactor trip breakers open)
2. A loss of offsite power will occur when SI is manually actuated (from conditional trigger 29 which actuates from condition of manual SI buttons pushed) 12 of 19 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 6 Page 1 of 5 Event

Description:

Steam Generator Tube Rupture with subsequent Loss of Offsite Power Time P

Position Amlicants Actions or Behavior SRO Direct Operators to perform immediate operator actions of EOP-E-0, Reactor Trip or Safety Injection RO Verifies Reactor Trip (from memory)

RO Verifies Turbine Trip (from memory)

~~

BOP Checks status of 480V ac buses (from memory)

NOTE: Following SI actuation, offsite power will be lost and all 480V buses will be powered from the EDGs RO Checks status of SI: (from memory)

- Determines pressurizer pressure and level are lowering

- Manually actuates SI

- Checks both trains of SI actuated EVALUATOR NOTE: The team may go to ES-0.1 and then manually actuate SI from the foldout. Also, the team may use AOP-SG-1 IAAT step 4.1 to actuate SI.

TEAM Perform immediate actions steps again (using the procedure)

SRO Directs BOP to perform E - 0 Attachment 1, Automatic Action Verification EVALUATOR NOTE: See required operator actions for event 7 for BOP E-0 Attachment 1, Automatic Action Verification RO Verify AFW Pumps Running RO Verify total AFW flow > 400 GPM

- - P 13 of 19 NUREG-1021 Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 6 Page2 of 5 Event

Description:

Steam Generator Tube Rupture with subsequent Loss of Offsite Power

~~

Time

__j Position Amlicants Actions or Behavior RO Verify SI System Flow

- Checks RCS Pressure c 1160 psig (no)

- Places one RHR pump in pullout RO Check RCP Seal Cooling

- Dispatch an NPO to align backup cooling to the Charging Pumps, RHR pumps, and SI pumps

- Dispatch an NPO to locally close SWN-4 and SWN-5 in the zurn strainer pit RO Check cold leg temperatures stable at or trending to 547°F RO Check PRZR Porvs and Spray Valves Closed RO Check RCPS stopped (yes- loss of offsite power)

RO Check if any SG is faulted (no)

RO Check if SG tubes are intact (no, 22 SG is Ruptured)

- Main Steam Line radiation recorder

- Condenser air ejector radiation recorder

- SG Blow down radiation recorder

- No SG Level increasing in an uncontrolled manner SRO Transitions to EOP E-3, Steam Generator Tube Rupture 14of 19 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 6 Event

Description:

Steam Generator Tube Rupture with subsequent Loss of Offsite SRO Determine required core exit temperature:

NOTE: 510°F expected with 22 SG pressure > 1025 PSlG 15of 19 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 6 Page4 of 5 Event

Description:

Steam Generator Tube Rupture with subsequent Loss of Offsite Power Time Position Applicant's Actions or Behavior BOP Check Intact SG Levels

- Maintain total feed flow > 400 gpm until narrow range level > l o % in at least one SG RO Check PORVs and Block Valves BOP Reset SI and CI Phase A BOP Check RCS pressure greater than 320 PSlG and then stop RHR pumps and place in AUTO RO Establish maximum charging flow RO Check 22 SG pressure stable or increasing RO Check RCS subcooling > value from table (>39"F expected)

RO Depressurize RCS using PORV

- Opens one PORV

- Monitors RCS Pressure, 22 SG Pressure, PRZR Level, and RCS subcooling

- Closes PORV when RCS pressure < 22 SG Pressure, o PRZR Level > 71%, or subcooling < value from table RO Checks RCS pressure increasing TEAM Checks if SI flow can be terminated

- Checks subcooling greater than value from table

- AFW flow > 400 GPM

- RCS Pressure stable or increasing

- PRZR Level > 14%

160f 19 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 I Op-Test No.: 1 Scenario No.: 1 Event No.: 6 Page4 o f 5 I Event

Description:

Steam Generator Tube Rupture with subsequent Loss of Offsite Power TEAM Verify SI system flow not required

- Checks Subcooling greater than value from table

- PRZR Level > 14%

EVALUATOR NOTE:

Terminate scenario after SI dumps stopped, or at the discretion ot the lead evaluator.

17of 19 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 7 Page 1 of 1 Event

Description:

21 SI Pump Fails to Auto Start (E-0, Attachment 1 Automatic Action Verification)

Time I Position A p I Verify charging system operation

- Starts one charging pump in manual at maximum speed

- Align charging system to the RWST (opens LCV-l12B, Closes LC-l12C, place Makeup Control Switch to STOP)

Check 345 KV MO Disc Switch F7-9 Open

- verifes BKR 7 and 9 open BOP Check status of 480 V buses

- Determines all are powered from EDGs

- Direct personnel to align lighting to TSC bus 1 BOP Verify FW Isolation I BOP Check if MSlVs should be isolated BOP Check SW system operation I

Check Three SI Pumps running

- Manually starts 21 SI pump

- OPEN851B

- Check RHR pumps running Check SI system valve aligment I I I

I BOP BOP BOP Verify Containment Fan Coolers in service Verify AFW Flow to all SGs NOTE: The team may use prudent operator action to isolate AFW flow to 22 SG when NR Level is > 10%

Verify Containment Ventilation Isolation Verify Containment Isolation Phase A Check if CS should be actuated Verify CCR Air Conditioner status

~~

I BOP Notify SRO Attachment 1 complete 18 of 19 NUREG-1021, Draft Revision 9

Shift Turnover Watch Team Turnover Sheet:

Datemime: TODAY Condition: Power Ops RCS Temp: 549 O F  % Power: 3%

RCS Press: 2235 psig MW Gross: 0 PZR Level: 38 % River Water: 63 O F RCS Total Leakage: 0.1 gpm Boron Conc: 1530 ppm RCS Unidentified 0.1 gpm Control Rods 105 CBD Leakage:

Xenon: Increasing Condenser Air leakage 6 SCFM EFPD: 30 RCS Gas activity 2.5E-3 pCi/cc PZR Press Control: Channel 1 PZR Level Control: Channel 2 Service Water: 3 Header Ops Risk Assessment: Green Daily Risk Factor: 0.78 Plant Equipment Status :

No equipment out of service Instructions to the Shift:

Continue plant startup IAW POP-1.3. Unit 2 is at 3% power, recovering from a 7 day forced outage to repair body to bonnet leak on PRZR Spray Loop 23 Bypass Valve 524. Shift orders are to continue the startup in accordance with Pop 1.3 Plant Startup, Mode 2 to Mode 1. The previous shift completed POP 1.3 though step 4.23.

Operations Manager has directed you to baseload the HP Steam Dumps to approximately 8%

prior to placing the unit on line per POP-2.1 The Operations Manager, Reactor Engineering and Power Marketing have authorized a rate of power increase of 200 MWe per hour to 100% RTP.

Page 19 of 19

Appendix D Scenario Outline Form ES-D-1 Facility: Indian Point 2 Scenario No.: NRC#2 Op-Test No.: 1 Examiners: Operators:

Initial Conditions: 100% Rated Thermal Power, MOL. 21 EDG is out of Service. 22 Charging Pump is out of service.

Turnover: Unit 2 is at 100% Power steady state conditions 340 EFPD. 21 EDG is out of service and has been inoperable for 42 hours4.861111e-4 days <br />0.0117 hours <br />6.944444e-5 weeks <br />1.5981e-5 months <br />. Maintenance is currently performing repairs.

In addition, 22 Charging Pump was removed from service for corrective maintenance 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> ago. Expected return to service in 35 hours4.050926e-4 days <br />0.00972 hours <br />5.787037e-5 weeks <br />1.33175e-5 months <br />.

Event Malf. No. Event Event No. ~ Type* Description 1 RLY- N 23 EDG inoperable due to 86 Lockout Relay tripped DSGOOS BOP/S RO Begin TS required plant shutdown R

RO 2 MAL- C Loss of Bus 6A (Lose 23 CHG Pump, Starts 21 CHG EPS007D ALL Pump) 3 MOT- C 21 Charging Pump Trips CVC003A ALL Manual Reactor Trip 4 MAL- M Loss of all AC EPS001 ALL Station Aux Xfmr fails MAL- 22 EDG fails to start DSG003B 5 MOC- C 25 SW Pump Fails to auto start following start of 22 swso10 SRO/BOP EDG and energizing associated 480V buses MOC-sws-011

' (N)ormal (R)eac: (I)nstrument, (C)omponent, (M)ajor 1 of 13

Simulator Setup

1. Execute batch file Bat "NRC2.bat from Ph.D Expert window:

A LOA-DSG055 DSG-NT-89 DG-21 MANUAL-OFF-AUTO (ECS)

IRF LOA-DSG055 (-1 0) OFF A LOA-DSG032 DSG-NT-110 BKR 52/EG1 RACK-OUT/RACK-IN IRF LOA-DSG032 (-1 0) OUT A LOA-EPSO10 52-C1 C 21 480V BKR RACK OUT/ RACK IN IRF LOA-EPS010 (-1 0) OUT A MOC-SWSO10 SW5-2A SW PUMP MOTOR 25 480V BUS 2A IMF MOC-SWS010 (-1 0) 4 A MOC-SWSOll SW5-3A SW PUMP MOTOR 25 480V BUS NO. 3A IMF MOC-SWSO11 (-1 0) 4 A MAL-DSG003B DG 22 AIR START FAILURE IMF MAL-DSG003B (-1 0) TRUE A RLY-DSGOOS RELAY FAILURES: 86-DG23 DG23 LOCKOUT RELAY IMF RLY-DSGOO9 (1 0) 3 A MAL-EPSOO7D 480V BUS 6A FAULT IMF MAL-EPS007D (2 0) TRUE A MOT-CVC003A C1 CHARGING PMP 21 MOTOR IMF MOT-CVC003A (3 0) 3 A MOV 625 fails closed after 204 closed TRGSET 30 "xcoi213o.eq.O" TRG 30 "IMF MOV-CCW008 (-1 0) 2 'I A Loss of Statin Aux Transforem 60 seconds after RX Trip TRGSET 29 "jbkrta.eq.0" TRG 29 "IMF MAL-EPS001 (-1 60) TRUE"

2. Place CS for 21 EDG in Pullout
3. Place 23 Charging pump in auto operation.
4. Place CS for 22 Charging Pump in Pullout
5. Verify that standard PlCs screens are displayed (no screens that could cue the team to upcoming events) 2of 13

Simulator Setup Validation time 105 minutes Verify the following commands appear in the instructor station summary:

GC-5WSU11 5% ?A S W W'dPMCTOR 25 46 110IJII 00 00 00 0 0 INone nia Pllt CIS on 110 (10 AL-DSGOEB DG ZZARSTAGTFALURE 000000 000000 None FALSE FALSE ooooon LY-DSG309 RELAY F4ILCIRES 85 DG?3 DG ooo3no nnnoon 1 n h i?natgi?e 000000 X-EPSUUiD 400'~BUS 6A FAUL- onndun oooooo i FALSE FALSE co uo no OT-CVCOC?A i l CI-WRGII'JG FMP21 MG nnnnoo oooooo 3 nia mding short 00 00 00 Tuggers TRUE FALSE 3 o f 13

Simulator Setup Verify that conditional trigger 29 and 30 appear as follows:

20 Available 21 Available 22 Available 23 Available 24 Available 25 Available 26 Available 27 Available IJ U I

xcoi213o.eq 0 71 2

TRUE FALSE 19 Available 20 Available 21 Available 22 Available 23 Available 24 Available 25 Available 26 Available 27 Available 28 Available

. ....... . ~

T . I d

TRUE FALSE 4of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 1 Page5 of 2 Event

Description:

23 EDG becomes Inoperable due to 86 Lockout Tripped. Begin TS required plant shutdown SIMULATOR OPERATOR:

Activate Trigger 1 to insert the 23 EDG 86 Relay Trip when directed by the lead evaluator Time P Position BOP Acknowledge alarm and perform Alarm Response Procedure:

- SG 4-9 23 Diesel Generator Trouble

- Dispatch NPO to 23 EDG

- Refer to SOP 27.3.1.3 23 Emergency Diesel Generator Manual Operation SIMULATOR OPERATOWCOMMUNICATOR:

After dispatched, NPO reports back to CCR that 23 EDG 86 lockout has tripped.

SRO/BOP Direct NPO to attempt to clear trouble and VERIFY that lockout relay is RESET SIMULATOR OPERATOWCOMMUNICATOR:

NPO reports back to CCR that 23 EDG 86 Lockout relay will NOT reset.

SRO Refers to Technical Specification 3.8.1 Condition E

- Two or more EDGs inoperable

- Action Statement E.l Restore at least two EDGs to operable status within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />

- Determines that plant shutdown must be commenced per action statement F.1, 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 /> SIMULATOR 0PERAT0 WCOMMUNlCAT0R:

Maintenance reports that 21 and 23 EDG cannot be returned to service within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. The 86 tripped and will not reset. It appears that the relay itself must be replaced.

Note: If the team does not begin the SD right away, then the Operations Manger directs the team to commence shutdown immediately.

SRO Directs plant shutdown per POP-3.1, Plant Shutdown, Mode 1 to Mode 3 5 o f 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 1 Page2 o f 2 Event

Description:

23 EDG becomes Inoperable due to 86 Lockout Tripped. Begin TS required plant shutdown Time Position Applicants Actions or Behavior P

RO Adds negative reactivity:

- Boration

- Control rod insertion

- Maintains Delta-flux within the target band BOP Lowers turbine load using Turbine Governor (or LLl/LL2 if directed)

SIMULATOR OPERATOR:

Activate Trigger 2 to insert the Loss of Bus 6A when directed by the lead evaluator 6of 13

Amendix D Reauired ODerator Actions Form ES-D-2 Event

Description:

Loss of Bus 6A (Lose 23 Charging Pump)

Position A p p l l c a n t ' s o n s or Behavior -

BOP Diagnose loss of Bus 6A. Acknowledge multiple alarms:

- SH 3-10 480V Swgr Motor Trip (Common)

- SH 4-10 480V Bus Main Tie or Emerg Gen Breaker Trip

- SG 4-6 Switch Gear 21 or 22 Undervoltage

- Additional alarms associated with loss of 26 SWP, 23 Charging Pump, 22 Rod Drive MG, 25 FCU, Process Radiation Monitors, 22 PW Pump, 22 BA Xfer Pump SRO Enters 2-AOP-480V-1, Loss of Normal Power to Any 480V Bus and directs team actions RO Starts 21 Charging Pump BOP Checks one CCW pump running (yes)

Checks OPEN MOV-625 RCP Thermal Barrier Discharge Is01Vlv (Yes)

Checks SW pumps running on essential and non-essential headers (yes)

RO Starts 21 PW Pump SRO Dispatches NPO to monitor all running EDGs NOTE: 22 EDG fails to start. NPO is unable to start it if directed to. 21 and 23 EDGs are inoperable. TS 3.8.1 Condition E still applies for two or more EDGs inoperable. NPO report 22 EDG OVERCRANK Alarm is annunciated.

7 o f 13

Amendix D Reauired OPerator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 2 Page2 o f 2 Event

Description:

Loss of Bus 6A (Lose 23 Charging Pump)

I Time Position Applicants Actions or Behavior BOP Performs Attachment 3 Restoring Normal Power to 480V Bus 6A:

- Dispatch NPO to start 23 EDG

- Notifies SRO that 23 EDG cannot be started

- Diagnoses fault on bus 6A (observes 6A fault lamp extinguished)

- Dispatch NPO to open bus 6A MCC breakers and perform visual inspection of Bus 6A

- Places Control Switches for Bus 6A loads to pullout:

SIMULATOR OPERATOWCOMMUNICATOR:

Report that the back of Bus 6A switchgear appears damaged and smells burned.

SRO Refer to attachment 5 480V Bus Equipment for loads lost and perform a review of Technical Specifications for required actions

- Refers to TS 3.8.9 Condition A SIMULATOR OPERATOR:

Activate Trigger 3 to insert Trip of 21 Charging Pump when directed by the lead evaluator 8of 13

Amendix D Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 3 Page9 o f 4 Event

Description:

21 Charging Pump Trips (Loss of all charging)

~ ~ _ ~~~ _ ~

Time Position Amlicants Actions or Behavior RO Diagnose trip of 21 Charging Pump SRO Enter 2-AOP-CVCS-1, Chemical and Volume Control System Malfunction and Directs operator actions RO Closes the following valves

- 200A Letdown Orifice 75 GPM

- 2008 Letdown Orifice 45 GPM

- 200C Letdown Orifice 75 GPM

- LCV-459 Letdown Stop BOP Closes 204A Alternate Charging 22 Hot Leg NOTE: MOV-625 should close at this time BOP Observe MOV-625 RCP Thermal Barrier Disc CLOSED

- Place control switch for MOV-625 in OPEN positon

- Determine MOV 625 does not open SRO Directs team to

- Trip Reactor

- Stop all RCPs

- Goto E-0 RO 4ctuates manual reactor trip BOP Stops all RCPs SRO 3irects team to perform immediate actions of E-0 9of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 4 Page2 of 4 Event

Description:

Loss of All AC Power NOTE: Loss of all AC occurs 60 seconds after reactor is tripped Position Applicants Actions or Behavior Directs team actions in EOPs RO Verifies Reactor Trip Verifies Turbine Trip BOP Checks status of AC Buses

- Determines that no AC bus is energized SRO Enters EOP ECA-0.0 Loss of All AC Power

- Directs team to perform ECA-0.0 immediate actions RO Verifies Reactor Trip Verifies Turbine Trip RO Verifies RCS isolated. Observes the following valves CLOSED:

- PRZRPORVS,

- LCV-459, Letdown Stop

- 200A, B, C, Letdown Isolation valves

- 213, Excess letdown isolation Establish at least 400 gpm AFW flow to the SGs before SG dry-out occurs (WR level less than 14%)

4lign AFW to SGs using 22 Turbine Drive AFW Pump

- Checks Open PCV-1139, steam supply regulator

- Manually aligns TD AFW Flow Control Valves

- Adjust HCV-1118, steam supply

- Observes > 400 GPM flow 10 of 13

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 4 Page3 o f 4 Event

Description:

Loss of All AC Power Position Applicants Actions or Behavior P TEAM Attempt to restore Power to any 480V Bus Dispatch NPO to emergency start EDGs SIMULATOR OPERATOR:

NPO is initially unsuccessful at starting an EDG BOP Performs 2-AOP-138KV-1, Loss of Power to 6.9KV Bus 5 AND/OR 6 SIMULATOR OPERATOR :

CONED DO provides permission use Feeder 13W92. However, 22EDG will be started by NPO BEFORE bus 5A is restored.

RO Places Control Switches- in Pull-Out:

- CSPumps

- SI Pumps

- FCUS

- MDAFWPumps

- Turning Gear Oil Pump

- Bearing Oil Pump

- Turb Aux Oil Pump

- CCWPumps

- RHRPumps SRO Dispatch personnel to locally restore AC power SIMULATOR OPERATORKOMMUNICATOR:

After this step is performed, report back to CCR that 22 EDG is ready to start. When permission is given to start 22 EDG, then delete the air start malfunction MAL-DSG003B and execute batch file bat EDG22-1.bat to reset and start 22 EDG ReDort back immediatelv after 22 EDG starts.

11 Of 13

Appendix D Required Operator Actions Form ES-0-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 4 Page4 o f 4 Event

Description:

Loss of All AC Power Time Position TEAM Verify equipment loaded onto energized bus:

- MCC24

- MCC24A

- 22 Battery Charger

- 22 Static Inverter on alternate power

- PA system inverter

- MCC26C

- MCC211

- 23 Battery Charger SRO Selects Recovery Procedure based upon conditions

- ECA-0.1, Loss of All AC Power Recovery Without SI Required (expected)

- ECA-0.2, Loss of All AC Power Recovery With SI Required (if RCP seals degrade)

NOTE:

Terminate the scenario when the transition from ECA-0.0 is made, or at the discretion of the lead examiner.

12 of 13

Shift Turnover Watch Team Turnover Sheet:

Datemime: TODAY Condition: Power Ops RCS Temp: 562 O F  % Power: 100%

RCS Press: 2235 psig MW Gross: 1017 PZR Level: 48 % River Water: 78 O F RCS Total Leakage: 0.1 gpm Boron Conc: 972 ppm RCS Unidentified 0.1 gpm Control Rods 214 CBD Leakage:

Xenon: Equilibrium Condenser Air leakage 6 SCFM EFPD: 340 RCS Gas activity 2.54e-2 pCi/cc PZR Press Control: Channel 1 PZR Level Control: Channel 2 Service Water: 3 Header Ops Risk Assessment: Yellow Daily Risk Factor: 3.45 Plant Equipment Status:

1. EDG 21 is out of service for bearing replacement. It was removed from service 42 hours4.861111e-4 days <br />0.0117 hours <br />6.944444e-5 weeks <br />1.5981e-5 months <br /> ago and is due back in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. Maintenance is currently performing repairs. TS 3.8.1.B surveillance (2ptw19) requirement last performed 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> ago.
2. 21 and 22 EDGs are protected equipment.
3. 22 Charging Pump was removed from service for corrective maintenance 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> ago.

Expected return to service in 35 hours4.050926e-4 days <br />0.00972 hours <br />5.787037e-5 weeks <br />1.33175e-5 months <br />.

Instructions to the Shift:

Maintain current plant conditions.

Page 13 of 13

Appendix D Scenario Outline Form ES-D-1 Facility: Indian Point 2 Scenario No.: NRC#3 Op-Test No.: 1 Examiners: Operators:

Initial Conditions: 40% Rated Thermal Power, MOL Turnover: Unit 2 is at 38% Power with power ascension to 100% in progress following a forced outage. No equipment 00s.

Event Event No. Description 1 Raise reactor power 2 MAL- C Stuck Control Rod (P-IO)

CRF001AY ALL 3 XMT- I LT 4478 24 SG Controlling Level Channel fails low.

SG N026A RO/SRO 4 MAL- C RCP Upper Bearing Oil Cooler CCW leak CCWOO1D BOP/SRO 5 MAL- M LBLOCA RCS001C ALL 6 RLY- C Safety Injection auto actuation failure, RO manually PPL487 RO actuates RLY-PPL488 7 MOC- C Both Recirculation Pumps both fail to start RHR001 ALL MOC-RHROO2 I

(N)ormal (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1 of 14

Simulator Setup Reset to IC-125 Execute batch file Bat "NRC3.bat from Ph.D Expert window:

A MAL-CRF001AY ROD: P10 STUCK ROD IMF MAL-CRF001AY (-1 0) 1 A RLY-PPL487 RELAY FAILURES: SIA-1 (A) SAFETY INJECTION AUTO MASTE IMF RLY-PPL487 (-1 0) 2 A RLY-PPL488 RELAY FAILURES: SIA-2 (6) SAFETY INJECTION AUTO MASTE IMF RLY-PPL488 (-1 0) 2 A MOC-RHR001 R1 RECIRC PUMP NO. 21 MOTOR IMFMOC-RHR001 (-1 0) 5 A MOC-RHR002 R2 RECIRC PUMP NO. 22 MOTOR IMF MOC-RHR002 (-1 0) 5 AXMT-SGNO26A FIXED OUTPUT: LT-4476 S/G 24 LEVEL IMF XMT-SGN026A (1 0) 0.000000 0 48.796101 A MAL-CCW001D RCP 24 OIL COOLER TUBE LEAK (NR)

IMF MAL-CCW001D (2 0) 1.OOOOOO 180 0.000000 A MAL-RCS001C RUPTURE LOOP C COLD LEG (NR)

IMF MAL-RCS001C (30 0) TRUE A Set Up trigger to actuate LBLOCA when Rx Trips TRGSET 30 "j bkrta.eq.0" Verify the following commands appear in the instructor station summary:

'T'FPILCIRES SIA-1 (A) S 4 oooooo OOOO~O None n/a aturk cnntactc 00 00 00

~'FAIltlfiEIS SIA-Z(F) SA nonnoo ononnn PJnn? nib durh contartc 'io no on RECIRC PUMP YO 21 000000 000000 None nla asis 000000 FiEClkCPUMP NO 2 asis UODOO0 IXED OUTPUT LT-4178 S,' 48 3509 0 OU 30 00 RCF 24 OIL COOLER TUBE LEAK UPTl.IRE LOOP C COL@LEG FPLS E FPLSE 000000 I

I TRUE 1

FALSE 2of 14

Simulator Setup Verify that conditional trigger 30 appears as follows giy.r -

, P i I Ih, I._, n*

Event# Event Action i

3of 14

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 1 Page1 of 1 Event

Description:

Raise reactor power Time Position Applicants Actions or Behavior -

SRO Directs activities associated with power increase per 2-POP-1.3, Plant Startup, Mode 2 to Mode 1:

- Rod Motion

- Dilution

- Turbine Load RO Adds Positive reactivity

- Rod Motion

- Dilution BOP Raises turbine load using Turbine Governor (or LLl/LL2 if directed)

CUE: Generator Flux surveys have been performed.

Extraction steam Bypass valves are closed.

Fuel conditioning 3% per hour limit on power increase is not required.

If questioned about the MBFP seal water injection pump, I&C is investigating the low delta-P alarm setpoint.

EVALUATOR NOTE:

Proceed to the next event after sufficient rod motion has resulted in positive indication of rod misalignment 4of 14 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Position Applicants Actions or Behavior

_5 RO Diagnoses Control Rod misalignment BOP Acknowledges alarm and performs ARP:

- SF 2-7 Control Rod or Power Distribution Trouble SRO Enters 2-AOP-ROD-1, Rod Control and Indication Systems Malf uncations

- Directs the actions of the ROs RO Determines Control Rod P-10 is misaligned by evaluating the following indications:

- Flight Panel DVM

- PlCS SRO Notifies Reactor Engineering of control rod misalignment.

NOTE: If reactor engineering is contacted to determine if P-10 is misaligned, then reactor engineering responds that P-10 is misaligned from its group.

RO Places rod control in MANUAL BOP Adjusts turbine load as necessary to maintain Tave on program SRO Evaluates the following Technical Specifications:

- 3.1.4 Rod Group Alignment Limits RO Determines actual position of rod P-10 EVALUATOR NOTE:

If I&C assistance is requested to determine rod position using RPI drawer, give the following cue: RPI drawer 2.60 volts.

SIMULATOR OPERATOR:

Activate Trigger 2 to fail LT-4476 when directed by the lead examiner 5of 14 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 3 Page 1 of 1 Event

Description:

LT 4478, 24 SG Controlling Level Channel fails low.

Time Position -

Applicants Actions or Behavior P RO Diagnoses 24 SG Level control deviation BOP Performs ARP for associated alarms:

- FB 1-1 Steam Generator Level Control Deviation

- SB-2 4-3 24 SG Low Level Channel Trip SRO Directs RO to perform immediate action of 2-AOP-INST-I ,

Instrument/Controller Failures RO Diagnoses failure of LT-447B, 24 SG controlling level channel

- Places 24 SG Feedwater Regulating Valve controller in Manual and adjusts FRV position as necessary to control 24 SG level at program.

SRO Evaluates the following Technical Specifications:

- 3.3.1 Table 1 Function 13 (condition E applies)

- 3.3.2 Table 1 Functions 5.b and 6.b (condition D applies)

- Determines that bistable must be tripped within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> per 3.3.1 Condition E and 3.3.2 Condition D BOP Places bistable trip switches in trip:

- LC-447E, Loop 4B High Level, in Foxboro Blue Rack 8-2

- LC-447F, Loop 4B Low Level, in Foxboro Blue Rack B-2

  • EXAMINER NOTE: the next event takes -6 minutes until the first alarm providing a cue to the operator. Therefore, the next malfunction should be activated accordingly.

SIMULATOR OPERATOR:

Insert the next malfunction by activating trigger 2 to cause RCP Upper Bearing Oil Cooler CCW leak when directed by the lead evaluator.

6 o f 14 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Event

Description:

RCP Upper Bearing Oil Cooler CCW leak Position BOP Acknowledge alarm and perform ARP:

- SA 3-1, Reactor Coolant Pump Motor Bearing Oil High Level 1.25

- Observes status light and identifies 24 RCP Upper bearing High lamp illuminated

- Monitors motor bearing temperatures and vibration SRO Enters 2-AOP-RCP-1 Reactor Coolant Pump Malfunctions and directs the actions of the team BOP Monitors the following parameters:

- Stator Winding Temperature

- #1 Seal Delta-P

- RCP Vibrations

- RCP Motor Bearing Temperatures

- #I Seal Inlet Temperatures Notifies the SRO WHEN RCP Motor Bearing Temperatures exceed 200°F (or at a lower value provided by the SRO)

NOTE: RCP BRG Temp High Alarm at 180F BOP Monitors RCP motor bearing temperatures and notifies the SRO when 24 RCP motor bearing temperature is >= 185°F SRO When 24 RCP motor bearing temperature >= 185"F, INITIATES plant shutdown using POP-3.1 (with goal of stopping 24 RCP prior to reaching 200°F)

SRO When 24 RCP temperatures reach 200°F (or earlier if a band is provided by the SRO) directs the team to trip the Reactor, Stop 24 RCP and INITIATE EOP E-0 RO Trips the reactor BOP Stops 24 RCP SRO Directs team to perform immediate actions of EOP E-0, Reactor Trip or Safety Injection EXAMINER NOTE:

Proceed to the next event after the reactor is tripped. The LBLOCA will occur automatically from the reactor trip.

7of 14 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Event

Description:

LBLOCA Directs team to perform immediate operator actions of EOP-E-0, Reactor Trip or Safety Injection Verifies Reactor Tripped Verifies Turbine Tripped Verifies all 480V buses energized 80f 14 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 6 Page1 o f 3 Event

Description:

Safety Injection auto actuation failure, RO manually actuates Time

__p Position RO Checks Status of Safety Injection

- Determines that neither train of SI is actuated

- Manually actuates both trains of Safety Injection BOP Performs Attachment 1 while SRO and RO continue in E-0:

Verify charging system operation

- Starts one charging pump in manual at maximum speed

- Align charging system to the RWST (opens LCV-l12B, Closes LC-l12C, place Makeup Control Switch to STOP)

Check 345 KV MO Disc Switch F7-9 Open

- verifes BKR 7 and 9 open Check status of 480 V buses

- Dispatches NPO to reset all lighting and MCCs 24A, 27A, and 29A

- Stops all Condensate Pumps Verify FW Isolation Check if MSlVs should be isolated Check SW system operation Check SI System Operation Check SI system valve aligment Verify Containment Fan Coolers in service Verify AFW Flow to all SGs Verify Containment Ventilation Isolation Verify Containment Isolation Phase A Check if CS status Verify CCR Air Conditioner status Notify SRO Attachment 1 complete 9of 14 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 6 Page2 of 3 Event

Description:

Safety Injection auto actuation failure, RO manually actuates

~

Position A p p l i c a n t m n s or Behavior -

RO Observes RCS Subcooling less than 30°F and at least one SI Pump Running Stops all RCPs RO Verifies AFW Pumps running and supplying > 400 GPM AFW flow to the SGs Verifies SI Pump flow and RHR pump flow Checks RCP seal cooling Starts 22 SWP Controls RCS Cool-Down by verifying not dumping steam, reducing AFW flow to >400gpm check MSlVs closed Checks PORVS and Spray Valves closed SRO Dispatches NPO to close SWN-4 and SWN-5 in the Zurn strainer pit RO Checks for Faulted and ruptured SGs SRO/RO Diagnose RCS is not intact SRO Transition to EOP E-1, Loss of Reactor or Secondary Coolant 10 of 14 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 6 Page3 o f 3 Event

Description:

Safety Injection auto actuation failure, RO manually actuates Position Applicants Actions or Behavior RO Verifies RCPs stopped Check for any faulted SG Checks SG levels and maintains >400gpm until one SG level >

27%

Opens one Block Valve BOP Resets SI Resets Phase A and Phase B Opens PCV-1228 to supply IA to containment RO Check for ruptured SG Check charging flow BOP Notifies team when RWST level c 9.24 feet SRO Transitions to ES-1.3, Transfer to Cold Leg Recirculation 11 of 14 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Event

Description:

Both Recirculation Pumps both fail to start Position Team Verify SI reset (Resets SI if not previously performed)

SRO Dispatch NPO to fully open SWN-35 and SWN-35-1 CCW Heat Exchanger SW Outlet valves RO Stop all Charging Pumps Turn off all PRZR Heaters Reset Containment Spray Place Recirc Switches 1 and 3 to ON SRO Check SW aligned for three header Check SWN-4 an SWN-5 have been closed RO Place SI Recirc Switch 2 to ON Check Containment Sump Level Greater than 4710 Place SI Recirc Switch 4 to ON

- Determines 21 Recirculation Pump will not start

- Attempts to manually start 22 Recirculation Pump

- Determines neither Recirculation Pump can be started Transfer to cold-leg recirculation and establish minimum required ECCS recirculation flow per ES-1.3 Step 10 Table prior to core uncovery based upon RVLIS indication (41%).

Performs Attachment 2 Cold Leg Recirculation Using RHR Pumps Establish Cold Leg Recirculation Using RHR Pumps

- Check 885A and 8858 both energized 12of 14 NUREG-1021 Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 7 Page2 of 2 Event

Description:

Both Recirculation Pumps both fail to start I SRO 1 Return to ES-1.3 step 10 Determine if adequate low head recirculation flow has been established Checks flow indicators 946A-D and provides values to SRO Place SI Recirc Switch 7 to ON Place SI Recirc Switch 8 to ON EXAMINER NOTE:

Terminate the scenario after adequate Recirc flow has been established and verified, or at the Lead Examiners discretion.

13 of 14 NUREG-1021, Draft Revision 9

Shift Turnover Watch Team Turnover Sheet:

Datemime: TODAY Condition: Power Ops RCS Temp: 552°F  % Power: 38%

RCS Press: 2235 psig MW Gross: 325 PZR Level: 41 % River Water: 63°F RCS Total Leakage: 0.1 gpm Boron Conc: 1138 ppm RCS Unidentified 0.1 gpm Control Rods 178 CBD Leakage:

Xenon: Increasing Condenser Air leakage 6 SCFM EFPD: 340 RCS Gas activity 2.54e-2 pCi/cc PZR Press Control: Channel 1 PZR Level Control: Channel 2 Service Water: 3 Header Ops Risk Assessment: Green Daily Risk Factor: 0.79 Plant Equipment Status :

1. The unit was forced offline four days ago. Repairs have been completed and restart is in progress.

Instructions to the Shift:

1. Continue startup per POP-1.3. Step 4.66 is currently in progress.
2. OM and Reactor Engineering have approved rate of power increase to 100% at 200 MWe per hour.

Page 14 of 14

Appendix D Scenacio Outline Form ES-D-1

-Facility: Indian Point 2 Scenario No.: NRC#4 Op-Test No.: 1 Examiners: Operators:

Initial Conditions: 100% Rated Thermal Power, MOL. 21 EDG is out of Service. 21 Charging Pump is out of service.

Turnover: Unit 2 is at 100% Power steady state conditions 340 EFPD. 21 EDG is out of service and has been inoperable for 42 hours4.861111e-4 days <br />0.0117 hours <br />6.944444e-5 weeks <br />1.5981e-5 months <br />. Maintenance is currently performing repairs.

In addition, 22 Charging Pump was removed from service for corrective maintenance 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> ago. Expected return to service in 35 hours4.050926e-4 days <br />0.00972 hours <br />5.787037e-5 weeks <br />1.33175e-5 months <br />.

Event Event Type* Description N Raise main generator reactive load (MVARS)

ALL C 23 Condensate Pump trips BOP/SRO Reduce steam flow<Feed Flow R Reduce Tave using boration and rod insertion RO I VCT Level Transmitter fails low ALL M Faulted Steam Generator ALL Reactor auto and manual trips fail to actuate

~ ~ ~ ~

C PORV Fails Open. Block valve used to isolate it.

RCS002A RO/SRO

  • (N)ormal (R)eactivity, (1)nstrumer , (C)omponent, (M)ajor 1 of 11

Simulator Setut,

1. Reset to IC-2, 100% MOL
2. Execute batch file Bat "NRC4.bat from Ph.D Expert window:

A BKR-PPL003 52/RTA REACTOR TRIP BKR IMF BKR-PPL003 (-1 0) 5 A BKR-PPL004 52/RTB REACTOR TRIP BKR IMF BKR-PPL004 (-1 0) 5 A BKR-EPS031 52/MG1 MG21 INPUT BREAKER (480)

IMFBKR-EPS031 (-1 0) 5 A BKR-EPS032 52/MG2 MG22 INPUT BREAKER (480)

IMF BKR-EPS032 (-1 0) 5 A LOA-DSG055 DSG-NT-89 DG-21 MANUAL-OFF-AUTO (ECS)

IRF LOA-DSG055 (-1 0) OFF A LOA-DSG032 DSG-NT-110 BKR 52/EG1 RACK-OUT/RACK-IN IRF LOA-DSG032 (-1 0) OUT A LOA-EPSO11 52-C2 C 22 480V BKR RACK OUT/RACK IN IRF LOA-EPSO11 (-1 0) OUT A MOT-CFW003A CP23 CONDENSATE PUMP 23 MTR IMF MOT-CFW003A (1 0) 3 A XMT-CVCOl9A FIXED OUTPUT: LT-112 VCT LEVEL IMF XMT-CVCO19A (2 0) 0.000000 0 34.159801 A MAL-SGN002B STM HDR LK INSIDE CNTMT S/G 22 (NR)

IMF MAL-SGN002B (3 0) 25.000000 360 0.000000

  • set up conditional trigger 30 to actuate when PORV opens TRGSET 30 "xeoo325r.eq.l 'I
  • Fails open PORV 455C four minutes after it auto opens TRG 30 "IMF AOV-RCS002A (-1 240) 1 'I
3. Place CS for 21 EDG in Pullout
4. Place 23 Charging pump in auto operation.
5. Place CS for 22 Charging Pump in Pullout
6. Put a copy of SOP 26.4 MVARs section on RO clipboard.

2 o f 11

Simulator Setup EkR-PPL004 S?/RTB REACTOR TRiP BJ3 00 00 00 00 00 00 None fbl *LIS 00 00 00 BKH-EPS031 5PlMGl MG?l INWTRPEAIEP. 00ODDO 000000 None nia fali 00 no 00 FPSO3Z 52:MGZ M G E 2 lNMJTBP.Ex<Fii (io 03 00 ii(i rici on I\lonp n/a fell AElS r10 00 00 CF#003A W E 3 CJNDN%TE PUMP23 000000 000000 1 n:o winding short 00 00 00

-om 9 4 FIXED IOIJTFIJT L T-i 1 ? LC Oil Ill1no 00 00 Oil 2 34 1w 11 00 loll [Ill

-SGt.IOO:G ZTTM t IDR A INSIDE CNTbiT S/C E nooooo OOOEOO 3 0 5: 0ooooo I

Triggers TRUE I

FALSE I

17 Available 18 Available 19 Available 20 Available 21 Available 22 Available 23 Available 24 Available 25 Available 26 Available 27 Available 28 Available I

TRUE FALSE 3 o f 11

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 1 Page4 o f 2 Event

Description:

Raise Main Generator Reactive Load (MVARS)

Simulator Operator: Telephone the CCR from the System Operator. Request Indian Point Unit 2 raise VARs 100 MVARs OUT.

~ ~~~~~

Position Atmlicants Actions or Behavior CRS Receives VAR request from SO. (Jim Armstrong)

Directs RO to increase lagging MVARs by 100 Directs BOP to monitor UAT voltage during main generator voltage adjustment.

RO Refers to 2-SOP-26.4 BOP If necessary, place Unit Aux Transformer tap changer in Manual and adjust UAT voltage to 7.0 to 7.1 KV while adjusting Main Generator Voltage.

RO Adjust Main Generator Voltage using the AC Raise switch to obtain desired VARS BOP When VARs adjustment is complete, verify UAT voltage 7.0 to 7.2 KV BOP Return the UAT Tap Changer to AUTO Simulator Operator: When directed by the lead examiner, activate Trigger 1 4of 11 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 2 Page1 of 1 Event

Description:

23 Condensate Pump trips, Reduce Steam flow<Feed Flow, Reduce Tave using boration and rod insertion SIMULATOR OPERATOR:

Activate Trigger 1 when directed by Lead Examiner to start event.

Time Position Applicants Actions or Behavior BOP Diagnoses trip of 23 Condensate Pump SRO Directs RO to perform immediate actions of 2-AOP-FW-1, Loss of Main Feedwater RO Verifies Main Feedwater Pumps running SRO Directs team actions using 2-AOP-FW-1, Loss of Main Feedwater RO Reduces turbine load as necessary to maintain Feed Flow 2 Steam Flow Adds negative reactivity using boration and/or control rods to maintain Tave on program Monitors delta-flux during reactivity addition and uses control rods when required to maintain delta-flux within the target band BOP Monitors MBFP suction pressure and if suction pressure cutback actuates, then places MBFP Master Speed Controller in MANUAL and slowly lowers MBFP speed to maintain suction pressure > 310 psig EXAMINER NOTE: Suction pressure will not immediately respond after manual action is taken: Suction pressure will respond after Feed Flow is > Steam Flow AND the Main Feed Regulating Valves begin to throttle closed.

RO Places Main Feed Regulating Valve controllers to manual as necessary and controls feed flow when level in SG > 60% or when controller windup is to be removed.

Places Main Boiler Feed Pump Master Controller back to automatic using SOP 21.1 SIMULATOR OPERATOR:

Activate trigger 2 when directed by the Lead Examiner to proceed to event 2: VCT Level Transmitter fails low 5of 11 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 3 Page 1 of 1 Event

Description:

VCT Level Transmitter fails low Applicants Actions or Behavior Diagnoses VCT Level Transmitter failure Enters 2-AOP-CVCS-1, Chemical and Volume Control System Malfunctions, and directs the operators actions BOP Holds LCV-112C Control Switch in OPEN When LCV-112C indicates open, then CLOSES LCV-1128 RO Places Makeup Control Switch in STOP If necessary, reduces turbine load to keep Tave on program When necessary to raise VCT pressure, initiates manual VCT makeup per SOP-3.2, Reactor Coolant System Boron Concentration Control BOP Monitors VCT Pressure. Controls VCT pressure 2-5 psig above pre-malfunction (19-20 psig) pressure as follows:

- Coordinates with RO to raise VCT Pressure by manual makeup to VCT per SOP-3.2, Reactor Coolant System Boron Concentration Control

- Lowers VCT Pressure by manually diverting letdown via LCV-112A SIMULATOR OPERATOR:

When directed by the Lead Examiner, actuate trigger 3 to cause Faulted Steam Generator, Reactor auto and manual trips fail to actuate 6of 11 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 actuate Diagnose failure of reactor to trip SIMULATOR OPERATOR: Trip both Rod Drive MG set Output Breakers to insert control rods at this time.

7 o f 11 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No. 4: Event No.: 4 Page2 o f 2 Event

Description:

Faulted Steam Generator, Reactor auto and manual trips fail to actuate Verify Containment Ventilation Isolation Verify Containment Pressure Relief Valves Closed I I RO I Check reactor trip and turbine trip have occurred Maintain total feed flow > 800 gpm until NR level in at least one SG > 10%

1 RO I Verify all dilution paths isolated:

- Check FCV-111A demin water flow control valve CLOSED

- Check no flow indicated on FI-111 Primary Water Flow Check for Reactivity Insertion from Uncontrolled RCS Cooldown RO Check CETs e 120OOF Verify Reactor Subcritical I I SRO 1 Return to EOP E-0, Reactor Trip or Safety Injection 8of 11 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 L

Op-Test No.: 1 Scenario No.: 4 Event No.: 5 Page 1 o f 2 Event

Description:

PORV Fails Open. Block valve used to isolate it.

Time Position Applicants Actions or Behavior RO Verify Reactor Trip Verify Turbine Trip BOP Verify power to 480V Buses RO Verify SI Status BOP Performs Attachment 1 while SRO and RO continue in E-0:

Verify charging system operation

- Starts one charging pump in manual at maximum speed

- Align charging system to the RWST (opens LCV-1128, Closes LC-112CJplace Makeup Control Switch to STOP)

Check 345 KV MO Disc Switch F7-9 Open

- verifes BKR 7 and 9 open Check status of 480 V buses

- Dispatches NPO to reset all lighting and MCCs 24AJ27AJ and 29A

- Stops all Condensate Pumps Verify FW Isolation Check if MSlVs should be isolated Check SW system operation Check SI System Operation Check SI system valve aligment Verify Containment Fan Coolers in service Verify AFW Flow to all SGs Verify Containment Ventilation Isolation Verify Containment Isolation Phase A Check if CS status Verify CCR Air Conditioner status Notify SRO Attachment 1 complete 9of 11 NUREG-1021, Draft Revision 9

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 4 Event No.: 5 Page2 o f 2 Event

Description:

PORV Fails Open. Block valve used to isolate it.

Amlicant's Actions or Behavior Verifies AFW Pumps running and supplying > 400 GPM AFW flow to the SGs Verifies SI Pump flow and RHR pump flow Checks RCP seal cooling Starts 22 SWP Controls RCS Cool-Down by verifying not dumping steam, reducing AFW flow to >400gpm and closing MSlVs

+ I I

Ro TEAM SRO Check if RCPs should be stopped Checks for any faulted SG Transitions to E-2, Faulted SG Isolation Verify all actions to isolate 22 SG have been completed Transition to E-1, Loss of Reactor or Secondary Coolant I TEAM Verify that SI Termination Criteria are met I CRS EXAMINER NOTE:

Transition to ES-1.l, SI Termination Terminate the scenario when transition to ES-1.1 is made, or at the discretion of the Lead Examiner 10 of 11 NUREG-1021, Draft Revision 9

Shift Turnover

_ _ ~

Watch Team Turnover Sheet:

Date/Time: TODAY Condition: Power Ops RCS Temp: 562 O F  % Power: 100%

RCS Press: 2235 psig MW Gross: 1017 PZR Level: 48 % River Water: 78 O F RCS Total Leakage: 0.1 gpm Boron Conc: 972 ppm RCS Unidentified 0.1 gpm Control Rods 214 CBD Leakage:

Xenon: Equilibrium Condenser Air leakage 6 SCFM EFPD: 340 RCS Gas activity 2.54e-2 pCi/cc PZR Press Control: Channel 1 PZR Level Control: Channel 2 Service Water: 3 Header Ops Risk Assessment: Yellow Daily Risk Factor: 3.45 Plant Equipment Status:

1. EDG 21 is out of service for bearing replacement. It was removed from service 42 hours4.861111e-4 days <br />0.0117 hours <br />6.944444e-5 weeks <br />1.5981e-5 months <br /> ago and is due back in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. Maintenance is currently performing repairs. TS 3.8.1.B surveillance requirement last performed 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> ago.
2. 21 and 22 EDGs are protected equipment.
3. 22 Charging Pump was removed from service for corrective maintenance 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> ago.

Expected return to service in 35 hours4.050926e-4 days <br />0.00972 hours <br />5.787037e-5 weeks <br />1.33175e-5 months <br />.

Instructions to the Shift:

Maintain current plant conditions.

Page 11 of 11

Retrieved from "https://kanterella.com/w/index.php?title=ML043170136&oldid=2604408"