ML112700883

2011-08-Draft Operating Test

ML112700883
Person / Time
Site:	Wolf Creek
Issue date:	08/26/2011
From:	NRC Region 4
To:	Wolf Creek
References
50-482/11-301 50-482/11-301
Download: ML112700883 (353)

Text

Appendix D Scenario Outline Form ES-D-1 Facility: ___Wolf Creek_______________ Scenario No.: ___1_____ Op-Test No.: _______

Examiners: ____________________________ Operators: _____________________________

Initial Conditions: MOL, 100%

Turnover: Red train CCW (pumps A/C secured due to leakage). TS 3.7.7 Cond A entered (72 hrs to restore). Welding on CCW A Surge tank outlet. Expected return in 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. TS 3.5.2 Cond A entered (72 hrs to restore). (ESFAS alarms are illuminated). Red train ECCS pumps are DNOd or have a TEST/CAUTION (TC) tag and pumps are in Pull-to-Lock (PTL). This includes: CCW A (DNO), CCW C (DNO), CCP A (TC), SIP A (TC) and RHR A (TC). DNO tags are on EG HV-11 and 13, and EG ZL-15 and 53.

Event Malf. Event Event No. No. Type* Description 1 mAB01D I - BOP, Steam Generator D pressure channel AB PT-545 fails low 2 SRO TS determined & entered. TS 3.3.2, Table 3.3.2-1, Fu 1e and 4e.

Cond A (Immediately) and Cond D (72 hrs to trip bistables) are entered.

2 mBB21B I - ATC, Pressurizer pressure channel BB PI-456 fails high SRO TS determined & entered. TS 3.3.1, Table 3.3.1-1, Fu 6 and 8.

Cond A (Immediately) and E (72 hrs to trip bistables) are entered.

TS 3.3.2, Table 3.3.2-1, Fu 1.d, 3.a.3, 5.d, 6.e and 8.b. Cond A (Immediately) and Cond D (72 hrs to trip bistables), and Cond L (1 hr to verify interlock (P-11)).

3 R- The Crew commences a turbine load reduction to 900 MWE NET CREW (945 MWE GROSS) per OFN AF-025, UNIT LIMITATIONS, per Attachment D, TURBINE /GENERATOR DECREASE USING STEAM DUMPS.

4 mBB06C M- Large Break LOCA: cold leg break on Loop C CREW 5 mEJ13B C - ATC, Post trip malfunction #1: Autostart failure of RHR B pump.

SRO Manual start is available.

6 mSA27E C- Post trip malfunction #2: Auto closure of EC HIS-12, SFP HX B C02 ATC, CCW OUTLET VLV, failure to close. Manual closure available.

SRO

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor DRAFT 1 of 5

Scenario summary:

The unit is at 100% power, middle of life. Turnover items include CCW pumps A and C (Red train) are secured due to leakage. Welding on CCW A Surge tank outlet is ongoing. Technical Specification 3.7.7 Condition A was entered (72 hrs to restore). Expected return to service is 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. Red train ECCS pumps are DNOd or have a TEST/CAUTION (TC) tag and pumps are in Pull-to-Lock (PTL). This includes: CCW A (DNO), CCW C (DNO), CCP A (TC), SIP A (TC) and RHR A (TC). DNO tags are on EG HV-11 and 13, and EG ZL-15 and 53.

Event 1: Steam Generator D pressure channel AB PT-545 fails low. Meter indications change, and Main Control Board alarms annunciate. ALRs 00-111C, SG D FLOW MISMATCH or 00-111B SG D LEV DEV, may be entered and performed. OFN SB-008, INSTRUMENT MALFUNCTIONS, is entered and Attachment C performed. These procedures diagnose and mitigate the instrument failure.

The Control Room Supervisor determines Technical Specifications.

Event 2: Pressurizer (PZR) pressure channel BB PI-456 fails high. The PZR spray valves close, meter indications change and various Main Control Board alarms annunciate. ALRs 00-034B, PZR PRESS HI, 00-034C, PZR PORV BLOCK; 00-034E, PRT PRESS HI; 00-035B, PORV OPEN; 00-035D, PZR PORV DISCH TEMP HI; 00-083C, RX PARTIAL TRIP annunciate. OFN SB-008, INSTRUMENT MALFUNCTIONS, is entered and Attachment K performed. These procedures diagnose and mitigate the instrument failure.

The Control Room Supervisor determines Technical Specifications.

Event 3: Booth cue: Topeka Dispatch/System Operator calls to inform Wolf Creek that 345-50 KV Benton line will be removed from service in 20 minutes for four hours. We will be performing Directive #300. Per Directive #300 we will be divorcing Wolf Creek from the Athens line (also opening 69-14 Breaker). Please reduce turbine load to less than 900 MWE NET.

If necessary, Call Superintendent cue: Maintain reactor power and use Attachment D, TURBINE

/GENERATOR DECREASE USING STEAM DUMPS.

The Crew commences a turbine load reduction to 900 MWE NET (945 MWE GROSS) per OFN AF-025, UNIT LIMITATIONS.

Event 4: The Main Event is a Large Break Loss of Coolant Accident.

Diagnostics include: PZR level decreases and RCS pressure decreases. OFN BB-007, SG/RCS LEAKAGE HIGH, may be entered & performed. A Reactor trip and Safety Injection occur. EMG E-0, REACTOR TRIP OR SAFETY INJECTION, is entered & performed.

RCPs are tripped per EMG E-0 Foldout page criteria.

EMG-E-1, LOSS OF REACTOR OR SECONDARY COOLANT is entered & performed.

Eventually 36% Refueling Water Storage Tank (RWST) level is achieved and Main Control Board alarm ALR 00-047C, RWST LEV LOLO 1 AUTO XFR actuates. ALR 00-047C directs performance of EMG ES-12, TRANSFER TO COLD LEG RECIRCULATION.

The crew transitions to EMG ES-12, TRANSFER TO COLD LEG RECIRCULATION. The procedure is performed through step 10 to establish cold leg recirculation/ECCS recirculation.

DRAFT 2 of 5

Post trip malfunctions:

Event 5: Autostart failure of RHR B pump. Manual start is available. This component failure is procedurally addressed in Attachment F of EMG E-0, REACTOR TRIP OR SAFETY INJECTION.

However, the pump can be started after the Immediate Actions of EMG E-0, REACTOR TRIP OR SAFETY INJECTION, are performed and concurrence of the CRS is obtained.

Event 6: Auto closure of EC HIS-12, SFP HX B CCW OUTLET VLV, fails to close. Manual closure is available. This component failure is procedurally addressed in EMG ES-12, TRANSFER TO COLD LEG RECIRCULATION, at step 3.

Scenario Critical Tasks (CT):

Event 1: CT: take manual control, select alternate controlling channel prior to actuation of the Reactor Protection System Event 4: CT: using EMG ES-12, steps 1 through 10, transfer to cold leg recirculation to establish ECCS recirculation Event 5: CT: start RHR B pump, as this is the only low head injection pump available for decay heat removal for a Large Break LOCA.

DRAFT 3 of 5

Probabilistic Risk Analysis for this scenario includes:

Core Damage Frequency by Initiating Event Initiating Event Core Damage CDF Percent Initiating Event Frequency (/yr) Frequency (/yr) Contribution Loss of Offsite Power 2.88E-02 6.59E-06 36.51%

Small LOCA 29.63%

3.00E-03 5.35E-06 Interfacing Systems LOCA 1.93E-06 10.69%

Very Small LOCA 7.03%

6.20E-03 1.27E-06 Transients With Power Conversion Systems Available 1.05E+00 9.88E-07 5.47%

Steam Generator Tube Rupture 3.67E-03 8.77E-07 4.86%

Reactor Vessel Failure 3.00E-07 3.00E-07 1.66%

Steamline Break 1.13E-02 1.88E-07 1.04%

Transients Without Power Conversion 1.15E-01 1.71E-07 0.95%

Systems Available Medium LOCA 6.10E-05 1.46E-07 0.81%

Loss of All Service Water 6.86E-06 8.30E-08 0.46%

Loss of Component Cooling Water 2.14E-04 5.79E-08 0.32%

Loss of Vital DC Bus NK04 2.64E-03 4.32E-08 0.24%

Large LOCA 7.20E-06 2.80E-08 0.16%

Feedwater Line Break 3.17E-03 2.06E-08 0.11%

Loss of Vital DC Bus NK01 2.64E-03 1.12E-08 0.06%

Top Risk Significant Systems EF Essential Service Water KJ/NE Onsite Emergency Power EG Component Cooling Water AL Aux Feedwater EJ Residual Heat Removal JE Diesel Fuel Oil NB Lower Medium Voltage NK 125 V DC BB Reactor Coolant System GM Diesel Building HVAC GD ESW HVAC GL Aux Building HVAC BN Refueling Water Storage Tank SA/SB ESFAS/Reactor Protection DRAFT 4 of 5

Technical Specifications exercised:

Event 1: TS determined & entered. TS 3.3.2, Table 3.3.2-1, Fu 1e and 4e. Cond A (Immediately) and Cond D (72 hrs to trip bistables) are entered.

Event 2: TS determined & entered. TS 3.3.1, Table 3.3.1-1, Fu 6 and 8. Cond A (Immediately) and E (72 hrs to trip bistables) are entered.

TS 3.3.2, Table 3.3.2-1, Fu 1.d, 3.a.3, 5.d, 6.e and 8.b. Cond A (Immediately) and Cond D (72 hrs to trip bistables), and Cond L (1 hr to verify interlock (P-11)).

DRAFT 5 of 5

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 1 Page 1 of 35_

Event

Description:

Steam Generator D pressure channel AB PT-545 fails low CT success: BOP takes manual control, selects alternate controlling channel prior to actuation of the Reactor Protection System Time Position Applicants Actions or Behavior BOOTH: Setup scenario and simulator. At Lead Examiner cue, insert KEY 1 for first event.

Diagnostics: Steam Generator D pressure channel AB PT-545 fails low. Meter AB PI-545A, SG D PRESS, fails low. Meter AB FI-543A, SG D STEAM FLOW, fails low. Main Control Board (MCB) alarms 00-111C, SG D FLOW MISMATCH and/or 00-111B SG D LEV DEV annunciate.

CREW Identifies and diagnoses SG D pressure channel AB PT-545 low failure.

CRS ENTER and DIRECT ALR 00-111B, SG D LEV DEV Procedure NOTE: Steps 1 through 3 are Memory Action steps.

BOP 1. Check SG D controlling level channel:

5% greater than program level or 5% less than program level BOP 2. Check instruments - operating properly o SG D controlling level channel - WITHIN 6% OF REMAINING SG D NARROW RANGE LEVEL CHANNELS AE LI-549 AE LI-554 o SG D controlling channel steam pressure - WITHIN 100 PSIG OF REMAINING CHANNELS - NO; perform RNO AB PI-544A AB PI-545A 2RNO: Perform the following (CT - performs RNO2a, b and c)

a. Place FRV controller AE FK-540 in MANUAL

b. ADJUST FRV controller AE FK-540, as necessary, to establish Steam Generator level at program value

c. SELECT alternate channel for control AB FS-542C for steam flow: selected to F542 channel DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 1 Page 2 of 35_

Event

Description:

Steam Generator D pressure channel AB PT-545 fails low Time Position Applicants Actions or Behavior BOP d. Return FRV controller AE FK-540 to AUTOMATIC (may be delayed until at 50% program or alarm is cleared)

CRS e. Go to OFN SB-008, INSTRUMENT MALFUNCTIONS Examiner NOTE: If the Crew performed the ALR, it will impact how OFN SB-008 is implemented. All appropriate OFN SB-008 steps are included for this event.

CRS ENTER and DIRECT OFN SB-008, INSTRUMENT MALFUNCTIONS Procedure NOTE: Steps 1 through 8 can be performed in any order.

CRS 1. Check if secondary system instrument channel is malfunctioning:

a. Determine appropriate attachment for malfunctioning channel from table below: Attachment C is determined and entered SG Pressure (AB) P-545 Attachment C

b. Go to appropriate attachment for malfunctioning secondary system channel.

CRS OFN SB-008, Attachment C, SG PRESSURE CHANNEL MALFUNCTION Procedure CAUTION: SG steam pressure is an input to the thermal power program. A failed steam pressure channel could cause the thermal power program to be inaccurate.

Procedure NOTE: Steps C1 through C4 are Memory Action steps.

BOP C1. Identify failed instrument channel:

o Compare SG pressure indications to confirm SG pressure channel failure:

o AB PI-544A for SG D o AB PI-545A for SG D o AB PI-546A for SG D DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 1 Page 3 of 35_

Event

Description:

Steam Generator D pressure channel AB PT-545 fails low CT success: BOP takes manual control, selects alternate controlling channel prior to actuation of the Reactor Protection System Time Position Applicants Actions or Behavior BOP C2. Check if failed SG pressure channel used for feedwater control:

a. Identify steam flow channel compensated by failed pressure channel from table below:

SG D P-544/P-545 F-542/F-543

b. Check steam flow channel associated with failed steam pressure channel selected on SG STEAM FLOW CHANNEL SEL switch; if NO, Perform RNO RNO b: Go to step C7 Examiner NOTE: Steps C3, C4, C5 and C6 are bypassed if ALR 00-111B was performed earlier.

BOP C3. Place affected SG MFW REG VLV CTRL - in MANUAL (CT - perform C3, C4 and C5)

AE FK-540 BOP C4. ADJUST affected SG MFW REG VLV CTRL, as necessary, to establish steam generator level at program: (CT - perform C3, C4 and C5)

AE FK-540 BOP C5. SELECT alternate steam flow channel on SG STEAM FLOW CHANNEL SEL switch: (CT - perform C3, C4 and C5) o AB FS-542C (selected to F542 channel)

BOP C6. Restore affected SG MFW REG VLV CTRL to - AUTO DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 1 Page 4 of 35_

Event

Description:

Steam Generator D pressure channel AB PT-545 fails low Time Position Applicants Actions or Behavior CRS C7. Monitor the following Technical Specifications LCOs and comply with Action Statements, as appropriate:

o 3.3.2, ESFAS, Table 3.3.2-1, Fu 1.e and 4.e o 3.3.4, Remote Shutdown Instrumentation, Table 3.3.4-1, Fu 7 o 3.3.3, Post Accident Monitoring Instrumentation, Table 3.3.3-1, Fu 8 o 3.3.6, Containment Purge Isolation Instrumentation o 3.3.7, CREVS CRS determines: TS 3.3.2, Table 3.3.2-1, Fu 1e and 4e. Cond A (Immediately) and Cond D (72 hrs to trip bistables) are entered.

Booth cues: If contacted as Call Supt.: acknowledge plant status. If contacted as INC: acknowledge request.

Event termination: When Technical Specifications are determined and/or at Lead Examiners discretion, event is terminated. Booth operator inserts KEY 2 for event two at Lead Examiners direction.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 2 Page 5 of 35_

Event

Description:

Pressurizer pressure channel BB PI-456 fails high Time Position Applicants Actions or Behavior Booth: Booth operator inserts KEY 2 for event two at Lead Examiners direction.

Diagnostics: Pressurizer pressure channel BB PI-456 fails high. Meter PRESSURIZER PRESSURE BB PI-456 fails high. PZR Spray valves BB ZL-455B and BB ZL-455C indicate closing. MCB alarms 00-034B, PZR PRESS HI, 00-034C, PZR PORV BLOCK; 00-034E, PRT PRESS HI; 00-035B, PORV OPEN; 00-035D, PZR PORV DISCH TEMP HI; 00-083C, RX PARTIAL TRIP annunciate.

CREW Identifies and diagnoses Pressurizer pressure channel BB PI-456 high failure.

Examiner NOTE: PORV BB HIS-456A will open and close.

CRS ENTER and DIRECT OFN SB-008, INSTRUMENT MALFUNCTIONS Procedure NOTE: Steps 1 through 8 can be performed in any order.

RO 2. Check if reactor coolant system instrument channel or controller is malfunctioning

a. Determine appropriate attachment for malfunction channel or controller from table below:

PZR Pressure (BB) P-456 Attachment K

b. Go to appropriate attachment for malfunctioning reactor coolant system channel or controller.

CRS, RO OFN SB-008, Attachment K, PZR Pressure Malfunction Procedure NOTE: Steps K1 through K3 are Memory Action steps RO K1. Identify failed instrument channel:

a. Compare PZR pressure indications to confirm pressure channel failure:

o BB PI-455A o BB PI-456 o BB PI-457 o BB PI-458 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 2 Page 6 of 35_

Event

Description:

Pressurizer pressure channel BB PI-456 fails high Time Position Applicants Actions or Behavior RO K2. Check failed PZR pressure channel selected on PZR PRESS CTRL SEL switch.

o BB PK-455K RO K3. Place PZR PRESS MASTER CTRL in manual and control pressure.

o BB PK-455A RO K4. Select alternate PZR pressure channel on PZR PRESS CTRL SEL switch o BB PS-455F SRO, RO K5. Take following actions, as appropriate to stop pressure control transient:

a. Check PZR spray valves - RESPONDING CORRECTLY

b. Check PZR control heaters - OPERABLE

c. Ensure PZR PORV - CLOSED o BB HIS-455A o BB HIS-456A RO K6. Return PZR pressure control to automatic:

o Spray valves o Control heaters o Backup heaters o Open PORV block valves o PZR pressure control DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 2 Page 7 of 35_

Event

Description:

Pressurizer pressure channel BB PI-456 fails high Time Position Applicants Actions or Behavior RO K7. Monitor PZR pressure response to ensure proper control RO K8. Check failed pressure channel not selected on PZR PRESS RECORD SEL o BB PS-455G RO K9. Check failed pressure channel not selected on OP DT/OP DT LOOP RECORD SEL switch o SC TS-411 CRS K10. Monitor the following Technical Specification LCOs and comply with Action Statements, as appropriate:

o 3.3.1, RTS INSTRUMENTATION, Table 3.3.1-1 Fu 6 and 8 o 3.3.2, ESFAS INSTRUMETATION, Table 3.3.2-1, Fu 1.d, 3.a.3, 5.d, 6.e and 8.b o 3.3.4, REMOTE SHUTDOWN INSTRUMENTATION, Table 3.3.4-1, Fu 3 o 3.3.6, CONTAINMENT PURGE ISOLATION INSTRUMENTATION o 3.3.7, CREVS ACTUATION INSTRUMENTATION CRS determines: TS 3.3.1, Table 3.3.1-1, Fu 6 and 8. Cond A (Immediately) and E (72 hrs to trip bistables) are entered.

TS 3.3.2, Table 3.3.2-1, Fu 1.d, 3.a.3, 5.d, 6.e and 8.b. Cond A (Immediately) and Cond D (72 hrs to trip bistables), and Cond L (1 hr to verify interlock (P-11)).

Booth cues: If contacted as Call Supt.: acknowledge plant status. If contacted as INC: acknowledge request.

Event termination: When Technical Specifications are determined and/or at Lead Examiners discretion, event is terminated.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 3 Page 8 of 35_

Event

Description:

The Crew commences a turbine load reduction to 900 MWE NET (945 MWE GROSS) per OFN AF-025, UNIT LIMITATIONS, per Attachment D, TURBINE /GENERATOR DECREASE USING STEAM DUMPS.

Time Position Applicants Actions or Behavior At Lead Examiner direction: Booth cue: KEY 3 for Event 3 inserted. Call as Topeka Dispatch/System Operations to inform Wolf Creek that 345-50 KV Benton line will be removed from service in 20 minutes for four hours. We will be performing Directive #300. Per Directive #300 we will be divorcing Wolf Creek from the Athens line (also opening 69-14 Breaker). Please reduce turbine load to less than 900 MWE NET.

Booth: If necessary, Call Superintendent cue: Maintain reactor power and use Attachment D, TURBINE

/GENERATOR DECREASE USING STEAM DUMPS.

CREW Commences a turbine load reduction to 900 MWE NET (945 MWE GROSS) per OFN AF-025, UNIT LIMITATIONS.

CRS ENTERS and DIRECTS OFN AF-025, UNIT LIMITATIONS CREW 1. Determine applicable step.

a. Check Stator Cooling Water System - NORMAL

b. Check Generator Hydrogen System - NORMAL

c. Check Main Transformers - NORMAL

d. Check all the following transformers - NORMAL o Startup transformer o XNB01 transformer o XNB02 transformer o Unit Auxiliary transformer - NORMAL

e. Check Condenser vacuum - NORMAL

f. Go to step 7 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 3 Page 9 of 35_

Event

Description:

OFN AF-025, UNIT LIMITATIONS Time Position Applicants Actions or Behavior CREW 7. Check Westar Transmission Services (WETS) has reported a loss of ability to assess the operation of the Electrical System relative to Predictive or Actual voltage with one of the following conditions met: NO, perform RNO TSO reports an unsatisfactory qualitative assessment Greater than 24 hrs have elapsed with neither the Westar Energy Model or the SPP model available RNO: Go to step 9 Booth cue: If contacted as Systems OPS: Qualitative assessment is SAT.

Booth: If necessary, Call Superintendent cue: Maintain reactor power and use Attachment D, TURBINE

/GENERATOR DECREASE USING STEAM DUMPS.

CRS 9. Check Westar Transmission Services (WETS) has reported an actual or predicted switchyard voltage degradation; No, Perform RNO 9RNO Go to Step 11 CRS 11. Check for conditions requiring unit load reduction:

a. Determine maximum unit load, using Attachment A, UNIT LOAD LIMITS.

b. Reduce unit load, as necessary, to satisfy load limits using appropriate procedure:

GEN 00-004, POWER OPERATIONS or GEN 00-005, MINIMUM LOAD TO HOT STANDBY or OFN MA-038, RAPID PLANT SHUTDOWN or ATTACHMENT D, TURBINE/GENERATOR LOAD DECREASE USING STEAM DUMPS Examiner NOTE: Attachment D supports a unit load reduction to less than 900 MWE NET (945 MWE GROSS) as directed by Topeka Dispatch for a loss of Benton line DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 3 Page 10 of 35_

Event

Description:

OFN AF-025, UNIT LIMITATIONS, ATTACHMENT D, TURBINE/GENERATOR LOAD DECREASE USING STEAM DUMPS Time Position Applicants Actions or Behavior CRS ENTER and DIRECT ATTACHMENT D, TURBINE/GENERATOR LOAD DECREASE USING STEAM DUMPS CRS D1. If the power decrease on steam dumps is anticipated to exceed 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, then the Call Superintendent and the System Engineer should be contacted to assess possible adverse affects on the main condenser internals.

NA as the power decrease is expected to be four hours per cue.

CRS D2. If reactor power is to be maintained using steam dumps, then perform the following:

RO D.2.1 Place bank selector switch (SE HS-9) in MANUAL BOP D.2.2 Record AB PK-507, STEAM HDR PRESS CTRL setpoint BOP D.2.3 Place STEAM HDR PRESS CTRL (AB PK-507) in MANUAL BOP D.2.4 Manually set STEAM HDR PRESS CTRL (AB PK-507) output to zero BOP D.2.5 Place STEAM DUMP SEL (AB US-500Z) to STM PRESS position BOP D.2.6 Ensure Miscellaneous Status Panel SC066W lights for Steam Dump Valves Armed are lit o LP COND STM DUMP VLVS ARMED o IP COND STM DUMP VLVS ARMED o HP COND STM DUMP VLVS ARMED DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 3 Page 11 of 35_

Event

Description:

OFN AF-025, UNIT LIMITATIONS, ATTACHMENT D, TURBINE/GENERATOR LOAD DECREASE USING STEAM DUMPS Time Position Applicants Actions or Behavior BOP D.2.7 () Place STEAM HDR PRESS CTRL (AB PK-507) in AUTO Procedure NOTE: AB PK-507, STEAM HDR PRESS CTRL setpoint must be adjusted to the point where the steam dumps are actually controlling steam pressure so they will respond as soon as turbine load is changed.

BOP D.2.8 Using slow incremental decreases in AB PK-507, STEAM HDR PRESS CTRL setpoint, decrease the setpoint until at least one valve in the first group of steam dumps starts cycling open and closed at least once every ten seconds controlling steam pressure.

BOP D.2.9 Maintain adjacent condenser Ps less than or equal to 2 Hg (Examiner NOTE: This step not expected to be performed)

1. If the P between adjacent condensers exceeds 2 Hg, then perform the following:

a. Stop turbine load decrease.

b. Decrease reactor power as follows to restore P

1) Adjust boron concentration and control rods as necessary, to establish desired reactor power decrease ramp rate.

2) As reactor power is reduced, adjust AB PK-507, STEAM HDR PRESS CTRL to maintain turbine load stable.

c. When P is restored, then stop reactor power decrease and continue turbine load decrease to desired power level DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 3 Page 12 of 35_

Event

Description:

OFN AF-025, UNIT LIMITATIONS, ATTACHMENT D, TURBINE/GENERATOR LOAD DECREASE USING STEAM DUMPS Time Position Applicants Actions or Behavior BOP D.2.10 At AC XX-1, decrease load set using Load Set pushbuttons or Load Limit potentiometer, as follows:

1. Use LOAD LIMIT SET potentiometer to decrease load OR

2. Use Load set, as follows:

a. () If desired to position control valves in their controlling range, then slowly decrease Load Limit pot until a 1-2 Mwe load decrease is noted.

b. Slowly decrease load set MW until AT SET LOAD light is on and LOAD LIMIT LINITING light extinguishes.

c. Raise load limit pot slightly

d. Select LOADING RATE LIMIT % MIN to 1/2

e. Depress DECREASE LOADING RATE ON pushbutton

f. Decrease load using the LOAD SELECTOR, DECREASE LOAD pushbutton

3. Adjust steam dumps, as necessary, to maintain reactor power less than or equal to 3565 MW thermal Lead Examiner may terminate the event when the BOP reduces turbine load approximately 10-20 MW, steam dumps are modulating and reactor power remains stable.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 13 of 35_

Event

Description:

Large Break Loss of Coolant Accident Time Position Applicants Actions or Behavior Booth: At Lead Examiner direction, insert KEY 4 for next event (event 4).

Diagnostics: PZR level decreases and RCS pressure decreases. CTMT humidity increases.

CRS ENTER and DIRECT OFN BB-007, RCS LEAKAGE HIGH (if time before automatic Reactor trip and Safety Injection allows)

CRS 1. Check plant in Mode 1, 2, or 3 with Accumulator outlet valves open RO 2. Check PZR level - GREATER THAN 6%

RO 3. Check PZ level - GREATER THAN 17%

RO 4. Check PZR level - STABLE OR INCREASING; No - Perform RNO RNO: If PZR level is less than program level, then perform the following:

a. Establish maximum required charging flow from one pump

b. If PZR level can NOT be maintained, then perform the following:

1) Close Letdown Orifice Isolation Valves to establish stable PZR level o BG HIS-8149AA o BG HIS-8149BA o BG HIS-8149CA

2) Close RCS Letdown to Regen HX isolation valves o BG HIS-459 o BG HIS-460 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 14 of 35_

Event

Description:

Large Break Loss of Coolant Accident CT success: start RHR B pump (EJ HIS-2 to RUN), as this is the only low head injection pump available for decay heat removal for a Large Break LOCA Time Position Applicants Actions or Behavior CRS, RO Foldout page criteria #1 SI Actuation criteria: If any condition listed occurs, then trip the reactor, actuate SI, and go to EMG E-0, REACTOR TRIP OR SAFETY INJECTION step 1.

Both the following conditions exist:

o Reactor is tripped AND o RCS subcooling based on subcooling monitor - LESS THAN 30° OR PZR pressure - CANNOT BE MAINTAINED OR PZR level - CANNOT BE MAINTAINED OR All of the following conditions exits:

o Normal charging is maximized from one pump AND o Letdown is isolated AND o PZR level is decreasing CREW Either the automatic Reactor trip and Safety Injection occur OR the CRS directs a manual Reactor trip and Safety Injection signal actuation.

CRS ENTER and DIRECT EMG E-0, REACTOR TRIP OR SAFETY INJECTION RO, BOP Perform Immediate Actions of EMG E-0, REACTOR TRIP OR SAFETY INJECTION and report results to CRS Examiner NOTE: Steps 1-4 are Immediate Action steps performed from memory. Usually the RO performs steps 1, 3 and 4, the while BOP performs step 2.

RO The RO reports the B RHR pump did not start. As it is the ONLY low head injection pump available for decay heat removal, the CRS directs the RO to start the pump. (CT - RHR PUMP B, EJ HIS-2 to RUN)

Examiner NOTE: this pump may be started during the performance of Attachment F.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 15 of 35_

Event

Description:

Large Break Loss of Coolant Accident Time Position Applicants Actions or Behavior CREW When RCS pressure is less than 1400 psig, RCPs are tripped per Foldout page criteria #1: RCP Trip Criteria If all conditions listed below occur, then trip all RCPs o RCS pressure - < 1400 psig o CCPs or SI pumps - AT LEAST ONE RUNNING o Operator controlled cooldown - NOT IN PROGRESS RO 1. Verify Reactor trip

a. Check rod bottom lights - LIT

b. Ensure reactor trip breakers and bypass breakers - OPEN o SB ZL-1 o SB ZL-2 o SB ZL-3 o SB ZL-4

c. Check intermediate range neutron flux - DECREASING o SE NI-35B [GAMMA METRICS]

o SE NI-36B [GAMMA METRICS]

BOP 2. Verify turbine trip

a. Check the following:

Main Stop valves - ALL CLOSED OR Turbine Auto Stop bistable lights - AT LEAST TWO LIT RO 3. Check AC Emergency Busses - AT LEAST ONE ENERGIZED NB01 - ENERGIZED NB02 - ENERGIZED DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 16 of 35_

Event

Description:

Large Break Loss of Coolant Accident Time Position Applicants Actions or Behavior RO 4. Check if Safety Injection is actuated:

a. Check any indication SI is actuated - LIT Annun. 00-030A NF039A LOCA SEQ ACTUATED - LIT Annun. 00-031A NF039B LOCA SEQ ACTUATED - LIT ESFAS status panel SIS section - ANY WHITE LIGHTS LIT Partial trip status Permissive/Block status panel - SI RED LIGHT LIT

b. Check both trains of SI actuated o Ann 00-030A NF039A LOCA SEQ ACTUATED - LIT o Ann 00-031A NF039B LOCA SEQ ACTUATED - LIT RO 5. Check if SI is required:

SI was manually actuated AND was required RCS pressure is currently or has been - LESS THAN OR EQUAL TO 1830 PSIG Any SG press is currently or has been - LESS THAN OR EQUAL TO 615 PSIG Containment press is currently or has been - GREATER THAN OR EQUAL TO 3.5 PSIG RCS subcooling is currently or has been - LESS THAN 30°F [45°F]

PZR level is currently or has been - LESS THAN 6% [33%]

BOP 6. Check Main Generator Breakers and Exciter Breaker - OPEN o MA ZL-3A o MA ZL-4A o MB ZL-2 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 17 of 35_

Event

Description:

Large Break Loss of Coolant Accident Time Position Applicants Actions or Behavior RO/BOP 7. Verify Automatic Actions using Attachment F, AUTOMATIC SIGNAL VERIFICATION Examiner NOTE: Attachment F procedure steps see page 22 BOP 8. Check total AFW flow - >270,000 lbm/hr BOP 9. Check RCS cold leg temperatures Stable at or trending to 557°F for condenser steam dumps; No, perform RNO Stable at or trending to 561°F for SG ARVs; NO perform RNO 9RNO:

a. If temperature is less than setpoint and decreasing, then perform the following:

1) Stop dumping steam

2) If any MSIV is open, then close Main Turbine Stop and Control Valves Startup Drains.

o AC HIS-134

3) If cooldown continues, then control total feed flow to limit RCS cooldown. Maintain total feed flow > 270,000 lbm/hr until narrow range level greater than 6% [29%] in at least one SG.

4) If cooldown continues due to excessive steam flow, then isolate main steamlines by depressing both MS ISO VLV ALL CLOSE pushbuttons o AB HS-79 o AB HS-80

b. If temperature is greater than setpoint and increasing, then perform one of the following:

Dump steam to condenser Dump steam using SG ARVs DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 18 of 35_

Event

Description:

Large Break Loss of Coolant Accident Time Position Applicants Actions or Behavior BOP 10. Establish SG pressure control

a. Check condenser - AVAILABLE; No Perform RNO o C-9 LIT o MSIV - OPEN; NO o Circulating water pumps - RUNNING 10RNOa. Perform the following

1) Use the SG ARVs

2) Go to step 11 RO 11. Check PZR PORVs

a. Check PZR PORVs - CLOSED o BB HIS-455A o BB HIS-456A

b. Power to block valves - AVAILABLE o BB HIS-8000A o BB HIS-8000B

c. RCS pressure - LESS THAN 2185 PSIG RO 12. Check normal PZR Spray valves - CLOSED o BB ZL-455B o BB ZL-455C DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 19 of 35_

Event

Description:

Large Break Loss of Coolant Accident Time Position Applicants Actions or Behavior RO 13. Check PZR Safety valves - CLOSED o BB ZL-8010A o BB ZL-8010B o BB ZL-8010C RO 14. Check if RCPs should be stopped:

a. Check RCPs - ANY RUNNING; No Perform RNO 14RNOa. Go to step 15 CRS 15. Direct Operator to monitor Critical Safety Functions using EMG F-0, CRITICAL SAFETY FUNCTION STATUS TRESES (CSFST).

Examiner NOTE: Surrogate STA performs this activity and reports results to the CRS.

RO 16. Check if SGs are not faulted:

a. Check pressures in all SG -

o NO SG PRESSURE DECREASING IN AN UNCONTROLLED MANNER o NO SG COMPLETELY DEPRESSURIZED RO 17. Check if SG tubes are intact:

Direct Health Physics to survey steam lines in Area 5 of the Aux.

Building.

Condenser air discharge radiation - NORMAL BEFORE DISCHARGE (GEG 925)

SG blowdown and sample radiation - NORMAL BEFORE ISOLATION (BML 256, SJL 026)

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 20 of 35_

Event

Description:

Large Break Loss of Coolant Accident Time Position Applicants Actions or Behavior RO Step 17 cont.

Turbine driven auxiliary feedwater pump exhaust radiation - NORMAL (FCT 381)

SG steamline radiation - NORMAL o ABS 114 for SG A o ABS 113 for SG B o ABS 112 for SG C o ABS 111 for SG D BOP 18. Check SG levels - INCREASING IN A CONTROLLED MANNER o Narrow range o Wide range RO 19. Check if RCS in intact in Containment:

a. Containment radiation - NORMAL BEFORE ISOLATION o GTP 311 o GTI 312 o GTG 313 o GTP 321 o GTI 322 o GTG 323 o GTA 591 o GTA 601 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 21 of 35_

Event

Description:

Large Break Loss of Coolant Accident Time Position Applicants Actions or Behavior RO Step 19 cont.

b. Containment pressure - NORMAL o GN PI-934 o GN PI-935 o GN PI-936 o GN PI-937 o GT PDI-40 o GN PR-934

c. Containment sump level - NORMAL; No, Perform RNO o EJ LI-7 o EJ LI-8 o EJ LR-6 o LF LI-9 o LF LI-10 19RNO: Perform the following:

1. Ensure BIT inlet and outlet valves are open:

o EM HIS-8803A o EM HIS-8803B o EM HIS-8801A o EM HIS-8801B

2. Go to EMG E-1, LOSS OF REACTOR OR SECONDARY COOLANT, Step 1 CRS LEAD a transition brief prior to directing actions of EMG E-1.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 5 Page 22 of 35_

Event

Description:

Large Break Loss of Coolant Accident EMG E-0 Attachment F, AUTOMATIC SIGNAL VERIFICATION CT success: start RHR B pump, as this is the only low head injection pump available for decay heat removal for a Large Break LOCA Time Position Applicants Actions or Behavior RO/BOP F1. Verify Feedwater Isolation

a. Main feedwater pumps - TRIPPED

b. Main feedwater reg valves - CLOSED

c. Main feedwater reg bypass valves - CLOSED

d. Main feedwater isolation valves - CLOSED

e. Main feedwater chemical injection valves - CLOSED

f. Check ESFAS status panel SGBSIS section - ALL WHITE LIGHTS LIT RO/BOP F2. Verify Containment Isolation Phase A

a. Check ESFAS status panel CISA section - ALL WHITE LIGHTS LIT RO/BOP F3. Verify AFW pumps running:

a. Check motor driven AFW pumps - BOTH RUNNING

b. Check turbine driven AFW pump - RUNNING RO/BOP F4. Verify ECCS pumps running

a. Check CCPs - BOTH RUNNING

b. Check SI pumps- BOTH RUNNING

c. Check RHR pumps - BOTH RUNNING; No - Perform RNO F4 RNO c. Manually start pumps.

o EJ HIS-1 o EJ HIS-2 CT success - RHR B must be started as it is the only available low head injection pump for decay heat removal DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 23 of 35_

Event

Description:

Large Break Loss of Coolant Accident EMG E-0 Attachment F, AUTOMATIC SIGNAL VERIFICATION Time Position Applicants Actions or Behavior RO/BOP F5. Verify CCW alignment:

a. Check CCW pumps - ONE RUNNING IN EACH TRAIN

b. Check one pair of CCW service loop Supply and Return valves for an operating CCW pump - OPEN RO/BOP F6. Check ESW pumps - BOTH RUNNING RO/BOP F7. Check Containment Fan Coolers - RUNNING IN SLOW SPEED RO/BOP F8. Verify Containment Purge Isolation:

a. Check ESFAS status panel CPIS section - ALL WHITE LIGHTS LIT RO/BOP F9. Verify both trains of Control Room Ventilation Isolation:

a. Check ESFAS status panel CRVIS section - ALL WHITE LIGHTS LIT

b. Ensure Control Room outer door - CLOSED RO/BOP F10. Verify Main Steamline Isolation not required:

a. Check Containment pressure - HAS REMAINED LESS THAN 17 PSIG (GN PR-934)

b. Check either condition below - SATISFIED Low steamline pressure SI - NOT BLOCKED AND steamline pressure - HAS REMAINED GREATER THAN 615 PSIG or Low steamline pressure SI - NOT BLOCKED AND steamline pressure - HAS REMAINED LESS THAN 100 PSI/50 SEC DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 24 of 35_

Event

Description:

Large Break Loss of Coolant Accident EMG E-0 Attachment F, AUTOMATIC SIGNAL VERIFICATION Time Position Applicants Actions or Behavior RO/BOP F11. Verify Containment Spray not required:

a. Containment pressure - HAS REMAINED LESS THAN 27 PSIG: No, Perform RNO o Ann 00-059A, CSAS - NOT LIT o Ann 00-059B, CISB - NOT LIT o GN PR-934 F11 RNO: Perform the following:

1. Stop all RCPs

2. If Containment Spray has NOT actuated, then manually actuate Containment Spray

3. Check ESFAS status panel CSAS section - ALL WHITE LIGHTS LIT

4. If any CSAS component NOT properly aligned, then manually align associated component

5. Check ESFAS status panel CISB section - ALL WHITE LIGHTS LIT

6. If any CISB valve not closed, then manually close valve. If valve(s) can not be closed, then manually or locally isolate affected Containment penetration.

Refer to ATTACHMENT E, VALVES CLOSED BY CONTAINMENT ISOLATION SIGNAL PHASE B RO/BOP F12. Verify ECCS flow:

a. Check CCP to BIT flow meters - FLOW INDICATED

b. Check RCS pressure - LESS THAN 1700 PSIG

c. Check SI pump discharge flow meters - FLOW INDICATED

d. Check RCS pressure - LESS THAN 325 PSIG; no, Perform RNO F12RNOd: Go to Step F13 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 25 of 35_

Event

Description:

Large Break Loss of Coolant Accident EMG E-0 Attachment F, AUTOMATIC SIGNAL VERIFICATION Time Position Applicants Actions or Behavior RO/BOP F13. Verify AFW valves - PROPERLY ALIGNED:

a. Check ESFAS status panel AFAS section - ALL WHITE LIGHTS LIT

b. Check white train ESFAS status panel AFAS section - ALL WHITE LIGHTS LIT RO/BOP F14. Verify SI valves - PROPERLY ALIGNED

a. Check ESFAS status panel SIS section - SYSTEM LEVEL WHITE LIGHTS ALL LIT RO/BOP F15. Check if NCP should be stopped:

a. CCPs - ANY RUNNING

b. Stop NCP o BG HIS-3 RO/BOP F16. Return to procedure and step in effect.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 26 of 35_

Event

Description:

Large Break Loss of Coolant Accident EMG E-1, LOSS OF REACTOR OR SECONDARY COOLANT Time Position Applicants Actions or Behavior CRS ENTER and DIRECT EMG E-1, LOSS OF REACTOR OR SECONDARY COOLANT RO 1. Check if RCPs should be stopped:

a. Check RCPs - ANY RUNNING; No Perform RNO 1RNOa. Go to step 2 RO 2. Check if SGs are not faulted:

a. Check pressures in all SG -

o NO SG PRESSURE DECREASING IN AN UNCONTROLLED MANNER o NO SG COMPLETELY DEPRESSURIZED BOP 3. Check intact SG levels:

a. Check narrow range level in at least one SG - GREATER THAN 6%

[29%]; No, Perform RNO

b. Check feed flow to maintain narrow range level in all SGs between 6%

[29%] and 50%

3RNOa. Maintain total feed flow greater than 270,000 lbm/hr until narrow range level greater than 6% [29%] in at least one SG RO 4. Reset SI o SB HS-42A o SB HS-43A DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 27 of 35_

Event

Description:

Large Break Loss of Coolant Accident EMG E-1, LOSS OF REACTOR OR SECONDARY COOLANT Time Position Applicants Actions or Behavior RO/BOP 5. Reset Containment Isolation Phase A and Phase B o SB HS-56 for phase A o SB HS-53 for phase A o SB HS-55 for phase B o SB HS-52 for phase B RO/BOP 6. Determine Secondary radiation levels:

a. Direct HP to survey steamlines in Area 5 of Aux Bldg

b. Check SG sampling - ISOLATED

c. Ensure SI - RESET

d. Check INST AIR PRESS GREATER THAN 105 PSIG o KA PI-40

e. Open CCW to Radwaste System Isolation valves; No, Perform RNO o EG HS-69 o EG HS-70 6RNOe. Go to step 7 Booth cue: If called as Health Physics: acknowledge survey steam line request.

RO/BOP 7. Check Secondary radiation - NORMAL

a. Condenser air discharge radiation (GEG 925) - NORMAL BEFORE ISOLATION

b. SG blowdown radiation (BML 256) - NORMAL BEFORE ISOLATION

c. SG sample radiation (SJL 026 or sample results) - NORMAL

d. Turbine driven auxiliary feedwater pump exhaust radiation (FCT 381) -

NORMAL DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 28 of 35_

Event

Description:

Large Break Loss of Coolant Accident EMG E-1, LOSS OF REACTOR OR SECONDARY COOLANT Time Position Applicants Actions or Behavior RO/BOP Step 7 cont.

e. SG steam line radiation - NORMAL o ABS 114 for SG A o ABS 113 for SG B o ABS 112 for SG C o ABS 111 for SG D o Local surveys Booth cue: If called as Health Physics: acknowledge local survey request.

RO 8. Check PZR PORVs and Block valves:

a. Power to block valves - AVAILABLE o BB HIS-8000A o BB HIS-8000B

b. PZR PORVs - CLOSED o BB HIS-455A o BB HIS-456A

c. RCS pressure - LESS THAN 2135 PSIG DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 29 of 35_

Event

Description:

Large Break Loss of Coolant Accident EMG E-1, LOSS OF REACTOR OR SECONDARY COOLANT Time Position Applicants Actions or Behavior BOP 9. Verify Instrument Air alignment:

a. Ensure at least one ESW TRN TO AIR COMPRESSOR valve - OPEN EF HIS-43 EF HIS-44

b. Check AIR COMPRESSOR BRKR RESET switch associated with open ESW valve - CLOSED; if NO, Perform RNO KA HIS-2C KA HIS-3C 9RNOb Reset and close AIR COMPRESSOR BRKR RESET switch KA HIS-2C KA HIS-3C

c. Check INST AIR PRESS - GREATER THAN 105 PSIG o KA PI-40

d. Check PZR PRESS MASTER CTRL output - LESS THAN 50%

o BB PK-455A

e. Check neither ESW TO AIR COMPRESSOR valve - LOCALLY OPENED o EF HV-33 o EF HV-44

f. Open INST AIR SPLY CTMT ISO VLV o KA HIS-29 RO 10. Check if ECCS flow should be reduced:

a. RCS subcooling - GREATER THAN 30°F [45°F]

b. Secondary heat sink:

Total feed flow To intact SGs - GREATER THAN 270,000 LBM/HR Or DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 30 of 35_

Event

Description:

Large Break Loss of Coolant Accident EMG E-1, LOSS OF REACTOR OR SECONDARY COOLANT Time Position Applicants Actions or Behavior RO Step 10.cont Narrow range level in at least one intact SG - GREATER THAN 6%

c. RCS pressure - STABLE OR INCREASING; No, Perform RNO 10RNOc Go to step 11 RO 11. Check if Containment Spray should be stopped:

a. Check spray pumps - ANY RUNNING; No, Perform RNO 11RNOa. OBSERVE CAUTION PRIOR TO STEP 12 and go to step 12 RO 12. Check is RHR pumps should be stopped:

a. Check RNR pumps- ANY RUNNING

b. Check RCS pressure:

1) Pressure - GREATER THAN 325 PSIG; No, Perform RNO 12RNOb. Go to step 14 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 31 of 35_

Event

Description:

Large Break Loss of Coolant Accident EMG E-1, LOSS OF REACTOR OR SECONDARY COOLANT Time Position Applicants Actions or Behavior RO 14. Check if Diesel Generators should be stopped:

a. Check NB01 - ENERGIZED BY OFFSITE POWER

b. Depress START/RESET pushbutton for diesel generator NE01 o KJ HS-8A

c. Depress STOP pushbutton for diesel generator NE01 o KJ HS-8A

d. Check NB02 - ENERGIZED BY OFFSITE POWER

e. Depress START/RESET pushbutton for diesel generator NE02 o KJ HS-108A

f. Depress STOP pushbutton for diesel generator NE02 o KJ HS-108A

g. Place all previously running diesels in standby using SYS KJ-121, DIESEL GENERATOR NE01 AND NE02 LINEUP FOR AUTOMATIC OPERATION, while continuing with this procedure.

Booth: Respond as Building watch to place NE01 and NE02 in standby. Insert KEY 6 to place NE01 in standby.

Insert KEY 7 to place NE02 in standby. Report to Control Room when actions are completed.

Examiner NOTE: Refueling Water Storage Tank (RWST) level has been decreasing. Eventually Annunciator 00-047D, RWST LEV LOLO 1 AUTO XFR actuates. This ALR directs the transition to EMG ES-12, TRANSFER TO COLD LEG RECIRCULATION. The CRS may enter EMG ES-12 directly.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 32 of 35_

Event

Description:

Large Break Loss of Coolant Accident EMG ES-12, TRANSFER TO COLD LEG RECIRCULATION CT success: using EMG ES-12, steps 1 through 10, transfer to cold leg recirculation to establish ECCS Recirculation; EC HIS-12 failure to CLOSE during ES-12 performance is discovered Time Position Applicants Actions or Behavior CRS Refers to ALR 00-047D, RWST LEV LOLO 1 AUTO XFR

1. Check RWST level - LESS THAN 36%

o BN LI-930 o BN LI-931 o BN LI-932 o BN LI-933 CRS 2. Check EMGs - NOT IN EFFECT; No, Perform RNO

a. Initiate transfer to cold leg recirc as required by EMGs. Refer to EMG ES-12, TRANSFER TO COLD LEG RECIRCULATION.

b. Return to procedure and step in effect.

Examiner NOTE: No transition brief occurs. The CRS and a board operator perform EMG ES-12, TRANSFER TO COLD LEG RECIRCULATION. The remaining board operator monitors the plant.

CRS ENTER and DIRECT EMG ES-12, TRANSFER TO COLD LEG RECIRCULATION RO/BOP 1. Reset all SI signals:

o SB HS-42A for SIS o SB HS-43A for SIS o SB HIS-62 for RWST switchover o SB HIS-63 for RWST switchover DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 6 Page 33 of 35_

Event

Description:

Large Break Loss of Coolant Accident EMG ES-12, TRANSFER TO COLD LEG RECIRCULATION Event 6: EC HIS-12 failure to CLOSE during EMG ES-12 performance is discovered. SUCCESS:

depress CLOSE pushbutton EC HIS-12 Time Position Applicants Actions or Behavior RO/BOP 2. Verify CCW flow to RHR heat exchangers:

a. Check at least one Red train CCW pump - RUNNING CCW pump A or CCW pump C

b. Check at least one Yellow train CCW pump - RUNNING CCW pump B or CCW pump D

c. Ensure both CCW to RHR heat exchanger valves - OPEN o EG HIS-101 o EG HIS-102 RO/BOP 3. Ensure both CCW from Spent Fuel Pool heat exchangers - CLOSED o EC HIS CLOSED o EC HIS OPEN, depresses CLOSE pushbutton on EC HIS-12.

Red light extinguishes and Green light illuminates.

RO/BOP 4. Verify Red train RWST switchover has occurred:

a. Check Containment Recirc Sump to RHR pump A suction - OPEN o EJ HIS-8811A

b. Check RWST to RHR pump A suction - CLOSED o BN HIS-8812A RO/BOP 5. Verify Yellow train RWST switchover has occurred:

a. Check Containment Recirc Sump to RHR pump B suction - OPEN o EJ HIS-8811B

b. Check RWST to RHR pump B suction - CLOSED o BN HIS-8812B DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 34 of 35_

Event

Description:

Large Break Loss of Coolant Accident EMG ES-12, TRANSFER TO COLD LEG RECIRCULATION Time Position Applicants Actions or Behavior RO/BOP 6. Check RHR pumps - BOTH RUNNING; No, Perform RNO o EJ HIS-1 o EJ HIS-2 6RNO: Perform the following:

a. Manually start RHR pumps with suction aligned to the containment sump

b. If neither RHR pump can be started, then observe NOTE prior to step 11 and go to step 11.

Examiner NOTE: Recall from turnover EJ HIS-2 (RHR B) is the only pump available.

Booth cue: If called about RHR pump A clearance removal - acknowledge request.

RO/BOP 7. Close both RHR train hot leg recirc valves o EJ HIS-8716A o EJ HIS-8716B RO/BOP 8. Isolate SI pump miniflow to RWST:

a. Check each SI pump injection flow - GREATER THAN 220 GPM o EM FI-918 AND o EM FI-922

b. Close both SI pump recirc to RWST valves o EM HIS-8814A o EM HIS-8814B

c. Ensure SI pump miniflow - ISOLATED EM HIS-8814A and EM HIS-8814B - BOTH CLOSED or BN HIS-8813 - CLOSED DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 1 Event No.: 4 Page 35 of 35_

Event

Description:

Large Break Loss of Coolant Accident EMG ES-12, TRANSFER TO COLD LEG RECIRCULATION Time Position Applicants Actions or Behavior RO/BOP 9. Align CCP and SI pump suctions to RHR pump discharge:

a. Open both RHR to CCP and SI pump suction valves o EJ HIS-8804A, RHR to Charging pumps o EJ HIS-8804B, RHR to SI pump B suction

b. Open both CVCS to SI pump suction valves o EM HIS-8807A o EM HIS-8807B RO/BOP 10. Isolate RWST from Charging and SI pumps

a. Close both RWST to SI pump suction valves o BN HIS-8806A o BN HIS-8806B

b. Close both CCP suction from RWST valves o BN HIS-112D o BN HIS-112E At the completion of step 10, the last critical task is completed. The scenario may be terminated at the discretion of the Lead Examiner.

Booth operator Freeze simulator at direction of Lead Examiner.

DRAFT

Appendix D Scenario Outline Form ES-D-1 Facility: _________Wolf Creek_________ Scenario No.: ____2____ Op-Test No.: _______

Examiners: ____________________________ Operators: _____________________________

Initial Conditions: Middle Of Life, ~74%

Turnover: Monitor MFP B vibration. Started the downpower and are currently on HOLD at ~74%

waiting an Engineering Evaluation. Annunciator 00-058B, VCT VLV NOT IN VCT POS, due to recent 200-gallon dilution to hold power. Diluting ~100 gallons every 10-15 minutes. No equipment is out of service.

Event Malf. Event Event No. No. Type* Description 1 mBB01E I - ATC, Loop A, BB TI-411, Tcold fails high SRO TS determined and entered. TS 3.3.1, Table 3.3.1-1, Fu 6 and 7, Cond A (Immediately) and Cond E (72 hrs to trip bistables) 2 mAE15C I - BOP, Steam Generator C controlling level channel AE LI-553 failure 4 SRO high TS determined and entered. TS 3.3.1, Table 3.3.1-1, Fu 14, Cond A (Immediately) and Cond E (72 hrs to trip bistables)

TS 3.3.2, Table 3.3.2-1, Fu 5.c and 6.d, Cond A (Immediately),

Cond I (72 hrs to trip bistable) and Cond D (72 hrs to trip bistable) 3 msovBB C- PORV BB PCV-455A fails to 0.25% open due to control circuitry PCV455 ATC, problems, PZR pressure begins to decrease A SRO TS determined and entered. TS 3.4.11 Cond. B.1 (1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> close seal valve) and B.2 (1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to de-energize seal valve) and B.3 (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to repair PORV) 4 mAB03A M- Steam line break inside Containment (Steam Generator A)

CREW Adverse Containment 5 mSNF01 C- Malfunction post Reactor Trip and Safety Injection: LOCA A ATC, Sequencer A failure at five second time.

SRO 6 mNF01A C- Malfunction post Reactor Trip and Safety Injection: Main Generator BOP, and Exciter breakers fail to automatically trip.

SRO

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor DRAFT 1 of 4

Scenario Summary:

The unit is at ~74% power, middle of life. Monitor MFP B vibration. Started the downpower and are currently on HOLD at ~74% waiting an Engineering Evaluation. Annunciator 00-058B, VCT VLV NOT IN VCT POS, due to recent 200-gallon dilution to hold power. Diluting ~100 gallons every 10-15 minutes. No equipment is out of service.

Event 1: RCS Loop A BB TI-411 Tcold fails high. Meter indication changes and the Control Rods insert - the Reactor Operator (RO) places control rods in MANUAL, stopping the insertion.

Many Main Control Board alarms annunciate: 00-065C, 00-065E, 00-066B, 00-067D, 00-068D, 00-069D, 00-082B and 00-083C. OFN SB-008, INSTRUMENT MALFUNCTIONS, is entered and Attachment L performed. This procedure will diagnose and mitigate the instrument failure.

The Control Room Supervisor determines Technical Specifications.

Event 2: Steam Generator C controlling level channel AE LI-553 fails high. Meter indications change and Main Control Board alarms, 00-110A, SG C LEV HI/LO and 00-110B, SG C LEV DEV, annunciate. ALR 00-110A, SG C LEV HI/LO, or 00-110B, SG C LEV DEV, may be entered and performed. OFN SB-008, INSTRUMENT MALFUNCTIONS, is entered and Attachment F is performed. These procedures diagnose and mitigate the instrument failure.

The Control Room Supervisor determines Technical Specifications.

Event 3: Pressurizer Pilot Operated Relief Valve (PORV) BB PCV-455A fails to 0.25% open due to control circuitry problems. Diagnostic parameters include dual indication on hand indicating switch BB HIS-455A, and alarms 00-035B, PORV OPEN, 00-035C, PZR SFTY DISCH TEMP HI, 00-035D, PZR PORV DISCH TEMP HI, 00-034E, PRT PRESS HI annunciating. ALR 00-035B may be entered and performed to close the PZR Seal Iso Valve using BB HIS-8000A. This action mitigates the event.

The Control Room Supervisor determines Technical Specifications.

Event 4: The Main Event is a Steam line break inside Containment (Steam Generator A).

Diagnostic parameters include Secondary steam flow to feed flow meters mismatch, increasing SG steam flow, Containment pressure and humidity while it decreases Main Turbine load and RCS pressure and temperature. OFN AB-041, STEAMLINE OR FEEDLINE LEAK may be entered. A Reactor trip and Safety Injection occurs. EMG E-0, REACTOR TRIP OR SAFETY INJECTION, is entered and performed. The faulted SG is identified and isolated (EMG E-0 foldout page criteria). Adverse Containment is identified and setpoints for various parameters are used. The Crew transitions to EMG E-2, FAULTED STEAM GENERATOR ISOLATION.

Eventually the Crew transitions to EMG ES-03, SI TERMINATION, to mitigate PZR overfill and RCS high pressure.

Post trip malfunctions:

1. Event 5: LOCA Sequencer A failure at five second time interval frame. This component failure requires the Crew to start ECCS equipment per EMG E-0 Attachment F.

2. Event 6: Main Generator and Exciter breakers fail to automatically trip. This component failure requires the BOP to permit MA HS-5, SWYD 345-50/60 MAN TRIP PERMIT switch, BEFORE opening the breakers per EMG step 6RNO. (NOTE: MA HS-5, SWYD 345-50/60 MAN TRIP PERMIT is a new switch added to Panel RL005 during Refuel 18).

DRAFT 2 of 4

Scenario Critical Tasks (CT)

Event 1: CT - place rods to manual prior to actuation of the Reactor Protection System Event 2 - CT - take manual control, select alternate controlling channel prior to actuation of the Reactor Protection System Event 4 - CT - isolate the faulted Steam Generator before an Orange path integrity challenge develops DRAFT 3 of 4

Probabilistic Risk Analysis for this scenario includes:

Core Damage Frequency by Initiating Event Initiating Event Core Damage CDF Percent Initiating Event Frequency (/yr) Frequency (/yr) Contribution Loss of Offsite Power 2.88E-02 6.59E-06 36.51%

Small LOCA 29.63%

3.00E-03 5.35E-06 Interfacing Systems LOCA 1.93E-06 10.69%

Very Small LOCA 7.03%

6.20E-03 1.27E-06 Transients With Power Conversion Systems Available 1.05E+00 9.88E-07 5.47%

Steam Generator Tube Rupture 3.67E-03 8.77E-07 4.86%

Reactor Vessel Failure 3.00E-07 3.00E-07 1.66%

Steamline Break 1.13E-02 1.88E-07 1.04%

Transients Without Power Conversion 1.15E-01 1.71E-07 0.95%

Systems Available Medium LOCA 6.10E-05 1.46E-07 0.81%

Loss of All Service Water 6.86E-06 8.30E-08 0.46%

Loss of Component Cooling Water 2.14E-04 5.79E-08 0.32%

Loss of Vital DC Bus NK04 2.64E-03 4.32E-08 0.24%

Large LOCA 7.20E-06 2.80E-08 0.16%

Feedwater Line Break 3.17E-03 2.06E-08 0.11%

Loss of Vital DC Bus NK01 2.64E-03 1.12E-08 0.06%

Technical Specifications exercised:

Event 1 - TS determined and entered. TS 3.3.1, Table 3.3.1-1, Fu 6 and 7, Cond A (Immediately) and Cond E (72 hrs to trip bistables)

Event 2 - TS determined and entered. TS 3.3.1, Table 3.3.1-1, Fu 14, Cond A (Immediately) and Cond E (72 hrs to trip bistables)

TS 3.3.2, Table 3.3.2-1, Fu 5.c and 6.d, Cond A (Immediately), Cond I (72 hrs to trip bistable) and Cond D (72 hrs to trip bistable)

Event 3 - TS determined and entered. TS 3.4.11 Cond. B.1 (1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> close seal valve) and B.2 (1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to de-energize seal valve) and B.3 (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to repair PORV)

DRAFT 4 of 4

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 1 Page 1 of 30_

Event

Description:

Loop A, BB TI-411, Tcold fails high CT success - place rods to manual prior to actuation of the Reactor Protection System Time Position Applicants Actions or Behavior BOOTH: Set up scenario and simulator. At Lead Examiner cue, insert KEY 1 for first event.

Diagnostics: RCS Loop A, BB TI-411, Tcold fails high. Meter BB TI-411A, T fails low, BB TI-412, Tavg, fails high. Control Rods insert. Main Control Board alarms include: 00-065C, 00-065E, 00-066B, 00-067D, 00-068D and 00-069D annunciate.

CREW Identifies and diagnoses Loop A, BB TI-411, Tcold fails high.

CRS ENTER and DIRECT OFN SB-008, INSTRUMENT MALFUNCTIONS Procedure NOTE: Steps 1 through 8 can be performed in any order.

CRS, RO 2. Check if reactor coolant system instrument channel or controller is malfunctioning

a. Determine appropriate attachment for malfunction channel or controller from table below:

RCS Temperature (BB) T-411 Attachment L

b. Go to appropriate attachment for malfunctioning reactor coolant system channel or controller.

CRS, RO OFN SB-008, Attachment L, NARROW RANGE RTD MALFUNCTION Procedure NOTE: Steps L1 through L2 are Memory Action steps BOP L1. Check load rejection - NOT ON PROGRESS o Generator Load MW - STABLE o Generator Load SET MW - STABLE RO L2. Switch ROD BANK AUTO/MAN SEL switch to - MANUAL (CT) o SE HS-9 CT success - place rods to manual prior to actuation of the Reactor Protection System

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 1 Page 2 of 30_

Event

Description:

Loop A, BB TI-411, Tcold fails high Time Position Applicants Actions or Behavior BOP L3. Check steam dumps:

a. Check STEAM DUMP SEL switch - IN TAVG MODE (AB US-500Z)

b. Check steam dumps - CLOSED RO L4. Identify failed instrument channel:

Loop 1 Function Indication 1 T BB TI-411A Tavg BB TI-412 RO L5. Remove failed temperature channel from Tavg and T auctioneering circuits, using DELTA T DEFEAT and ROD CTRL TAVG INPUT CHANNEL DEFEAT switches:

o BB TS-411F o BB TS-412T RO L6. Check (Tavg/Tref) error signal within 1°F; if No, Perform RNO L6RNO. () Manually adjust control rod position to maintain Tavg within 1°F of Tref NOTE Two of procedure: Control Rods should be restored to their parked position when plant conditions allow at the discretion of the CRS.

Examiner NOTE: The CRS may elect to restore control rods to their previous position before directing ROD BANK AUTO/MAN SEL switch to AUTO in step L7.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 1 Page 3 of 30_

Event

Description:

Loop A, BB TI-411, Tcold fails high Time Position Applicants Actions or Behavior RO L7. Check ROD BANK AUTO/MAN SEL switch in AUTO; No, Perform RNO o SE HS-9 L7RNO () When Tavg is within 1°F of Tref, then place ROD BANK AUTO/MAN SEL switch in AUTO RO L8. Monitor Rod Control System response to ensure proper control BOP L9. Check C-7 Loss of Load interlock - NOT LIT BOP L10. Check STEAM DUMP BYPASS INTERLOCK switches in - ON o AB HS-63 o AB HS-64 BOP L11. Monitor Steam Dump Control System to ensure proper operation RO L12. Check failed temperature channel not selected on OP DT/OT DT LOOP RECORD SEL; if No, Perform RNO o SC TS-411E L12RNO. Select alternate temperature channel for input to recorder.

CRS Monitor the following Technical Specification LCOs and comply with Action Statements, as appropriate:

o 3.3.1, RTS INSTRUMENTATION, Table 3.3.1-1, Fu 6 and 7 CRS determines TS: TS 3.3.1, Table 3.3.1-1, Fu 6 and 7, Cond A (Immediately) and Cond E (72 hrs to trip bistables)

Booth cues: If contacted as Call Supt.: acknowledge plant status. If contacted as INC: acknowledge request.

Event termination: When Technical Specifications are determined and/or at Lead Examiners discretion, event is terminated. Booth operator inserts KEY 2 for event two at Lead Examiners discretion.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 2 Page 4 of 30_

Event

Description:

Steam Generator C controlling level channel AE LI-553 failure high CT success - take manual control, select alternate controlling channel prior to actuation of the Reactor Protection System Time Position Applicants Actions or Behavior Booth operator inserts KEY 2 for event two at Lead Examiners discretion.

Diagnostics: Steam Generator C controlling level channel AE LI-553 fails high. Meter SG C LEV AE LI-553 fails high. MFRV for Steam Generator C begins to close. Main Control Board alarms 00-110A, SG C LEV HI/LO, 00-110B, SG C LEV DEV and 00-110C SG FLOW MISMATCH annunciate.

CREW Identifies and diagnoses Steam Generator C controlling level channel AE LI-553 failure high CRS May ENTER and DIRECT ALR 00-110A SG C LEV HI/LO Procedure NOTE: Steps 1 through 3 are Memory Action Steps BOP 1. Check SG C controlling level channel:

Less than 30% or Greater than 70%

BOP 2. Check for instrument failure

a. Check SG C controlling level channel - WITHIN 7% OF REMAINING SG C LEVEL CHANNELS; No, Perform RNO AE LI-539 AE LI-553 2RNO: Perform the following:

1. Place Feedwater Reg Valve (FRV) in MANUAL (CT - perform 2RNO1)

AE FK-530

2. Adjust FRV, as necessary, to establish SG level at program value (CT -

perform 2RNO2)

AE FK-530

3. Select alternate channel for control (CT - perform 2RNO3) o AE LS-539C Examiner NOTE: BOP selects L539 using switch AE LS-539C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 2 Page 5 of 30_

Event

Description:

Steam Generator C controlling level channel AE LI-553 failure high CT success - take manual control, select alternate controlling channel prior to actuation of the Reactor Protection System Time Position Applicants Actions or Behavior BOP Step 2RNO cont

4. Return FRV to AUTOMATIC AE FK-530

5. Go to OFN SB-008, INSTRUMENT MALFUNCTIONS CT success - take manual control, select alternate controlling channel prior to actuation of the Reactor Protection System Examiner NOTE: BOP actions include taking FRV to manual and adjusting FRV to match steam flow and feed flow - Selecting an alternate channel will occur at the procedure step by direction of CRS.

CRS ENTER and DIRECT OFN SB-008, INSTRUMENT MALFUNCTIONS Procedure NOTE: Steps 1 through 8 can be performed in any order.

CRS 1. Check if secondary system instrument channel is malfunctioning:

a. Determine appropriate attachment for malfunctioning channel from table below: Attachment C is determined and entered SG Level (AE) Control Channel L-553 Attachment F

b. Go to appropriate attachment for malfunctioning secondary system channel.

Examiner NOTE: If ALR 110A is entered first, the procedure flowpath in OFN SB-008 is different than if OFN SB-008 is entered first. All the OFN SB-008 Attachment F procedure steps are included regardless of which procedure is entered first.

CRS OFN SB-008, Attachment F, SG LEVEL CHANNEL MALFUNCTION Procedure NOTE: Steps F1 through F4 are Memory Action steps.

BOP F1. Identify failed narrow range SG level instrument channel:

a. Compare narrow range SG level indications to confirm a narrow range SG level channel failure:

Examiner NOTE: See next page for Table.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 2 Page 6 of 30_

Event

Description:

Steam Generator C controlling level channel AE LI-553 failure high CT success - take manual control, select alternate controlling channel prior to actuation of the Reactor Protection System Time Position Applicants Actions or Behavior BOP Step F1 cont.

SG INDICATION FUNCTION C AE LI-537 Indication AE LI-538 Indication AE LI-549 Control AE LI-553 Control BOP F2. Check failed SG level channel selected on SG LEV CHANNEL SEL switch; if NO, Perform RNO AE LS-539C F2RNO: Go to step 7 Examiner NOTE: RNO (Go to step 7) is used if ALR 110A entered first.

BOP F3. Place affected SG MFW REG VLV CTRL - IN MANUAL (CT - perform F3)

AE FK-540 BOP F4. Adjust affected SG MFW REG VLV CTRL, as necessary, to establish Steam generator level at program: (CT - perform F4)

AE FK-540 BOP F5. Select alternate SG level channel on SG LEV CHANNEL SEL switch: (CT -

perform F5)

AE LS-539C Examiner NOTE: BOP selects L539 using switch AE LS-539C CT success - take manual control, select alternate controlling channel prior to actuation of the Reactor Protection System BOP F6. Restore affected SG MFW REG VLV CTRL to - AUTO (AE FK-540)

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 2 Page 7 of 30_

Event

Description:

Steam Generator C controlling level channel AE LI-553 failure high Time Position Applicants Actions or Behavior CRS F7. Monitor the following Technical Specifications for LCOs and comply with Action Statements, as appropriate:

o 3.3.1, RTS INSTRUMENTATION, Table 3.3.1-1, Fu 14 o 3.3.2, ESFAS INSTRUMENTATION, Table 3.3.2-1, Fu 5.c and 6.d o 3.3.4, REMOTE SHUTDOWN INSTRUMENTATION, Table 3.3.4-1, Fu 8 o 3.3.3, ACCIDENT MONITORING INSTRUMENTATION, Fu 13 CRS determines: TS 3.3.1, Table 3.3.1-1, Fu 14, Cond A (Immediately) and Cond E (72 hrs to trip bistables)

TS 3.3.2, Table 3.3.2-1, Fu 5.c and 6.d, Cond A (Immediately), Cond I (72 hrs to trip bistable) and Cond D (72 hrs to trip bistable)

Booth cues: If contacted as Call Supt.: acknowledge plant status. If contacted as INC: acknowledge request.

Event termination: When Technical Specifications are determined and/or at Lead Examiners discretion, event is terminated.

Booth operator inserts KEY 3 for event 3 at Lead Examiners discretion.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 3 Page 8 of 30_

Event

Description:

PORV BB PCV-455A fails to 0.25% open due to control circuitry problems, PZR pressure begins to decrease Time Position Applicants Actions or Behavior Booth operator inserts KEY 3 for event 3 at Lead Examiners discretion.

Diagnostics: RCS pressure decreases. Dual indication on hand indicating switch BB HIS-455A. Main Control Board alarms 00-035B, PORV OPEN, 00-035C, PZR SFTY DISCH TEMP HI, 00-035D, PZR PORV DISCH TEMP HI, 00-034C, PZR PORV BLOCK and 00-034E, PRT PRESS HI annunciate CREW Identifies and diagnoses PORV BB PCV-455A has dual indication and is OPEN.

CRS ENTER and DIRECT ALR 00-035B, PORV OPEN Procedure NOTE: Step 1 is a Memory Action step RO 1. Check if PZR PORVs should be closed when NOT in Cold Overpressure Protection:

a. Check Cold Overpressure System - NOT IN SERVICE o BLOCK/ARM switches in BLOCK o BB HS-8000A o BB HS-8000B

b. Check PZR pressure - LESS THAN 2310 PSIG

c. Close affected PZR PORVs; if NO, Perform RNO BB HIS-455A BB HIS-456A 1RNOc: If affected PORV(s) will not closed, then close associated PORV block valve.

BB HIS-8000A for BB HV-455A BB HIS-8000B for BB HV-456A Examiner NOTE: BB HIS-455A is ISOLATED by board operator action.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 3 Page 9 of 30_

Event

Description:

PORV BB PCV-455A fails to 0.25% open due to control circuitry problems, PZR pressure begins to decrease Time Position Applicants Actions or Behavior CRS 2. Check if PZR PORVs should be closed when in Cold Overpressure Protection:

a. Check Cold Overpressure protection - IN SERVICE; No, Perform RNO 2RNOa. Go to step 3 RO 3. Verify PZR PORVs - AT LEAST ONE OPENED

a. Check PZR PORV discharge temperature - GREATER THAN NORMAL o BB TI-463 CRS 4. Refer to Technical Specifications 3.4.11 and 3.4.12 CRS determines TS: TS 3.4.11 Cond. B.1 (1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> close seal valve) and B.2 (1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to de-energize seal valve) and B.3 (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to repair PORV)

EXAMINER note: NG01BBR3 is the breaker to de-energize the Block valve (BB HV-8000A).

Booth cues: If contacted as Building Watch to remove power from Block valve, acknowledge request, insert KEY 5 and report to Control Room when action complete. NG01BBR3 is the breaker to de-energize the Block valve (BB HV-8000A).

Booth cues: If contacted as Shift Manager or Call Supt.: acknowledge plant status. If contacted as INC:

acknowledge request. If contacted as Maintenance, acknowledge request.

Event termination: When Technical Specifications are determined and/or at Lead Examiners discretion, event is terminated. Booth operator inserts KEY 4 for event four at Lead Examiners discretion.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 4 Page 10 of 30_

Event

Description:

Steam line break inside Containment (Steam Generator A)

Time Position Applicants Actions or Behavior Booth operator inserts KEY 4 for event four at Lead Examiners discretion.

Diagnostics for Steam Line break inside Containment: Secondary steam flow to feed flow meters mismatch, increasing SG steam flow, increasing Containment pressure and humidity. Main Turbine load decreases and RCS pressure and temperature decreasing.

CREW Identify and diagnose a secondary coolant failure - steam line break inside Containment CRS May ENTER and DIRECT OFN AB-041, STEAMLINE OR FEEDLINE LEAK CRS Based on plant conditions, DIRECT a Reactor Trip and Safety Injection Signal actuation, and DIRECT performance of Immediate Actions per EMG E-0, REACTOR TRIP OR SAFETY INJECTION Examiner NOTE: an automatic Reactor trip and Safety Injection may occur.

RO Perform Reactor Trip and Safety Injection Signal actuation at direction of CRS using o SB HS-1, REACTOR TRIP MAN ACTUATION to TRIP position o SB HS-27, SI MAN ACTUATION to ACTUATE position o SB HS-28, SI MAN ACTUATION to ACTUATE position RO, BOP Perform Immediate Actions of EMG E-0, REACTOR TRIP OR SAFETY INJECTION and report results to CRS Examiner NOTE: Steps 1-4 are Immediate Action steps performed from memory.

Usually the RO performs steps 1, 3 and 4, the while BOP performs step 2.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 4 Page 11 of 30_

Event

Description:

Steam line break inside Containment Time Position Applicants Actions or Behavior CRS, RO The RO reports many ECCS equipment did not start from the LOCA sequencer.

CRS directs that the equipment will be started using Attachment F of EMG E-0.

Examiner NOTE: The CRS may direct the RO to start ESW and /or CCW pumps now, then use Attachment F for the remaining equipment.

CRS, BOP The BOP reports Main Generator and Exciter Breaker did not trip. CRS directs that the equipment will be placed in its correct state using EMG E-0.

RO 1. Verify Reactor trip

a. Check rod bottom lights - LIT

b. Ensure reactor trip breakers and bypass breakers - OPEN o SB ZL-1 o SB ZL-2 o SB ZL-3 o SB ZL-4

c. Check intermediate range neutron flux - DECREASING o SE NI-35B [GAMMA METRICS]

o SE NI-36B [GAMMA METRICS]

BOP 2. Verify turbine trip

a. Check the following:

Main Stop valves - ALL CLOSED OR Turbine Auto Stop bistable lights - AT LEAST TWO LIT RO 3. Check AC Emergency Busses - AT LEAST ONE ENERGIZED NB01 - ENERGIZED NB02 - ENERGIZED

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 4 Page 12 of 30_

Event

Description:

Steam line break inside Containment CT success - isolate the faulted Steam Generator before an Orange path integrity challenge develops Time Position Applicants Actions or Behavior RO 4. Check if Safety Injection is actuated:

a. Check any indication SI is actuated - LIT Annun. 00-030A NF039A LOCA SEQ ACTUATED - LIT Annun. 00-031A NF039B LOCA SEQ ACTUATED - LIT ESFAS status panel SIS section - ANY WHITE LIGHTS LIT Partial trip status Permissive/Block status panel - SI RED LIGHT LIT

b. Check both trains of SI actuated o Ann 00-030A NF039A LOCA SEQ ACTUATED - LIT o Ann 00-031A NF039B LOCA SEQ ACTUATED - LIT CREW Identified SG A as the faulted Steam Generator.

CRS, BOP EMG E-0 Foldout Page Criteria #3, FAULTED SG ISOLATION CRITERIA: If any SG pressure decreasing in an uncontrolled manner OR any SG completely depressurized, then the following may be performed:

a. Close main steam isolation valves

b. Isolate feed flow to faulted SG(s)

c. Maintain total feed flow greater than 270,000 lbm/hr until narrow range level in at least one SG is greater than 6% [29%]

CT success- isolate the faulted Steam Generator before an Orange path integrity challenge develops

a. Depresses AB HS-79, MS ISO VLVS and AB HS-80, MS ISO VLVS (ALL CLOSE) (CT action by BOP)

b. Takes AL HK-8A, SG A TD AFP AFW REG VLV CTRL and AL HK-7A, SG A MD AFP AFW REG VLV CTRL to zero output. Flow meter AL FI-2A, AFW TO SG A FLOW, decreases to zero. (CT action by BOP)

c. May adjust SG B, C and D MD and TD AFW REG VLV controllers to maintain a total feed flow greater than 270,000 lbm/hr until narrow range level in at least one SG is greater than 6% [29%]

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 6 Page 13 of 30_

Event

Description:

Steam line break inside Containment Event 6: Main Generator and Exciter breakers fail to automatically trip. Success: EMG E-0 step 6RNO Time Position Applicants Actions or Behavior RO 5. Check if SI is required:

SI was manually actuated AND was required RCS pressure is currently or has been - LESS THAN OR EQUAL TO 1830 PSIG Any SG press is currently or has been - LESS THAN OR EQUAL TO 615 PSIG Containment press is currently or has been - GREATER THAN OR EQUAL TO 3.5 PSIG RCS subcooling is currently or has been - LESS THAN 30°F [45°F]

PZR level is currently or has been - LESS THAN 6% [33%]

BOP 6. Check Main Generator Breakers and Exciter Breaker - OPEN; No, Perform RNO o MA ZL-3A o MA ZL-4A o MB ZL-2 RNO Step 6: When time since turbine trip is greater than 30 seconds and all steam is secured to the turbine then perform the following:

a. Place SWYD 345-50/60 MAN TRIP PERMIT switch to PERMIT o MA HS-5

b. Open main generator and exciter breakers

1) MA HS-3

2) MA HS-4

3) MA HS-2 RO/BOP 7. Verify Automatic Actions using Attachment F, AUTOMATIC SIGNAL VERIFICATION Examiner NOTE: Attachment F procedure steps see page 18

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 4 Page 14 of 30_

Event

Description:

Steam line break inside Containment Time Position Applicants Actions or Behavior BOP 8. Check total AFW flow - >270,000 lbm/hr BOP 9. Check RCS cold leg temperatures Stable at or trending to 557°F for condenser steam dumps Stable at or trending to 561°F for SG ARVs; No, perform RNO 9RNO:

a. If temperature is less than setpoint and decreasing, then perform the following:

1) Stop dumping steam

2) If any MSIV is open, then close Main Turbine Stop and Control Valves Startup Drains.

o AC HIS-134

3) If cooldown continues, then control total feed flow to limit RCS cooldown. Maintain total feed flow > 270,000 lbm/hr until narrow range level greater than 6% [29%] in at least one SG.

4) If cooldown continues due to excessive steam flow, then isolate main steamlines by depressing both MS ISO VLV ALL CLOSE pushbuttons o AB HS-79 o AB HS-80

b. If temperature is greater than setpoint and increasing, then perform one of the following:

Dump stem to condenser Dump steam using SG ARVs

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 4 Page 15 of 30_

Event

Description:

Steam line break inside Containment Time Position Applicants Actions or Behavior BOP 10. Establish SG pressure control

a. Check condenser - AVAILABLE; No Perform RNO o C-9 LIT o MSIV - OPEN; NO o Circulating water pumps - RUNNING 10RNOa. Perform the following

1) Use the SG ARVs

2) Go to step 11 RO 11. Check PZR PORVs

a. Check PZR PORVs - CLOSED o BB HIS-455A (recall dual indication, Block valve is closed) o BB HIS-456A

b. Power to block valves - AVAILABLE

i. BB HIS-8000A ii. BB HIS-8000B

c. RCS pressure - LESS THAN 2185 PSIG Examiner NOTE: If power was removed from Block valve BB HV-8000A, the CRS may request that the power be restored per Step 11 RNO Restore power to block valves.

Booth: If contacted as Building Watch to restore power to de-energized Block valve, acknowledge request, delete the remote (see Key 5) and report to Control Room when action complete.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 4 Page 16 of 30_

Event

Description:

Steam line break inside Containment Time Position Applicants Actions or Behavior RO 12. Check normal PZR Spray valves - CLOSED o BB ZL-455B o BB ZL-455C RO 13. Check PZR Safety valves - CLOSED o BB ZL-8010A o BB ZL-8010B o BB ZL-8010C RO 14. Check if RCPs should be stopped:

a. Check RCPs - ANY RUNNING

b. Check RCS pressure - LESS THAN 1400 PSIG; No, Perform RNO 14RNOb. Go to step 15 CRS 15. Direct Operator to monitor Critical Safety Functions using EMG F-0, CRITICAL SAFETY FUNCTION STATUS TREES (CSFST).

Examiner NOTE: Surrogate STA performs this activity and reports results to the CRS.

RO 16. Check if SGs are not faulted:; No, Perform RNO, SG A is Faulted

a. Check pressures in all SG -

o NO SG PRESSURE DECREASING IN AN UNCONTROLLED MANNER o NO SG COMPLETELY DEPRESSURIZED No, Perform RNO - see next page

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 4 Page 17 of 30_

Event

Description:

Steam line break inside Containment Time Position Applicants Actions or Behavior RO 16RNO cont.

a. Perform the following:

1) Ensure BIT inlet and outlet valves are OPEN o EM HIS-8803A o EM HIS-8803B o EM HIS-8801A o EM HIS-8801B

2) Go to EMG E-2, FAULTED STEAM GENERATOR ISOLATION, step 11 CRS LEAD a transition brief prior to directing actions of EMG E-2.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 5 Page 18 of 30_

Event

Description:

LOCA Sequencer A failure at five second time interval frame EMG E-0 Attachment F, AUTOMATIC SIGNAL VERIFICATION Time Position Applicants Actions or Behavior RO/BOP F1. Verify Feedwater Isolation

a. Main feedwater pumps - TRIPPED

b. Main feedwater reg valves - CLOSED

b. Main feedwater reg bypass valves - CLOSED

c. Main feedwater isolation valves - CLOSED

d. Main feedwater chemical injection valves - CLOSED

e. Check ESFAS status panel SGBSIS section - ALL WHITE LIGHTS LIT RO/BOP F2. Verify Containment Isolation Phase A

a. a. Check ESFAS status panel CISA section - ALL WHITE LIGHTS LIT RO/BOP F3. Verify AFW pumps running:

a. Check motor driven AFW pumps - BOTH RUNNING; No, Perform RNO

b. Check turbine driven AFW pump - RUNNING F3RNOa. Manually start pumps.

o AL HIS-22A (start MD AFP A)

RO/BOP F4. Verify ECCS pumps running

a. Check CCPs - BOTH RUNNING

b. Check SI pumps- BOTH RUNNING

c. Check RHR pumps - BOTH RUNNING; No - Perform RNO F4RNOc: Manually start pump o EJ HIS-1 (RHR PUMP A)

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 5 Page 19 of 30_

Event

Description:

LOCA Sequencer A failure at five second time interval frame EMG E-0 Attachment F, AUTOMATIC SIGNAL VERIFICATION Time Position Applicants Actions or Behavior RO/BOP F5. Verify CCW alignment:

a. Check CCW pumps - ONE RUNNING IN EACH TRAIN

b. Check one pair of CCW service loop Supply and Return valves for an operating CCW pump - OPEN RO/BOP F6. Check ESW pumps - BOTH RUNNING; No, Perform RNO F6RNOa. Manually start pumps.

o EF HIS-55A (ESW PUMP A)

Examiner NOTE: A ESW pump may have been started at the direction of the CRS once the Immediate Actions of EMG E-0 were complete.

RO/BOP F7. Check Containment Fan Coolers - RUNNING IN SLOW SPEED; No, Perform RNO F7RNO Perform the following

a. Place Containment Cooler Fan speed selector switches in SLOW (only Red train listed) o GN HS-5 for cooler 1A o GN HS-13 for cooler 1C

b. Manually start Containment Cooler Fans.

o GN HIS-5 for cooler 1A o GN HIS-13 for cooer 1C

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 5 Page 20 of 30_

Event

Description:

LOCA Sequencer A failure at five second time interval frame EMG E-0 Attachment F, AUTOMATIC SIGNAL VERIFICATION Time Position Applicants Actions or Behavior RO/BOP F8. Verify Containment Purge Isolation:

a. Check ESFAS status panel CPIS section - ALL WHITE LIGHTS LIT RO/BOP F9. Verify both trains of Control Room Ventilation Isolation:

a. Check ESFAS status panel CRVIS section - ALL WHITE LIGHTS LIT

b. Ensure Control Room outer door - CLOSED RO/BOP F10. Verify Main Steamline Isolation not required:

a. Check Containment pressure - HAS REMAINED LESS THAN 17 PSIG (GN PR-934)

b. Check either condition below - SATISFIED Low steamline pressure SI - NOT BLOCKED AND steamline pressure -

HAS REMAINED GREATER THAN 615 PSIG or Low steamline pressure SI - NOT BLOCKED AND steamline pressure -

HAS REMAINED LESS THAN 100 PSI/50 SEC RO/BOP F11. Verify Containment Spray not required:

a. Containment pressure - HAS REMAINED LESS THAN 27 PSIG; No, Perform RNO o Ann 00-059A, CSAS - NOT LIT o Ann 00-059B, CISB - NOT LIT o GN PR-934 F11RNO: Perform the following:

1. Stop all RCPs

2. If Containment Spray has NOT actuated, then manually actuate Containment Spray

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 5 Page 21 of 30_

Event

Description:

LOCA Sequencer A failure at five second time interval frame EMG E-0 Attachment F, AUTOMATIC SIGNAL VERIFICATION Time Position Applicants Actions or Behavior RO/BOP F11 RNO cont.

3. Check ESFAS status panel CSAS section - ALL WHITE LIGHTS LIT

4. If any CSAS component NOT properly aligned, then manually align associated component

5. Check ESFAS status panel CISB section - ALL WHITE LIGHTS LIT

6. If any CISB valve not closed, then manually close valve. If valve(s) can not be closed, then manually or locally isolate affected Containment penetration. Refer to ATTACHMENT E, VALVES CLOSED BY CONTAINMENT ISOLATION SIGNAL PHASE B RO/BOP F12. Verify ECCS flow:

a. Check CCP to BIT flow meters - FLOW INDICATED

b. Check RCS pressure - LESS THAN 1700 PSIG; No, Perform RNO F12RNOb. Go to step F13 RO/BOP F13. Verify AFW valves - PROPERLY ALIGNED:

a. Check ESFAS status panel AFAS section - ALL WHITE LIGHTS LIT

b. Check white train ESFAS status panel AFAS section - ALL WHITE LIGHTS LIT RO/BOP F14. Verify SI valves - PROPERLY ALIGNED

a. Check ESFAS status panel SIS section - SYSTEM LEVEL WHITE LIGHTS ALL LIT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 5 Page 22 of 30_

Event

Description:

LOCA Sequencer A failure at five second time interval frame EMG E-0 Attachment F, AUTOMATIC SIGNAL VERIFICATION Time Position Applicants Actions or Behavior RO/BOP F15. Check if NCP should be stopped:

a. CCPs - ANY RUNNING

b. Stop NCP o BG HIS-3 RO/BOP F16. Return to procedure and step in effect.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 4 Page 23 of 30_

Event

Description:

Steam line break inside Containment EMG E-2 FAULTED STEAM GENERATOR ISOLATION Time Position Applicants Actions or Behavior CRS LEAD a transition brief prior to directing actions of EMG E-2.

CRS ENTER and DIRECT EMG E-2 FAULTED STEAM GENERATOR ISOLATION BOP 1. Check steamlines on all SGs - ISOLATED

a. Ensure Main Steamline Isolation Valve(s) - CLOSED o AB HIS-14 for SG A o AB HIS-17 for SG B o AB HIS-20 for SG C o AB HIS-11 for SG D

b. Ensure Main Steamline Isolation Bypass Valves - CLOSED o AB ZL-15A for SG A o AB ZL-18A for SG B o AB ZL-21A for SG C o AB ZL-12A for SG D

c. Ensure Main Steamline Low Point Drain Valve(s) - CLOSED o AB HIS-9 for SG A o AB HIS-8 for SG B o AB HIS-7 for SG C o AB HIS-10 for SG D CRS 2. Check if limitations for fault in Area 5 are required:

a. Check if steam is issuing from vent openings at 2000 foot elevation on south end of Turbine Building; No, Perform RNO 2RNOa. Go to step 3

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 4 Page 24 of 30_

Event

Description:

Steam line break inside Containment EMG E-2 FAULTED STEAM GENERATOR ISOLATION CT success - isolate the faulted Steam Generator before an Orange path integrity challenge develops Time Position Applicants Actions or Behavior Booth cue: If contacted as Building Watch at EMG E-2 step 2, report that no steam is issuing from the Area 5 vent openings.

BOP 3. Check if any SG is not faulted:

a. Check pressure in all SG:

ANY SG PRESSURE STABLE OR ANY SG PRESSURE INCREASING Examiner NOTE: SG B, C, and D pressure are stable for plant conditions. Crew should not transition to EMG C-21, UNCONTROLLED DEPRESSURIZATION OF ALL STEAM GENERATORS.

BOP 4. Identify faulted SGs:

a. Check pressure in all SGs:

ANY SG PRESSURE DECREASING IN AN UNCONTROLLED MANNER OR ANY SG COMPLETELY DEPRESSURIZED Examiner NOTE: SG A should be completely depressurized and previously identified as the faulted SG.

BOP 5. Isolate faulted SGs: (CT success - performed earlier per Foldout criteria of EMG E-0)

a. Close AFW flow control valves to faulted SGs (BOP CT action)

AL HK-8A and AL HK-7A for SG A

b. Locally close steam supply to Turbine Driven AFW pump from faulted SG; step not applicable

c. Ensure SG ARV on faulted SG - CLOSED AB PIC-1A for SG A Examiner NOTE: SG A was identified and isolated in EMG E-0.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 4 Page 25 of 30_

Event

Description:

Steam line break inside Containment EMG E-2 FAULTED STEAM GENERATOR ISOLATION Time Position Applicants Actions or Behavior BOP 6. Verify feedline isolated on faulted SG:

a. Main feedwater reg valve - CLOSED AE ZL-510 for SG A

b. Main feedwater reg bypass valve - CLOSED AE ZL-550 for SG A

c. Main feedwater isolation valve - CLOSED AE HIS-39 for SG A

d. Main feedwater chemical injection valve - CLOSED AE HIS-43 for SG A BOP 7. Verify Blowdown and Sampling isolated on faulted SG:

a. SG blowdown Containment isolation valves - CLOSED BM HIS-1A for SG A

b. SG upper sample isolation valves - CLOSED BM HIS-19 for SG A Procedure CAUTION: If any PZR PORV opens because of high PZR pressure, the PORV shall be monitored to ensure it recloses after pressure decreases to less than 2235 psig.

RO 8. Check PZR PORVs and Block valves:

a. Power to Block valves - AVAILABLE o BB HIS-8000A; No, this valve may be de-energized. Perform RNO o BB HIS-8000B

b. PZR PORVs - CLOSED o BB HIS-455A; No, dual indication, RNO - close Block valve o BB HIS-456A

c. RCS pressure - LESS THAN 2185 PSIG

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 4 Page 26 of 30_

Event

Description:

Steam line break inside Containment EMG E-2 FAULTED STEAM GENERATOR ISOLATION Time Position Applicants Actions or Behavior RO 8RNOa

a. Restore power to block valves o NG01BBR3 for BB HV-8000A Examiner NOTE: If power was removed from Block valve BB HV-8000A, the CRS may request that the power be restored per Step 8 RNO Restore power to block valves.

Booth cue: If contacted as Building Watch to restore power to the block valve: acknowledge request. Delete the remote (See KEY 5) and report to Control Room when task complete.

BOP 9. Check if uncontrolled cooldown has stopped:

a. Check RCS hot leg temperatures - STABLE OR DECREASING

b. Control steam flow and feed flow as necessary, to maintain stable RCS hot leg temperatures CREW 10. Determine secondary radiation levels:

a. Direct Health Physics to survey steamlines in area 5 of Aux Bldg.

b. Check SG sampling - ISOLATED

c. Ensure SI - RESET; No, Perform RNO 10RNOc: Reset SI

d. Check INST AIR PRESS - GREATER THAN 105 PSIG o KA PI-40

e. Open CCW to Radwaste System isolation valves; No, Perform RNO o EG HS-69 o EG HS-70 10RNOe. Go to step 12.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 4 Page 27 of 30_

Event

Description:

Steam line break inside Containment EMG E-2 FAULTED STEAM GENERATOR ISOLATION Time Position Applicants Actions or Behavior Booth cue: If contacted as HP: acknowledge request to survey steamlines in Area 5.

RO/BOP 12. Check if SG tubes are intact:

a. Condenser air discharge radiation - NORMAL BEFORE ISOLATION o GEG 925

b. SG blowdown and sample radiation - NORMAL o BML 256 o SJL 026 o Sample results

c. Turbine driven auxiliary feedwater pump exhaust radiation - NORMAL o FCT 381

d. SG steamline radiation - NORMAL o ABS 114 for SG A o ABS 113 for SG B o ABS 112 for SG C o ABS 111 for SG D o Local surveys

e. SG narrow range levels - NO LEVEL INCREASING IN AN UNCONTROLLED MANNER Booth cue: If contacted as Chemistry: acknowledge sampling request. If contacted as HP: acknowledge survey request.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 4 Page 28 of 30_

Event

Description:

Steam line break inside Containment EMG E-2 FAULTED STEAM GENERATOR ISOLATION Time Position Applicants Actions or Behavior RO 13. Check if ECCS flow should be reduced:

a. RCS subcooling - GREATER THAN 30°F [45°F]

b. Secondary heat sink:

Total feed flow to intact SG - GREATER THAN 270,000 LBM/HR OR Narrow range level in at least one intact SG - GREATER THAN 6%

[29%]

c. RCS pressure - STABLE OR INCREASING

d. PZR level - GREATER THAN 6% [33%]

e. Go to EMG ES-03, SI TERMINATION, step 1 CRS LEAD a transition brief prior to directing actions of EMG ES-03, SI TERMINATION.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 4 Page 29 of 30_

Event

Description:

Steam line break inside Containment EMG ES-03, SI TERMINATION Time Position Applicants Actions or Behavior CRS ENTER and DIRECT EMG ES-03, SI TERMINATION RO 1. Reset SI o SB HS-42A o SB HS-43A RO/BOP 2. Reset Containment Isolation Phase A and B o SB HS-56 for phase A o SB HS-53 for phase A o SB HS-55 for phase B o SB HS-52 for phase B RO/BOP 3. Verify Instrument Air alignment

a. Ensure at least one ESW TRAN TO AIR COMPRESSOR valve - OPEN EF HIS-43 EF HIS-44

b. Check AIR COMPRESSOR BRKR RESET switch associated with open ESW valve - CLOSED; if No Perform RNOb KA HIS-2C KA HIS-3C 3RNOb Reset and close AIR COMPRESSOR BRKR RESET switch

c. Check INST AIR PRESS - GREATER THAN 105 PSIG o KA PI-40

d. Check PZR PRESS MASTER CTRL output - LESS THAN 50%; if No, Perform RNO d o BB PK-455A

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 2 Event No.: 4 Page 30 of 30_

Event

Description:

Steam line break inside Containment EMG ES-03, SI TERMINATION Time Position Applicants Actions or Behavior RO/BOP Step 3RNOd cont.

3RNOd Perform the following:

1) Place PZR PRESS MASTER CTRL in manual (BB PK-455A)

2) Set PZR PRESS MASTER CTRL to less than 50% output signal

3) When instrument air has been established to Containment, then place PZR PRESS MASTER CTRL in AUTOMATIC

e. Check neither ESW TO AIR COMPRESSOR valve - locally open o EF HV-43 o EF HV-44

f. Open INST AIR SPLY CTMT ISO VLV o KA HIS-29 RO 4. Reduce charging flow:

a. Check shutdown sequencers - NOT ACTUATED:

o Annun. 00-018C, NF039A S/D SEQ ACTUATED - CLEAR o Annun. 00-021C, NF039B S/D SEQ ACTUATED - CLEAR

b. Stop all but one CCP and place in standby BG HIS-1A OR BG HIS-2A Lead Examiner may terminate scenario when CCP is stopped.

Booth operator Freeze simulator at direction of Lead Examiner.

Appendix D Scenario Outline Form ES-D-1 Facility: ______Wolf Creek____________ Scenario No.: ____3____ Op-Test No.: _______

Examiners: ____________________________ Operators: _____________________________

Initial Conditions: BOL ~10% power Turnover: Power ascension in progress, negative MTC. Perform step 6.40 through step 6.46 of GEN 00-003, HOT STANDBY TO MINIMUM LOAD. Use SYS AC-120, MAIN TURBINE GENERATOR STARTUP to synchronize the Main Generator to the grid.

Event Malf. Event Event No. No. Type* Description 1 N- Per GEN 00-003, HOT STANDBY TO MINIMUM LOAD, from step CREW 6.40 through step 6.46.

Step 6.40 directs SYS AC-120, MAIN TURBINE GENERATOR STARTUP (synchronize Main Generator to grid).

GEN 00-003 steps 6.41 through 6.46: valve alignments, increase turbine load using load potentiometer, verify Permissive states etc.

2 mNN02 C- Loss of NN02 (White train)

CREW TS determined and entered. TS 3.3.1 - Protective Interlocks in correct state; Table 3.3.1-1, Fu 18; Cond A (Immediately); Cond T for P-7, P-8, P-9 and P-13 (Verify interlock in required state within one hour); Cond S for P-10 (Verify interlock in required state within one hour).

TS 3.8.7, Cond A (restore to operable within twenty four hours)

TS 3.8.9, Cond C (restore to operable status within two hours) 3 mAB07 C- Atmospheric Relief Valve (ARV) C fails PARTIALLY open; manual G BOP, control unavailable SRO TS determined and entered. TS 3.7.4 Cond A (restore to operable within seven days) 4 Precursor: Seismic event Main Feed Pump trip Reactor trip 5 mSF17A M- Reactor fails to trip in automatic or manual. Anticipated Transient CREW Without Trip (ATWT) mSF17B 6 mAC02B C- Post trip malfunction #1: Turbine will not manually trip.

BOP, SRO 7 p01024 C- Post trip malfunction #2: BG HV-8104 does not open (see step 6 of C ATC, EMG FR-S1) RNO performed: aligns RWST to charging pump SRO suction

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor DRAFT 1 of 4

Scenario summary:

Unit is at ~ 10 % power, beginning of life. Power ascension in progress, negative MTC. Perform step 6.40 through step 6.46 of GEN 00-003, HOT STANDBY TO MINIMUM LOAD. Use SYS AC-120, MAIN TURBINE GENERATOR STARTUP to synchronize the Main Generator to the grid.

Event 1: The Crew, using GEN 00-003, HOT STANDBY TO MINIMUM LOAD, from step 6.40 through step 6.46 will synchronize Main Generator to the grid, verify valve alignments, increase turbine load using load potentiometer, and verify Permissive states etc.

Event 2: Loss of NN02 occurs. White train meter indications change and many Main Control Board alarms annunciate aid in diagnosing the component failure. The Crew may enter ALR 00-026A, NN02 INST BUS UV. The Crew enters OFN NN-021, LOSS OF VITAL 120VAC INSTRUMENT BUS, and performs Attachment B to restore power.

The Control Room Supervisor determines Technical Specifications.

Event 3: Atmospheric Relief Valve (ARV) C fails PARTIALLY open and manual control is unavailable. The Crew enters OFN AB-041, STEAMLINE OR FEEDLINE BREAK to mitigate the component failure. An Operator is dispatched to locally close the valve.

The Control Room Supervisor determines Technical Specifications.

Event 4: A Seismic event occurs. Main Control Board alarms 00-098D, OBE and 00-098E, SEISMIC RECORDER ON, annunciate. OFN SG-003, NATURAL EVENTS, is entered. The only running Main Feed Pump trips three minutes later. Main Control Board alarm 00-123A, MFP B TRIP, annunciates. The Crew determines a Reactor trip is necessary. A Reactor trip condition occurs; only the reactor fails to trip.

Event 5: The Main Event is an Anticipated Transient Without Trip (ATWT).

The Crew enters either EMG E-0, REACTOR TRIP OR SAFETY INJECTION, and from step 1RNO transitions to EMG FR-S1, RESPONSE TO NUCLEAR POWER GENERATION/ATWS or the Crew enters EMG FR-S1, RESPONSE TO NUCLEAR POWER GENERATION/ATWS directly to mitigate the Anticipated Transient Without Trip (ATWT).

Event 6: The turbine will not trip manually - the BOP must manually trip the turbine within thirty seconds to prevent an uncontrolled cooldown of the RCS due to steam flow that the turbine would require (2RNO EMG FR-S1 and EMG E-0).

Event 7: When aligning emergency boration, BG HV-8104 does not open. The ATC aligns Refueling Water Storage Tank to charging pump suction instead (6RNO of EMG FR-S1).

Successful mitigation strategy requires the Crew continues performance of EMG FR-S1, RESPONSE TO NUCLEAR POWER GENERATION/ATWS, transitions to EMG E-0, REACTOR TRIP OR SAFETY INJECTION, and finally EMG ES-02, REACTOR TRIP RESPONSE.

DRAFT 2 of 4

Post trip malfunction:

1. Event 6: Post trip malfunction #1: The turbine will not trip manually. As part of Immediate Actions of EMG FR-S1, RESPONSE TO NUCLEAR POWER GENERATION/ATWS, step 2RNO, the BOP must trip the turbine.

2. Event 7: Post trip malfunction #2: EMER BORATE TO CHG PUMP SUCT BG HIS-8104 does not open (see step 6 of EMG FR-S1, RESPONSE TO NUCLEAR POWER GENERATION/ATWS). RNO performed: aligns RWST to charging pump suction.

Scenario Critical Tasks (CT):

Event 5: CT: Insert negative reactivity into the core by at least one of the following methods before the Steam Generators dry-out:

• De-energize the control rod drive MG sets

• Manually insert control rods Event 6: CT: Manually trip the turbine within thirty seconds to prevent an uncontrolled cooldown of the RCS due to steam flow that the turbine would require.

DRAFT 3 of 4

Probabilistic Risk Analysis for this scenario includes:

Core Damage Frequency by Event Tree Core Damage Percent Event Tree Frequency (/yr) Contribution Station Blackout 6.46E-06 35.79%

Small LOCA 5.35E-06 29.65%

Interfacing Systems LOCA 1.93E-06 10.68%

Very Small LOCA 1.27E-06 7.05%

Steam Generator Tube Rupture 8.77E-07 4.86%

Loss of Reactor Coolant Pump Seal Cooling Following a Transient Initiator 5.91E-07 3.28%

Transients With Power Conversion Systems Available 3.30E-07 1.83%

Reactor Vessel Failure 3.00E-07 1.66%

Steamline Break 1.88E-07 1.40%

Transients Without Power Conversion Systems Available 1.71E-07 0.95%

Medium LOCA 1.46E-07 0.81%

Loss of All Service Water 8.30E-08 0.46%

Anticipated Transient Without Scram 6.67E-08 0.37%

Loss of Component Cooling Water 5.79E-08 0.32%

Loss of Offsite Power 4.98E-08 0.28%

Loss of Reactor Coolant Pump Seal Cooling With At Least One CCW Train Available 5.03E-08 0.28%

Loss of Vital DC Bus NK04 4.32E-08 0.24%

Large LOCA 2.80E-08 0.16%

Feedwater Line Break 2.06E-08 0.11%

Stuck Open Pressurizer PORV Following a Transient Initiator 3.14E-08 0.17%

Loss of Vital DC Bus NK01 1.12E-08 0.06%

Technical Specifications exercised:

Event 2: TS determined and entered. TS 3.3.1 - Protective Interlocks in correct state; Table 3.3.1-1, Fu 18; Cond A (Immediately); Cond T for P-7, P-8, P-9 and P-13 (Verify interlock in required state within one hour); Cond S for P-10 (Verify interlock in required state within one hour).

TS 3.8.7, Cond A (restore to operable within twenty four hours)

TS 3.8.9, Cond C (restore to operable status within two hours)

Event 3: TS determined and entered. TS 3.7.4 Cond A (restore to operable within seven days)

DRAFT 4 of 4

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 1 Page 1 of 54_

Event

Description:

Using GEN 00-003, HOT STANDBY TO MINIMUM LOAD, from step 6.40 through step 6.46, the Crew will synchronize Main Generator to the grid. SYS AC-120, MAIN TURBINE GENERATOR STARTUP (section 6.4 synchronizes and loads Main Generator to grid)

Time Position Applicants Actions or Behavior CREW Using GEN 00-003, HOT STANDBY TO MINIMUM LOAD, from step 6.40 through step 6.46 the Crew will synchronize Main Generator to the grid. SYS AC-120, MAIN TURBINE GENERATOR STARTUP (section 6.4 synchronizes Main Generator to grid)

CRS DIRECT GEN 00-003, HOT STANDBY TO MINIMUM LOAD CREW 6.40 When reactor power is stable between 8% and 10%, then synchronize Main Generator to the grid, using TMP 10-023 or SYS AC-120, MAIN TURBINE GENERATOR STARTUP as applicable.

CRS DIRECT SYS AC-120, MAIN TURBINE GENERATOR STARTUP, section 6.4, Synchronizing Main Generator CRS 6.4.1 Meter and Relay personnel are prepared to enable distance relays 321-1/G, 321-2/G and 321-3/G, when Exciter Field Breaker is closed.

Booth cue: If contacted as Meter and Relay personnel, Meter and Relay personnel are prepared to enable relays.

CRS 6.4.2 Establish Main Generator field, as follows:

CRS 6.4.2.1 Notify System Operations that the Generator is ready to be synchronized.

Booth cue: When contacted as System Operations: acknowledge report DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 1 Page 2 of 54_

Event

Description:

SYS AC-120, MAIN TURBINE GENERATOR STARTUP (section 6.4 synchronizes and loads Main Generator to grid)

Time Position Applicants Actions or Behavior CRS 6.4.2.2 Ensure POWER SYS STABILIZER MODE SEL switch is in normal unless System Operations directs otherwise.

o MB HS NORMAL Booth cue: If contacted as System Operations: NORMAL is fine.

BOP 6.4.2.3 Ensure Sync Check Relay Bypass switch in off position

a. Ensure Sync Check Relay Bypass switch handle removed.

o MA HS HANDLE REMOVED BOP 6.4.2.4 Place REG MODE TRANSFER switch in manual.

o MB HS MANUAL BOP 6.4.2.5 Check the green light lit on the DC MAN VOLT REG.

o MB ZL GREEN LIGHT LIT BOP 6.4.2.6 Verify Turbine speed - AT 1800 RPM BOP 6.4.2.7 Close EXCITER FIELD BKR o MB HS-2 CRS/BOP 6.4.2.8 At panels MA104C/MA104B, ensure Meter and Relay personnel have enabled 321-1/G, 321-2/G & 321-3/G distance relays o Distance relays - ENABLED o Target/Auxiliary relays - DROP FLAGS RESET o 21XMA001 (MA104C) o 21XMA002 (MA104C)

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 1 Page 3 of 54_

Event

Description:

SYS AC-120, MAIN TURBINE GENERATOR STARTUP Time Position Applicants Actions or Behavior CRS/BOP Step 6.4.2.8 cont.

o 21XMA003 (MA104C) o 321/X (MA104B)

Booth cue: Respond as Meter & relay personnel: Distance relays ENABLED.

CRS 6.4.2.9 At panel MA104B, Main Generator System Relay Panel, ensure Reverse Power Relay 332/GX and Reverse Time Delay 362/G are reset.

o 332/GX - RESET o 362/G - RESET Booth cue: Respond as Meter & relay personnel: Relays are reset BOP 6.4.2.10 Place MAIN GEN VOLTMETER 0 SEL switch in any position except off.

o MA HS NOT IN OFF BOP 6.4.2.11 Adjust MB HS-5, DC MAN VOLT REG BKR, as necessary, to establish Main Generator voltage at 24.5 KV on all three phases o MB HS ADJUSTED, AS NECESSARY o MA EI AT 24.5 KV BOP 6.4.2.12 Adjust MB HS-6, AC AUTO VOLT REF BKR, as necessary, to zero Voltage Regulator Manual/Auto Signal Match o MB HS ADJUSTED, AS NECESSARY o MB EI 0 VOLTAGE MISMATCH DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 1 Page 4 of 54_

Event

Description:

SYS AC-120, MAIN TURBINE GENERATOR STARTUP Time Position Applicants Actions or Behavior BOP 6.4.2.13 Transfer RED MODE TRANSFER switch to auto o MB HS AUTO o MB ZL-3, REG MODE MAN/AUTO Red light - LIT Procedure NOTE: 8% to 10% reactor power level is desired. This ensures an adequate number of Steam Dumps are open to support synchronizing Main Generator without all Steam Dumps going closed and requires minimal rod movement.

BOP 6.4.3 Synchronize Main Generator to grid, as follows:

BOP 6.4.3.1 Ensure REVERSE POWER PERMISSIVE BYPASS SWITCH is in off.

o MA HS-005 - OFF BOP 6.4.3.2 Adjust the load limit potentiometer to prevent excessive loading as follows:

a. Lower the load limit potentiometer, by slowly turning it counterclockwise, until LOAD LIMITING light comes on.

b. Increase the load limit potentiometer, by turning it clockwise four tenths of one turn (forty clicks)

BOP 6.4.3.3 Select first switchyard breaker to be synchronized, using MA HS-2, BKR SEL switch Breaker 1 - SELECTED OR Breaker 2 - SELECTED Procedure NOTE: Matching Generator transformer voltage with switchyard voltage must be as close as possible to avoid system upset.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 1 Page 5 of 54_

Event

Description:

SYS AC-120, MAIN TURBINE GENERATOR STARTUP Time Position Applicants Actions or Behavior BOP 6.4.3.4 Adjust MB HS-6, AC AUTO VOLT REG BKR, as necessary, to establish Generator Transformer Voltage between 1 KV and 2 KV higher than switchyard voltage o MA EI-8 For Transformer Voltage o MA EI-9 For Switchyard Voltage Procedure NOTE: When adjusting Turbine speed at or near 1800 rpm, response to small changes may require between 15 seconds and 30 seconds to stabilize.

BOP 6.4.3.5 Adjust Main Generator speed for synchronizing, as follows:

a. Adjust load set using INCREASE LOAD pushbutton or DECREASE LOAD pushbutton, as necessary, to rotate the Main Generator Synchroscope in the fast direction.

o MA SI-6

b. Ensure rotation of the synchroscope is between 30 seconds and 90 seconds, by adjusting load set, as necessary.

c. Check selected breaker Sync Check Permissive white light is lit only when the synchroscope pointer is in the up direction MA ZL LIT MA ZL LIT

d. Ensure Generator transformer voltage is between 1 KV and 2 KV higher than switchyard voltage o MA EI-8 o MA EI-9 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 1 Page 6 of 54_

Event

Description:

SYS AC-120, MAIN TURBINE GENERATOR STARTUP Time Position Applicants Actions or Behavior BOP 6.4.3.6 When selected breaker Sync Check Permissive white light is lit for the selected breaker, then close selected breaker.

MA HS CLOSED OR MA HS CLOSED BOP 6.4.3.7 Ensure selected switchyard breaker is closed Breaker 1 - CLOSED At RL006, MA ZL-3A At RL014, 1ZL-SY010 Breaker 2 - CLOSED At RL006, MA ZL-4A At RL014, 1ZL-SY011 Procedure NOTES:

o Once the initial 50 MWe to 100 MWe has been picked up using INCREASE LOAD, consideration should be given to swapping to load limit potentiometer control for increased plant stability.

o Computer point MAP0001 may update quicker and should be monitored in addition to the digital load MW meter.

o Operation of Main Turbine below 5% load is not recommended, due to the increased rates of moisture erosion of the latter stage buckets.

o Rapid temperature changes increase the likelihood of initiating a packing rub on monoblock rotors.

Average temperature ramp rates of 125°F/hr for the LP rotors and 150°F/hr for the HP rotor are recommended.

o With exhaust hood temperature between 125°F and 175°F, the unit may be operated continuously but load should be increased slowly to avoid unnecessary thermal stress.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 4 Page 7 of 54_

Event

Description:

SYS AC-120, MAIN TURBINE GENERATOR STARTUP Time Position Applicants Actions or Behavior BOP 6.4.4 Load Main Generator BOP 6.4.4.1 Press INCREASE LOAD pushbutton to increase Generator load between 50 megawatts and 100 megawatts, as soon as possible, to prevent Generator motoring and maintain load stability.

BOP 6.4.4.2 Select Generator loading rate, as directed by the SM/CRS.

BOP 6.4.4.3 If the LOAD LIMITING light comes on before achieving 50 Mwe, then increase the LOAD LIMIT SET potentiometer, by turning it clockwise to allow load increase to continue.

BOP 6.4.4.4 If desired to transfer control to Load Limit Potentiometer, then perform the following:

a. Slowly reduce Load Limit Potentiometer, until the Load Limit Limiting light has just lit.

b. When Load Limit Limiting light is lit, then use Load Set Increase pushbutton to raise the setting of the Load Set above the setting of the Load Limit Potentiometer.

BOP 6.4.4.5 If steam dumps remain open when 50 Mwe is achieved, then loading may continue until one of the following occurs:

Steam Dumps are closed or 120 Mwe is achieved DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 4 Page 8 of 54_

Event

Description:

SYS AC-120, MAIN TURBINE GENERATOR STARTUP Time Position Applicants Actions or Behavior CRS 6.4.4.6 If exhaust hood bypass valve was opened during the performance of this procedure, then ensure exhaust hood temperatures remain between 100°F - 125°F, while closing TURBINE EXHAUST HOOD SPRAY VALVE AC FV-191 BYPASS.

o AC-944 - CLOSED Booth cue: If contacted as Building Watch to close AC-944 (not modeled); wait a few minutes and then report to Control Room that valve is closed BOP 6.4.5 Close the other switchyard breaker:

BOP 6.4.5.1 Select open switchyard breaker on MA HS-2, BKR SEL Breaker 1 - SELECTED or Breaker 2 - SELECTED BOP 6.4.5.2 Close selected switchyard breaker.

MA HS CLOSED or MA HS CLOSED BOP 6.4.5.3 Ensure selected switchyard breaker closed Breaker 1 - CLOSED At RL006, MA ZL-3A At RL014, 1ZL-SY010 Breaker 2 - CLOSED At RL006, MA ZL-4A At RL014, 1ZL-SY011 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 1 Page 9 of 54_

Event

Description:

GEN 00-003, HOT STANDBY TO MINIMUM LOAD Time Position Applicants Actions or Behavior BOP 6.4.5.4 Place BKR SEL switch in off position.

o MA HS OFF BOP 6.4.6 Open Bus Duct Cooling Unit Heater breaker o PG1502 - OPEN Booth cue: If contacted to open breaker PG1502 (not modeled) wait a few minutes and report back to Control Room that the breaker is open.

BOP 6.4.7 At AC XX-1, EHC Panel, select, SLOW STARTING RATE BOP 6.4.8 Section 6.4, Synchronizing Main Generator complete CRS DIRECT GEN 00-003, HOT STANDBY TO MINIMUM LOAD RO/BOP 6.41 Position the following valves:

6.41.1 Close MAIN STMLINES DRN TRAP BYPASS VLV o AB HIS CLOSED RO/BOP 6.41.2 Close MAIN TURN STOP AND CTRL VLVS SU DRNS o AC HIS-134 - CLOSED DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 1 Page 10 of 54_

Event

Description:

GEN 00-003, HOT STANDBY TO MINIMUM LOAD Time Position Applicants Actions or Behavior RO/BOP 6.41.3 Ensure the following Turbine Extraction valves to High Pressure Feedwater heaters are open:

o AF HIS-24, FW HP HTR 5A Extraction Vlvs - OPEN o AF HIS-64, FW HP HTR 5B Extraction Vlvs - OPEN o AF HS-12, FW HP HTR 6A Extraction Vlvs - OPEN o AF HS-44, FW HP HTR 6B Extraction Vlvs - OPEN o AF HS-7, FW HP HTR 7A Extraction Vlvs - OPEN o AF HS-58, FW HP HTR 7B Extraction Vlvs - OPEN Procedure CAUTION: The rate of power increase shall be limited to the following:

o Unit loading between 0 and 15 percent power shall be limited to 0.5% (rated) power per minute.

o Unit loading between 15 and 40 percent power shall be limited to 5% (rated) power per minute or a maximum step change of 10% (rated) power.

Procedure NOTES:

o All individual indicated rod positions shall be within 12 steps of their group step counter demand position and shall be within the insertion, sequence and overlap limits specified in the COLR in accordance with TS 3.1.4, 3.1.5 and 3.1.6 o If steam flow oscillations are observed, manual control of Steam Dump Controllers may be required.

CRS 6.42 When Turbine load is being increased, then use the following techniques:

NA - MTC is 6.42.1 If moderator temperature coefficient is positive the perform the following:

negative Procedure CAUTION: Increasing turbine load is a critical step and must be performed in a slow and deliberate manner, to maintain RCS pressure and temperature within DNB limits.

CRS 6.42.2 () If moderator temperature coefficient is negative or zero, then perform the following:

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 1 Page 11 of 54_

Event

Description:

GEN 00-003, HOT STANDBY TO MINIMUM LOAD Time Position Applicants Actions or Behavior Procedure NOTE: Selecting the lowest reading channel will provide more margin to the DNB limit.

RO 6.42.1 Ensure BB PS/455F, PRESSURIZER PRESSURE CONTROL switch is selected to the lowest reading channel.

BOP 6.42.2 Perform Turbine load increase using load limit potentiometer in a slow controlled manner. When the Main Feed Reg valves have been placed inservice, then automatic turbine loading may be used.

BOP 6.42.3 If the potentiometer is NOT available, then with Operations Management approval, control Turbine load using automatic turbine-generator loading selected to 1/2% per minute in a slow controlled manner.

RO 6.42.4 When Steam Dumps are open, then adjust control rods as needed to maintain Tavg constant.

RO 6.42.5 When Steam Dumps are closed, then adjust control rods , as necessary, to maintain Tavg within 1.5°F of Tref.

BOP 6.43 () Increase reactor power, by increasing Turbine load using the technique selected in step 6.42 in a slow controlled manner, while continuing with this procedure.

CRS 6.43.1 Make appropriate log entry to reflect the requirement to complete STS SE-001, POWER RANGE ADJSUTMENT TO CALORIMETRIC within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after power is greater than or equal to 15% to satisfy SR 3.3.1.2.

CRS 6.44 When reactor power is greater than 10%, then perform the following:

Procedure NOTE: If P-10 fails to properly change state, refer to step 4.15.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 1 Page 12 of 54_

Event

Description:

GEN 00-003, HOT STANDBY TO MINIMUM LOAD Time Position Applicants Actions or Behavior RO 6.44.1 Check P-10 permissive properly changes state, by observation of the following:

1. Bistable status lights lit.

o SB069, 14 Down, 1 Across - LIT o SB069, 14 Down, 2 Across - LIT o SB069, 14 Down, 3 Across - LIT o SB069, 14 Down, 4 Across - LIT

2. Permissive status light lit.

o SB069, 15 Down, 4 Across - LIT RO 6.44.2 Check Annunciator 00-077E, SR HI VOLT FAIL - CLEAR RO 6.44.3 Block intermediate range low power trips:

1. Depress both IR TRIP BLOC pushbuttons.

o SE HS DEPRESSED o SE HS DEPRESSED

2. Ensure intermediate range reactor trips are blocked.

o SB069, 13 Down, 1 Across - LIT o SB069, 13 Down, 2 Across - LIT DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 1 Page 13 of 54_

Event

Description:

GEN 00-003, HOT STANDBY TO MINIMUM LOAD Time Position Applicants Actions or Behavior RO 6.44.4 Block power range low power trips:

1. Depress both PR LO Trip Bloc pushbuttons.

o SE HS DEPRESSED o SE HS DEPRESSED

2. Ensure power range low setpoint reactor trips are blocked.

o SB069, 13 Down, 3 Across - LIT o SB069, 13 Down, 4 Across - LIT Procedure NOTE: When P-7 bistable is deenergized (P-7 permissive light energizes), the following reactor trips are automatically unblocked:

o Pressurizer low pressure o Pressurizer high pressure o Loss of flow - two loop logic o RCP underfrequency o RCP undervoltage RO 6.44.5 When P-10 permissive has changed state, then ensure that P-7 permissive light has energized.

o SB069, 12 Down, 4 Across - LIT RO 6.44.6 Transfer NR-45 pen that is recording intermediate range to a delta flux channel.

CRS 6.45 Align the Unit Auxiliary Transformer, by performing CKL MA-132, UNIT AUXILIARY TRANSFORMER XMA02 LINEUP FOR OPERATION Booth cue: If contacted as Building Watch, acknowledge request. Ensure simulator and this CKL are SAT.

CKL MA-132, UNIT AUXILIARY TRANSFORMER XMA02 LINEUP FOR OPERATION DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 1 Page 14 of 54_

Event

Description:

GEN 00-003, HOT STANDBY TO MINIMUM LOAD Time Position Applicants Actions or Behavior CRS 6.46 If operating with a negative MTC and Turbine load is sufficient such that Steam Dump valves are closed, then perform the following:

BOP 6.46.1 Ensure all Steam Dump valves indicate closed.

o Condenser Steam Dumps - CLOSED o Atmospheric Relief Valves - CLOSED BOP 6.46.2 Momentarily place Condenser Steam Dump Control Mode Selector switch to reset.

o AB US-500Z - RESET BOP 6.46.3 Ensure loss of load interlock C-7 is reset.

BOP 6.46.4 Place Steam Dump Mode Controller in Tavg mode.

o AB US-500Z - TAVG BOP 6.46.5 Ensure flags are matched on STEAM DUMP BYPASS INTERLOCK switches o AB HS ON/ GREEN FLAG o AB HS ON/ GREEN FLAG BOP 6.46.6 Ensure all Atmospheric Relief Valve Controllers are set to maintain 1125 psig in automatic o AB PIC-1A - IN AUTO AT 1125 PSIG o AB PIC-2A - IN AUTO AT 1125 PSIG o AB PIC-3A - IN AUTO AT 1125 PSIG o AB PIC-4A - IN AUTO AT 1125 PSIG DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 2 Page 15 of 54_

Event

Description:

Loss of NN02 (White train)

Time Position Applicants Actions or Behavior When Main Generator is synced to the grid and reactor power has been raised, and the Permissives verified, and at Lead Examiner direction, continue with the next event.

Booth: Insert KEY 2 for Event 2 at Lead Examiner discretion.

Diagnostics: White train meter indications change and many Main Control Board alarms annunciate aid in diagnosing the component failure. MCB 00-026A, NN02 INSTR BUS UV annunciates.

CREW Diagnoses an NN02 failure (white train) and selects out affected instruments.

BOP Selects alternate channel for:

o SG C STEAM FLOW CHANNEL SEL, AB FS-532C (select F-532) o SG C LEV CHANNEL SEL, AE LS-539C (select L-539) o SG D STEAM FLOW CHANNEL SEL, AB FS-542C (select F-542) o SG D LEV CHANNEL SEL, AE LS-549C (select L-554)

RO Selects alternate channel for:

o PZR PRESS CTRL SEL, BB PS-455F (MANUAL on controller, select P-455/P-458) o PZR LEV CTRL SEL, BB LS-459D (select L-459/L-461)

Examiner NOTE: PZR Pressure Master Controller must be placed in MANUAL first.

CRS May ENTER and DIRECT ALR 00-026A, NN02 INSTR BUS UV Procedure NOTES:

o Steps 1 through 3 are Memory action steps.

o Steps 1 through 3 may be done in any order.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 2 Page 16 of 54_

Event

Description:

Loss of NN02 (White train)

Time Position Applicants Actions or Behavior RO 1. Loss of NN02 with Control Rods inserting; No, Perform RNO 1RNO: Go to step 2 BOP 2. Ensure SG control systems are using unaffected channels:

NN02 WHITE TRAIN SG STEAM FLOW SELECT SG LEVEL SELECT SELECTOR CHANNEL SELECTOR CHANNEL SWITCH SWITCH SG A AB FS-512C F512 AE LS-519C L551 SG B AB FS-522C F522 AE LS-529C L529 SG C AB FS-532C F532 AE LS-539C L539 SG D AB FS-542C F542 AE LS-549C L554 RO 3. Ensure PZR control signals are using unaffected channels:

a. Check alternate channel selection required.

b. Check Pressurizer pressure channel affected.

c. Place Pressurizer Master Controller in manual.

o BB PK-455A

d. Select alternate channel, using table below:

AFFECTED BUS PZR PRESSURE PZR LEVEL SWITCH SELECT SWITCH SELECT CHANNEL CHANNEL NN02 WHITE PS-455F P455/ P458 LS-459D L459/ L461 TRAIN RO 3e. cont. Return Pressurizer Master Controller to auto, as directed by CRS.

o BB PK-455A DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 2 Page 17 of 54_

Event

Description:

Loss of NN02 (White train)

Time Position Applicants Actions or Behavior CRS 4. Dispatch Operator to NN02 instrument bus with Interlock Key to perform actions, as directed by SM or CRS.

Booth cue: If contacted as Building watch, acknowledge request.

CRS 5. Refer to Technical Specifications 3.8.9, 3.8.10, and 3.3.1.

CRS determines: TS 3.3.1 - Protective Interlocks in correct state; Table 3.3.1-1, Fu 18; Cond A (Immediately); Cond T for P-7, P-8, P-9 and P-13 (Verify interlock in required state within one hour); Cond S for P-10 (Verify interlock in required state within one hour).

TS 3.8.9, Cond C (restore to operable status within two hours)

CRS When TS 3.3.1 identified, DIRECT RO or BOP to verify Protective Interlocks and Control Interlocks are in the correct state.

CRS 6. Go to OFN NN-021, LOSS OF VITAL 120 VAC INSTRUMENT BUS, step 1 CREW ENTER OFN NN-021, LOSS OF VITAL 120 VAC INSTRUMENT BUS CRS ENTER and DIRECT ENTER OFN NN-021, LOSS OF VITAL 120 VAC INSTRUMENT BUS Examiner NOTE: CREW may enter OFN NN-021, LOSS OF VITAL 120 VAC INSTRUMENT BUS directly.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 2 Page 18 of 54_

Event

Description:

Loss of NN02 (White train)

Time Position Applicants Actions or Behavior Procedure NOTES:

o Steps 1 through 3 can be done in any order.

o Steps 1 through 3 are Memory Action steps.

CRS, RO 1. Loss of NN01 or NN02 with control rods inserting; No, Perform RNO 1RNO: Go to step 2 BOP 2. Ensure SG control systems are using unaffected channels:

NN02 WHITE TRAIN SG STEAM FLOW SELECT SG LEVEL SELECT SELECTOR CHANNEL SELECTOR CHANNEL SWITCH SWITCH SG A AB FS-512C F512 AE LS-519C L551 SG B AB FS-522C F522 AE LS-529C L529 SG C AB FS-532C F532 AE LS-539C L539 SG D AB FS-542C F542 AE LS-549C L554 Examiner NOTE: this is only the NN02 selection RO 3. Ensure PZR control signals are using unaffected channels:

a. Check alternate channel selection required.

b. Check Pressurizer pressure channel affected.

c. Place Pressurizer Master Controller in manual.

o BB PK-455A

c. Select alternate channel, using table below:

(See next page)

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 2 Page 19 of 54_

Event

Description:

Loss of NN02 (White train)

Time Position Applicants Actions or Behavior AFFECTED BUS PZR PRESSURE PZR LEVEL SWITCH SELECT SWITCH SELECT CHANNEL CHANNEL NN02 WHITE PS-455F P455/ P458 LS-459D L459/ L461 TRAIN Examiner NOTE: this is only the NN02 selection.

RO 3e cont. Return Pressurizer Master Controller to auto, as directed by CRS.

o BB PK-455A RO 4. () Check RWST switchover has occurred A Train swapped over.

o BG HIS-112B - CLOSED o BN HIS-112D - OPEN or B Train swapped over.

o BG HIS-112C - CLOSED o BN HIS-112E - OPEN or RO 5. Isolate LTDN and establish minimum charging flow:

a. Close letdown orifice isolation valves.

o BG HIS-8149AA o BG HIS-8149BA o BG HIS-8149CA

b. Close charging flow control valve.

o BG HC-182 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 2 Page 20 of 54_

Event

Description:

Loss of NN02 (White train)

Time Position Applicants Actions or Behavior RO Step 5 cont.

c. Ensure CCP A, CCP B, or NCP - AT LEAST ONE RUNNING

d. Establish 32 gpm seal injection flow o BG FCV-121 o BG FK-462 CRS 6. Stabilize plant:

a. Stop any plant operations requiring rod motion.

b. () Adjust turbine load, as necessary, to maintain Tavg within 3°F of Tref.

CRS 7. Dispatch operator to affected Instrument bus with Backup Breaker Interlock key Booth Cue: Respond as Building watch when dispatched to Instrument bus.

CRS 8. Go to appropriate

Attachment:

o Loss of NN02, Attachment B CREW Enter Attachment B, LOSS OF NN02 CRS ENTER and DIRECT Attachment B, LOSS OF VITAL INSTRUMENT BUS NN02 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 2 Page 21 of 54_

Event

Description:

Loss of NN02 (White train)

Time Position Applicants Actions or Behavior RO B1. Defeat RCS temperature control for loop 2

a. Position Loop Tavg control signal to - T422 o BB TS-412T

b. Position Loop T control signal to - T421 o BB TS-411F BOP B2. Ensure AC PT-505 selected.

o AC PS-505Z BOP B3. Lock SG B Atmospheric Relief Valve manual drive level in closed position.

o AB PIC-2A CRS, RO B4. Locally restore normal power to bus NN02:

a. Check NN02 bus - NO APPARENT DAMAGE

b. Check inverter NN12 output voltage - NORMAL; No, Perform RNO B4RNOb. Go to step B5 Booth Cue: B4 cue: NN02 has no apparent damage. NN12 output voltage is zero. Later: B5 cue: Understand, Close NG02AFF3 then report to Control Room the breaker is closed; White Light is LIT; I have the Kirk Key and will open NN0201 and close Alternate Feed NN0202. MCB alarms will occur. Insert KEY 8 to realign power.

CRS, RO B5. Align backup power to bus NN02

a. Close backup transformer XNN06 power supply breaker.

o NG02AFF3

b. Verify Backup Power available white Light - LIT

c. Open Normal feeder breaker o NN0201 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 2 Page 22 of 54_

Event

Description:

Loss of NN02 (White train)

Time Position Applicants Actions or Behavior CRS, RO d. Close Alternate feeder breaker o NN0202

e. Refer to applicable Technical Specification:

3.8.7, Inverters - Operating 3.8.8, Inverters, Shutdown CRS determines: TS 3.8.7, Cond A (restore to operable within twenty four hours)

TS overall: CRS determines: TS 3.3.1 - Protective Interlocks in correct state; Table 3.3.1-1, Fu 18; Cond A (Immediately); Cond T for P-7, P-8, P-9 and P-13 (Verify interlock in required state within one hour); Cond S for P-10 (Verify interlock in required state within one hour).

TS 3.8.7, Cond A (restore to operable within twenty four hours)

TS 3.8.9, Cond C (restore to operable status within two hours)

CRS When TS 3.3.1 identified, DIRECT RO or BOP to verify Protective Interlocks and Control Interlocks are in the correct state.

RO B6. Establish 60 gpm charging flow, as directed by the CRS

a. Check CCP A, CCP B or NCP - AT LEAST ONE RUNNING BG HIS-1A BG HIS- 2A BH HIS-3 (NCP - should be running)

b. Adjust CCP or NCP flow control valves and charging header back pressure control valve, as necessary to establish 60 gpm charging flow.

BG FK-121 (CCP)

BG FK-462 (NCP)

BG HC-182 (backpressure flow control)

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 2 Page 23 of 54_

Event

Description:

Loss of NN02 (White train)

Time Position Applicants Actions or Behavior RO Step B6 cont.

c. Adjust charging header flow control, as necessary, to establish between 8 gpm and 13 gpm seal injection flow to each RCP o BG HC-182 RO B7. Check if letdown can be established:

RO a. PZR level - GREATER THAN 18%

b. Establish normal letdown:

1. Open letdown system Containment isolation valves.

o BG HIS-8152 o BG HIS-8160

2. Open RCS letdown to regenerative heat exchanger valves.

o BG HIS-459 o BG HIS-460

3. Place letdown heat exchanger outlet pressure controller in manual and full open.

o BG PK-131

4. Open orifice isolation valves, as necessary, to establish desired letdown flow.

BG HIS-8149AA BG HIS-8149BA BG HIS-8149CA

5. Adjust letdown heat exchanger outlet pressure controller, to maintain between 300-350 psig and place in automatic.

o BG PK-131

6. Go to step B9 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 2 Page 24 of 54_

Event

Description:

Loss of NN02 (White train)

Time Position Applicants Actions or Behavior RO B9. Adjust charging flow, as necessary, to maintain PZR level BOP B10. Check SG level control:

a. Check SG narrow range level - TRENDING TO PROGRAMMED LEVEL

b. Check feedwater pump P - AT PROGRAMMED VALUE RO B11. Check if PZR variable heaters can be energized:

a. PZR level - GREATER THAN 18%

b. Reset and energize variable heaters.

o BB HIS-50

c. Ensure PZR level - STABLE AT OR TRENDING TO PROGRAMMED VALUE RO B12. Verify PZR pressure control established:

a. Spray valves - MODULATE AS NECESSARY TO CONTROL PRESSURE

b. PRZ pressure - STABLE

c. PZR heaters - ENERGIZE AS NECESSARY TO CONTROL PRESSURE

d. PZR PORVs - AT LEAST ONE AVAILABLE BB HIS-455A BB HIS-456A CRS B13. Check NN02- DEENERGIZED; No, Perform RNO B13RNO. Go to step B15 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 2 Page 25 of 54_

Event

Description:

Loss of NN02 (White train)

Time Position Applicants Actions or Behavior BOP B15. Check plant - IN MODE 1 OR 2

a. On Detector Current Comparator Drawer, place Rod Stop Bypass Switch in N42 position CRS B16. Refer to OFN SB-008, INSTRUMENT MALFUNCTIONS, as necessary to address instrument malfunctions.

RO B17. Check for stable plant conditions:

a. Check Tavg - WITHIN 1°F OF Tref

b. Check PZR pressure - STABLE AT OR TRENDING TO 2235 PSIG

c. Check PZR level - STABLE AT OR TRENDING TO PROGRAM VALUE B17RNOa if needed: () Adjust the following, as necessary, to maintain Tavg within 1°F of Tref:

Adjust turbine load Adjust control rods Adjust boron concentration CRS/RO B18. Check Flux Distribution - WITHIN TECHNICAL SPECIFICATIONS LIMITS o 3.2.3 - AFD o 3.2.4 - QTPR Examiner NOTE: Neither TS are applicable as the unit is less than 50%.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 2 Page 26 of 54_

Event

Description:

Loss of NN02 (White train)

Time Position Applicants Actions or Behavior CRS B19. Check Protective Interlocks and Control Interlocks in correct state to meet Technical Specification 3.3.1 requirements CRS determines: TS 3.3.1 - Protective Interlocks in correct state; Table 3.3.1-1, Fu 18; Cond A (Immediately); Cond T for P-7 (LIT), P-8 (NOT LIT), P-9 (NOT LIT) and P-13 (may be LIT based on power level) (Verify interlock in required state within one hour); Cond S for P-10 (LIT) (Verify interlock in required state within one hour).

Once TS 3.3.1 have been identified, the Lead Examiner may proceed to the next Event (three).

Booth: At Lead Examiner direction, insert KEY 3 for Event three.

CRS When TS 3.3.1 identified, DIRECT RO or BOP to verify Protective Interlocks and Control Interlocks are in the correct state.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 3 Page 27 of 54_

Event

Description:

Atmospheric Relief Valve (ARV) C fails PARTIALLY open; manual control unavailable Time Position Applicants Actions or Behavior Booth: Insert KEY 3 for Event 3 for Lead Examiner direction.

Diagnostics: Dual indication on switch SG C STEAM DUMP TO ATMS AB ZL-3A. RCS temperature slowly decreasing.

Booth Cue if necessary: Site watch calls Control Room: I see steam issuing from an ARV silencer.

CREW Identifies and Diagnoses ARV C is partially open.

CRS DIRECT closure of ARV C Examiner NOTE: AP 15C-003, PROCEDURE USERS GUIDE FOR ABNORMAL PLANT CONDITIONS, step 6.1.7: Components not performing their intended function should be manually controlled.

BOP Reports ARV C will not close.

CREW Dispatch Building Operator to locally isolate ARV C using AB-V029, SG C Atmospheric Relief Valve Iso Booth cue: Respond to CR request as Building watch to close AB-V029. Insert KEY 9 to close AB-V029.

When valve closed, report back to Control Room.

CREW Enter OFN AB-041, STEAMLINE OR FEEDLINE LEAK CRS ENTER and DIRECT OFN AB-041, STEAMLINE OR FEEDLINE LEAK DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 3 Page 28 of 54_

Event

Description:

Atmospheric Relief Valve (ARV) C fails PARTIALLY open; manual control unavailable Time Position Applicants Actions or Behavior RO 1. Check Reactor power - LESS THAN 100%

o SE NI-41B o SE NI-42B o SE NI-43B o SE NI-44B BOP 2. Check Steam Generator levels - STABLE OR TRENDING TO PROGRAM RO 3. Check Tref/Tavg deviation - LESS THAN 3°F o 00-065D - NOT LIT BOP 4. Check Condenser Hotwell level - STABLE OR INCREASING o AD LI-114 BOP 5. Ensure SG ARVs are - CLOSED o AB PIC-1A for SG A (YES) o AB PIC-2A for SG B (YES) o AB PIC-3A for SG C (No, Perform RNO) o AB PIC-4A for SG D (YES) 5RNO Perform the following:

a. If any valve can not be closed, then dispatch operator to locally isolate affected SG ARV AB-V029 for SG C

b. Refer to Tech Spec 3.7.4 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 3 Page 29 of 54_

Event

Description:

Atmospheric Relief Valve (ARV) C fails PARTIALLY open; manual control unavailable Time Position Applicants Actions or Behavior CRS/BOP Dispatch Building watch to locally isolate affected SG ARV - CLOSE AB-V029 Booth cue: Respond to CR request as Building watch to close AB-V029. Insert KEY 9 to close AB-V029.

When valve closed, report back to Control Room.

CRS Step 5RNOb cont.

CRS determines Technical Specification TS 3.7.4 Cond A (restore to operable within seven days).

Lead Examiner: When Technical Specification 3.7.4 Cond A is identified and the ARV is locally isolated, proceed to next event. Three additional steps are provided while AB-V029 is closing.

Booth: Insert KEY 4 for Event four at Lead Examiner direction.

CREW When valve is closed, CREW determines that cooldown stabilized.

BOP 6. Ensure Condenser Steam Dump valves - CLOSED o AB ZL-34 o AB ZL-35 o AB ZL-36 o AB ZL-37 o AB ZL-38 o AB ZL-39 o AB ZL-40 o AB ZL-41 o AB ZL-42 o AB ZL-43 o AB ZL-44 o AB ZL-45 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 3 Page 30 of 54_

Event

Description:

Atmospheric Relief Valve (ARV) C fails PARTIALLY open; manual control unavailable Time Position Applicants Actions or Behavior RO 7. Verify no steam leakage from SG Safety valves Booth cue: If contacted as Site watch: No steam is leaking from SG Safety valves RO 8. Check the following Containment parameters - NORMAL

a. Containment temperature o GN TI-60 o GN TI-61 o GN TI-62 o GN TI-63

b. Containment pressure (GT PDI-40)

c. Containment humidity o GN AI-27 o GN AI-28

d. Containment sump levels EJ LI-7 EJ LI-8 EJ LR-6 LF LI-9 LF LI-10

e. Containment radiation o GTP 311 o GTI 312 o GTG 313 o GTP 321 o GTI 322 o GTG 323 o GTA 591 o GTA 601 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 4 Page 31 of 54_

Event

Description:

Seismic event Main Feed Pump trip Reactor trip Time Position Applicants Actions or Behavior Booth: Insert KEY 4 for Event four at Lead Examiner direction. (Seismic event Main Feed Pump trip Reactor trip)

Diagnostics: Main Control Board alarms 00-098D, OBE and 00-098E, SEISMIC RECORDER ON, annunciate.

Earthquake sound is heard. The only running Main Feed Pump trips (three minutes later). MCB alarm 00-123A, MFP B TRIP, annunciates.

CREW Identifies a seismic event has occurred.

CRS ENTER and DIRECT OFN SG-003, NATURAL EVENTS CRS 1. Determine appropriate attachment for Natural Event from Table below:

EVENT ATTACHMENT EARTHQUAKE A TORNADO B FLOODING C COOLING DAM FAILURE D CRS transitions to ATTACHMENT A, EARTHQUAKE CRS 2. Go to appropriate Attachment for Natural Event CRS ENTER and DIRECT ATTACHMENT A, EARTHQUAKE RESPONSE CRS A1. Check earthquake magnitude - GREATER ENOUGH TO START SEISMIC RECORDER o Annun 00-098E, SEISMIC RECORDER ON - LIT o Earthquake effects - SEEN, FELT OR HEARD DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 5 Page 32 of 54_

Event

Description:

Seismic event Main Feed Pump trip Reactor trip Time Position Applicants Actions or Behavior CRS, RO, BOP A2. Stabilize plant conditions:

a. Stop all plant evolutions.

b. Maintain steady state conditions.

c. Ensure vital plant parameters - STABLE o Reactor power o RCS temperature o RCS flow o PZR pressure o PZR level o SG level o SG pressure o Turbine load Examiner NOTE: Event 5 and Diagnostics: Three minutes post Seismic event, the only running Main Feed Pump trips. MCB alarm 00-123A, MFP B TRIP, annunciates. An automatic reactor trip/turbine trip will not occur. The crew recognizes the loss of Main Feedwater will ultimately lead to LOLO Steam Generator Reactor trip (23.5%). Therefore the CRS may order the Reactor trip PRIOR to reaching the setpoint.

CREW Identifies Main Feedwater Pump B has tripped.

CREW Determine reactor trip imminent.

CRS ORDER Reactor trip and performance of EMG E-0 Immediate Actions RO/BOP Identify and report that the Reactor did not trip RO - SB HS manipulated by RO and Reactor trip breakers do not open BOP - SB HS manipulated by BOP and Reactor trip breakers do not open DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 33 of 54_

Event

Description:

Anticipated Transient Without Trip (ATWT)

Time Position Applicants Actions or Behavior Diagnostics: DRPI displays all rods at current positions. Reactor trip and bypass breakers are closed.

CRS ENTER and DIRECT EMG E-0, REACTOR TRIP OR SAFETY INJECTION RO 1. Verify Reactor Trip

a. Check all rod bottom lights - LIT; No, Perform RNO 1RNO: Manually trip reactor. If reactor power is greater than or equal to 5% or intermediate range power is increasing, then perform the following:

1. Direct operator to monitor Critical Safety Functions using EMG F-0, CRITICAL SAFETY FUNCTION STATUS TREES (CSFST)

2. Go to EMG FR-S1, RESPONSE TO NUCLEAR POWER GENERATION/ATWS CRS DIRECT performance of Immediate Actions of EMG FR-S1, RESPONSE TO NUCLEAR POWER GENERATION/ATWS Examiner NOTE: Steps 1 and 2 of EMG FR-S1 are Immediate Action steps.

RO, BOP Perform Immediate Action (step 1and step 1RNO) of EMG FR-S1, RESPONSE TO NUCLEAR POWER GENERATION/ATWS

1. Verify reactor trip:

a. Check all rod bottom lights - LIT; No, Perform RNO:

1RNO: Perform the following:

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 34 of 54_

Event

Description:

Anticipated Transient Without Trip (ATWT)

CT success: Insert negative reactivity into the core by at least one of the following methods before the Steam Generators dry-out:

o De-energize the control rod drive MG sets o Manually insert control rods Time Position Applicants Actions or Behavior RO; BOP Step 1RNOa cont.: Perform the following:

1. Manually trip reactor (RO and BOP performed)

2. If reactor will not trip, then perform the following:

(CT RO action, Manual rods) a. Insert control rods in automatic or manual.

(CT BOP action post step 2 completion) b. Manually deenergize rod drive motor generators

1) Open the following breakers:

o PG HIS-16 o PG HIS-18

2) If load center PG20 does not deenergize, then open 13.8 KV bus to XPG14 BKR PA0207 o PG HIS-3 (RO action) 3) Dispatch operator to locally open reactor trip breakers and bypass breakers (BOP action) 4) When reactor trip and bypass breakers have been opened or all rod bottom lights are lit, the close the following breakers:

o PG HIS-16 o PG HIS-18

5) Continue with step 2 CT is successfully completed when the control rods are fully inserted by either manual insertion or de energized PG breakers, removing power from the rod control system.

Booth cue: Respond as Building watch and locally open the reactor trip and bypass breakers. Insert KEY 10 to open the breakers. When complete, report back to the Control Room that the breakers are open.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 6 Page 35 of 54_

Event

Description:

The turbine will not trip manually CT success: Manually trip the turbine within thirty seconds to prevent an uncontrolled cooldown of the RCS due to steam flow that the turbine would require.

Time Position Applicants Actions or Behavior Examiner NOTE: The turbine will not trip. The BOP determines the turbine is not tripped while performing the Immediate Actions of EMG FR-S1, RESPONSE TO NUCLEAR POWER GENERATION/ATWS. The BOP must trip the turbine per the RNO of EMG FR-S1, step 2. (The reactor trip signal should trip the turbine.

However, the reactor trip signal did not occur, so the turbine did not receive its trip signal either.)

Diagnostics: During the performance of EMG FR-S1 Immediate actions, the BOP determines the turbine did not trip (all four MAIN STOP valves remain open).

BOP 2. Verify Turbine trip:

a. Check the following:

Main Stop valves - ALL CLOSED or; No; Stop valves are not closed; Perform RNO Turbine Auto Stop bistable lights - AT LEAST TWO LIT; No, Perform RNO 2RNOa. Perform the following:

1) Manually trip the turbine (BOP depressed TRIP pushbutton on panel AC XX-1, MAIN TURB EHC OPER PANEL) - turbine does not trip

2) If turbine will not trip, then perform the following in any order: (CT success actions follow)

(CT) Manually runback turbine (LOAD LIMIT SET potentiometer dialed in the counterclockwise direction; Depressing the DECREASE LOAD pushbutton on the LOAD SELECTOR is also acceptable) or (CT) Place EHC pumps in Pull-to-Lock o CH HIS-1A o CH HIS-1B or Direct operator to locally trip turbine at front standard

3) If turbine can not be runback or tripped, then close main steam isolation valves and main steam bypass valves AB HS-79 AB HS-80 CT is successfully completed when BOP isolates steam to the main turbine -- Manually runback turbine using the potentiometer or by placing the EHC pumps in Pull-to-Lock, within thirty seconds.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 36 of 54_

Event

Description:

Anticipated Transient Without Trip (ATWT)

Time Position Applicants Actions or Behavior CRS ENTER and DIRECT EMG FR-S1, RESPONSE TO NUCLEAR POWER GENERATION/ATWS RO 1. Verify Reactor trip:

a. Check all rod bottom lights - LIT; Originally No - Perform RNO - performed by RO and BOP; Currently - Yes, all rod bottom lights are LIT

b. Currently, Yes - Waiting on Building Watch to open the breakers

c. Check intermediate range neutron flux - DECREASING BOP 2. Verify Turbine trip

a. Check the following:

Main Stop valves - ALL CLOSED or Turbine Auto stop bistable lights - AT LEAST TWO LIT Originally - BOP had to manually trip the Main turbine by performance of the RNO; Currently the turbine is tripped - steam isolated from turbine.

BOP 3. Check Main Generator Breakers and Exciter Breakers - OPEN o MA ZL-3A o MA ZL-4A o MA ZL-2 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 7 Page 37 of 54_

Event

Description:

Anticipated Transient Without Trip (ATWT)

Event 7: BG HV-8104 does not open, align RWST to charging pump suction Time Position Applicants Actions or Behavior BOP 4. Verify AFW pumps running:

a. Check motor driven AFW pumps - BOTH RUNNING o AL HIS-22A o AL HIS-23A

b. Check turbine driven AFW pump - RUNNING RO 5. Check SI - NOT IN PROGRESS o CCPs - ALIGNED FOR NORAL CHARGING o SI pumps - NONE RUNNING IN INJECTION MODE o RHR pumps - NONE RUNNING IN INJECTION MODE RO 6. Initiate Emergency Boration of RCS

a. Ensure one of the following pumps is running:

BG HIS-1A for CCP A BG HIS-2A for CCP B BG HIS-3 for NCP

b. Align boration flow path:

1) Ensure boric acid transfer pumps - AT LEAST ONE RUNNING BG HIS-5A BG HIS-6A

2) Open Emergency Borate to Charging Pump Suction valve o BG HIS-8104; No, Perform RNO 6RNOb2 Align RWST to charging pump suction: see next page DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 7 Page 38 of 54_

Event

Description:

Event 7: BG HV-8104 does not open, align RWST to charging pump suction. Step 6 RNO action Time Position Applicants Actions or Behavior RO 6RNOb2 cont. Align RWST to charging pump suction:

a. Ensure charging pump suction from RWST - AT LEAST ONE OPEN BN HIS-112D BN HIS-112E

b. Ensure VCT outlet valves - AT LEAST ONE CLOSED BG HIS-112B BG HIS-112C RO 7. Verify charging flow path:

a. Ensure charging pumps to Regenerative Heat Exchanger Containment isolation valves - OPEN o BG HIS-8105 o BG HIS-8106

b. Ensure Regenerative Heat Exchanger to Loop cold leg valves - ONLY ONE OPEN BG HIS-8146 for Loop 1 or BG HIS-8147 for Loop 4

c. Adjust charging flow to maintain PZR level BG FK-121 for CCP or BG FK-462 for NCP

d. Adjust charging header back pressure control as necessary to establish between 8 gpm and 13 gpm seal injection flow to each RCP o BG HC-182 RO 8. Check Emergency Borate flow - GREATER THAN 30 GPM; No, Perform RNO o BG FI-183A DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 39 of 54_

Event

Description:

Anticipated Transient Without Trip (ATWT)

Time Position Applicants Actions or Behavior RO Step 8RNO Perform the following:

a. Align RWST to charging pump suction:

1. Ensure charging pumps suction from RWST - AT LEAST ONE OPEN BN HIS-112D BN HIS-112E

2. Ensure VCT outlet valves - AT LEAST ONE CLOSED BG HIS-112B BG HIS-112C

b. Ensure RWST flow through charging system - GREATER THAN 90 GPM BG HIS-121A or EM FI-917A or EM FI-917B RO 9. Check PZR pressure - LESS THAN 2335 PSIG BOP 10. Verify Containment Purge Isolation:

a. Check ESFAS status panel CPIS section -ALL WHITE LIGHTS LIT; No, Perform RNO o Red train o Yellow train 10RNOa. Perform the following:

1) If Containment purge isolation has not actuated, then manually actuate containment purge isolation.

o SA HS-11 o SA HS-15

b. If any CPIS component not properly aligned, then manually align component.

If component(s) can not be aligned, then manually or locally isolate affected containment penetration. Refer to Attachment B.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 40 of 54_

Event

Description:

Anticipated Transient Without Trip (ATWT)

Time Position Applicants Actions or Behavior RO 11. Check Safety Injection NOT actuated o Annun 00-030A, NF039A LOCA SEQ ACTUATED - CLEAR and o Annun 00-031A, NF039B LOCA SEQ ACTUATED - CLEAR and o ESFAS status panel SIS sections- NO WHITE LIGHTS LIT and o Partial Trip Status Permissive / Block status panel - SI RED LIGHT NOT LIT RO/BOP 12. Check if the following trips have occurred:

a. Reactor trip

b. Turbine trip RO 13. Verify Reactor subcritical:

a. Power range channels [GAMMA METRICS] - LESS THAN 5%

b. Intermediate range channels - NEGATIVE STARTUP RATE [GAMMA METRICS - STABLE OR DECREASING]

c. Go to step 25 RO 25. Check Reactor Trip Breakers - OPEN RO 26. Continue boration until adequate shutdown margin is obtained.

BOP 27. Check CRDM fans - ALL RUNNING; No, Perform RNO o GN HIS-42 o GN HIS-43 o GN HIS-44 27RNO Start all available CRDM fans.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 41 of 54_

Event

Description:

EMG E-0, REACTOR TRIP OR SAFETY INJECTION Time Position Applicants Actions or Behavior CRS 28. Return to procedure and step in effect.

CRS LEAD a transition brief prior to entering EMG E-0.

CRS ENTER and DIRECT EMG E-0, REACTOR TRIP OR SAFETY INJECTION RO 1. Verify reactor trip

a. Check all rod bottom lights - LIT

b. Ensure reactor trip and bypass breakers - OPEN o SB ZL-1 o SB ZL-2 o SB ZL-3 o SB ZL-4

c. Check intermediate neutron flux - DECREASING o SE NI-35B o SE NI-36B BOP 2. Verify turbine trip:

a. Check the following:

Main Stop valves - ALL CLOSED or Turbine Auto Stop bistable lights - AT LEAST TWO LIT DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 42 of 54_

Event

Description:

EMG E-0, REACTOR TRIP OR SAFETY INJECTION Time Position Applicants Actions or Behavior RO 3. Check AC Emergency busses - AT LEAST ONE ENERGIZED NB01 - ENERGIZED NB02 - ENERGIZED RO/ BOP 4. Check is Safety Injection is actuated:

a. Check any indication SI is actuated - LIT; if NO, Perform RNO Annun 00-030A, NF039A LOCA SEQ ACTUATED - LIT Annun 00-031A, NF039B LOCA SEQ ACTUATED - LIT ESFAS status panel SIS section - ANY WHITE LIGHTS LIT Partial Trip Status Permissive / Block status panel - SI RED LIGHT LIT

b. Check both trains of SI actuated o Ann 00-030A, NF039A LOCA SEQ ACTUATED - LIT o Ann 00-031A, NF039B LOCA SEQ ACTUATED - LIT 4RNOa. Perform the following:

1) Check SI required:

RCS pressure - LESS THAN OR EQUAL TO 1830 PSIG or Any SG pressure - LESS THAN OR EQUAL TO 615 PSIG or Containment pressure - GREATER THAN OR EQUAL TO 3.5 PSIG or RSC subcooling - LESS THAN 30°F [45°F] or PZR level- LESS THAN 6% [33%]

2) If SI is required, then manually actuate SI and go to step 6.

o SB HS-27 o SB HS-28

3) If SI is not required, then perform the following:

a. Direct operator to monitor Critical Safety Functions using EMG F-0, CRITICAL SAFETY FUNCTION STATUS TREES (CSFST)

b. Go to EMG ES-02, REACTOR TRIP RESPONSE, step 1 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 43 of 54_

Event

Description:

EMG ES-02, REACTOR TRIP RESPONSE If no SI is actuated, EMG ES-02 is entered. If SI is actuated, crew continues in EMG E-0 and transitions to EMG ES-03, SI TERMINATION Time Position Applicants Actions or Behavior CRS Direct STA to perform and monitor Critical Safety Functions using EMG F-0, CRITICAL SAFETY FUNCTION STATUS TREES (CSFST).

CRS LEAD a transition brief prior to entering EMG ES-02, REACTOR TRIP RESPONSE.

CREW Enter EMG ES-02, REACTOR TRIP RESPONSE, step 1.

CRS ENTER and DIRECT EMG ES-02, REACTOR TRIP RESPONSE RO/ BOP 1. Check RCS cold leg temperatures:

Stable at or trending to 557°F for condenser steam dumps Stable at or trending to 561°F for SG ARVs 1RNOa. Perform the following:

a. If temperature is less than setpoint and decreasing, then perform the following:

1) Stop dumping steam

2) Ensure SG BD CTMT ISO valves are closed.

o BM HIS-1A o BM HIS-2A o BM HIS-3A o BM HIS-4A

3) If any MSIV is open, then close Main Turbine Stop and Control Valves Startup Drains.

o AC HIS-134 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 44 of 54_

Event

Description:

EMG ES-02, REACTOR TRIP RESPONSE Time Position Applicants Actions or Behavior RO/ BOP Step 1RNOa. Cont.

4) If cooldown continues, then control total feed flow to limit RCS cooldown. Maintain total feed flow greater than 270,000 lbm/hr until narrow range level greater than 6% in at least one SG.

5) If cooldown continues due to excessive steam flow, then isolate main steamlines by depressing both MS ISO VLV ALL CLOSE pushbuttons.

o AB HS-79 o AB HS-80

b. If temperature is greater than setpoint and increasing, then perform one of the following:

Dump steam to condenser Dump steam using SG ARVs RO 2. Check RCS cold leg temperatures - GREATER THAN OR EQUAL TO 550°F BOP 3. Check Main Generator Breakers and Exciter Breaker - OPEN o MA ZL-3A o MA ZL-4A o MA ZL-2

4. Check Feedwater status:

a. Check RCS average temperature - LESS THAN 564°F

b. Check Main Feedwater Pumps - TRIPPED o Annun 00-120A, MFP A TRIP - LIT o Annun 00-123A, MFP B TRIP - LIT DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 45 of 54_

Event

Description:

EMG ES-02, REACTOR TRIP RESPONSE Time Position Applicants Actions or Behavior BOP Step 4 cont.

c. Check Main Feedwater Isolation Valves - CLOSED o AE HIS-39 for SG A o AE HIS-40 for SG B o AE HIS-41 for SG C o AE HIS-42 for SG D

d. Check total feed flow to SGs - GREATER THAN 270,000 LBM/HR Lead Examiner may terminate scenario at their discretion.

Booth - terminate scenario at direction of Lead Examiner. FREEZE DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 46 of 54_

Event

Description:

EMG E-0 continuation to EMG ES-03, SI TERMINATION Time Position Applicants Actions or Behavior RO 5. Check if SI required:

SI was manually actuated and required RCS pressure is currently or has been - LESS THAN OR EQUAL TO 1830 PSIG Any SG pressure is currently or has been - LESS THAN OR EQUAL TO 615 PSIG Containment pressure is currently or has been - GREATER THAN OR EQUAL TO 3.5 PSIG RCS subcooling is currently or has been - LESS THAN 30°F [45°F]

PZR level is currently or has been - LESS THAN 6% [33%]

Examiner NOTE: The crew may have actuated SI based on PZR level. EMG E-0 Fold out page criteria 2, SI ACTUATION allows for a SI actuation based on subcooling or PZR level. Once the crew enters EMG E-0 from EMG FR-S1, the foldout page applied.

BOP 6. Check Main Generator Breakers and Exciter Breaker - OPEN o MA ZL-3A o MA ZL-4A o MB ZL-2 CRS 7. Verify Automatic Actions using Attachment F, AUTOMATIC SIGNAL VERIFICATION CRS DIRECT either the RO or the BOP to perform the Attachment F, AUTOMATIC SIGNAL VERIFICATION Examiner NOTE: see page 54 for a brief Attachment F, AUTOMATIC SIGNAL VERIFICATION DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 47 of 54_

Event

Description:

EMG E-0 continuation to EMG ES-03 Time Position Applicants Actions or Behavior BOP 8. Check total AFW flow - GREATER THAN 270,000 LBM/HR BOP 9. Check RCS cold leg temperatures; if NO, Perform RNO Stable at or trending to 557°F for condenser steam dumps Stable at or trending to 561°F for SG ARVs Step 9RNO. Perform the following:

a. If temperature is less than setpoint and decreasing, then perform the following:

1. Stop dumping steam

2. If any MSIV is open, then close Main Turbine Stop and Control Valves Startup Drains.

o AC HIS-134

3. If the cooldown continues, then control total feed flow to limit RCS cooldown. Maintain total feed flow greater than 270,000 lbm/hr until narrow range level greater than 6% [29%] in at least one SG.

BOP 10. Establish SG pressure control:

a. Check condenser - AVAILABLE o C-9 LIT o MSIV - OPEN o Circulating water pumps - RUNNING

b. Place Steam Header Pressure Control in manual o AB PK-507

c. Manually set Steam Header Pressure Control output to zero o AB PK-507

d. Place Steam Dump Select Switch in STEAM PRESS position o AB US-500Z DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 48 of 54_

Event

Description:

EMG E-0 continuation to EMG ES-03 Time Position Applicants Actions or Behavior BOP Step 10 cont

e. Place Steam Header Pressure Control in automatic o AB PK-507 RO 11. Check PZR PORVs

a. Check PZR PORVs - CLOSED o BB HIS-455A o BB HIS-456A

b. Power to block valves - AVAILABLE o BB HIS-8000A o BB HIS-8000B

c. RCS pressure - LESS THAN 2185 PSIG RO 12. Check Normal PZR Spray valves - CLOSED o BB ZL-455B o BB ZL-455C RO 13. Check PZR Safety Valves - CLOSED o BB ZL-8010A o BB ZL-8010B o BB ZL-8010C DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 49 of 54_

Event

Description:

EMG E-0 continuation to EMG ES-03 Time Position Applicants Actions or Behavior RO 14. Check if any RCPs should be stopped:

a. Check RCPs - ANY RUNNING

b. Check RCS pressure - LESS THAN 1400 PSIG; No, Perform RNO 14RNOb. Go to step 15.

CRS 15. Direct Operator to monitor Critical Safety Functions using EMG F-0, CRITICAL SAFETY FUNCTION STATUS TREES (CSFST).

CRS DIRECT surrogate STA to perform EMG F-0, CRITICAL SAFETY FUNCTION STATUS TREES (CSFST).

BOP 16. Check if SGs are not faulted:

a. Check pressures in all SGs -

o NO SG PRESSURE DECREASING IN AN UNCONTROLLED MANNER o NO SG COMPLETELY DEPRESSURIZED RO/ BOP 17. Check if SG tubes are intact:

Direct Health Physics to survey steam lines on Area 5 of the Aux Building Condenser sir discharge - NORMAL BEFORE ISOLATION (GEG 925)

SG blowdown and sample radiation - NORMAL BEFORE ISOLATION o BML 256 o SJL 026 Turbine driven auxiliary feedwater pump exhaust radiation - NORMAL o FCT 381 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 50 of 54_

Event

Description:

EMG E-0 continuation to EMG ES-03 Time Position Applicants Actions or Behavior RO/ BOP Step 17 cont.

SG steam line radiation - NORMAL o ABS 114 for SG A o ABS 113 for SG B o ABS 112 for SG C o ABS 111 for SG D BOP 18. Check SG levels - INCREASING IN A CONTROLLED MANNER o Narrow range o Wide range BOP 19. Check if RCS in intact in Containment:

a. Containment radiation - NORMAL BEFORE ISOLATION o GTP 311 o GTI 312 o GTG 313 o GTP 321 o GTI 322 o GTG 323 o GTA 591 o GTA 601

b. Containment pressure - NORMAL o GN PI-934 o GN PI-935 o GN PI-936 o GN PI-937 o GT PDI-40 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 51 of 54_

Event

Description:

EMG E-0 continuation to EMG ES-03 Time Position Applicants Actions or Behavior RO Step 19 cont.

o GN PR-934

c. Containment sump level - NORMAL o EJ LI-7 o EJ LI-8 o EJ LR-6 o LF LI-9 o LF LI-10 RO 20. Check if ECCS flow should be reduced:

a. RCS subcooling - GREATER THAN 30°F

b. Secondary heat sink:

Total feed flow to SGs - GREATER THAN 270,000 LBM OR Narrow range level in at least one SG - GREATER THAN 6%

c. RCS pressure - STABLE OR INCREASING

d. PZR level - GREATER THAN 6%

e. Go to EMG ES-03, SI TERMINATION CRS LEAD a transition brief prior to entering EMG ES-03, SI TERMINATION.

CREW Enter EMG ES-03, SI TERMINATION CRS ENTER and DIRECT EMG ES-03, SI TERMINATION DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 52 of 54_

Event

Description:

EMG ES-03, SI TERMINATION Time Position Applicants Actions or Behavior RO 1. Reset SI o SB HS-42A o SB HS-43A RO 2. Reset Containment Isolation Phase A and Phase B o SB HS-56 for phase A o SB HS-53 for phase A o SB HS-55 for phase B o SB HS-52 for phase B BOP 3. Verify Instrument Air Alignment:

a. Ensure at least one ESW TRN TO AIR COMPRESSOR valve - OPEN EF HIS-43 EF HIS-44

b. Check AIR COMPRESSOR BRKR RESET switch associated with open ESW valve - CLOSED; if NO, Perform RNOb KA HIS-2C KA HIS-3C 3RNOb Reset and close AIR COMPRESSOR BRKR RESET switch KA HIS-2C KA HIS-3C

c. Check INST AIR PRESS - GREATER THAN 105 PSIG o KA PI-40

d. Check PZR PRESS MASTER CTRL output - LESS THAN 50%

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 53 of 54_

Event

Description:

EMG ES-03, SI TERMINATION Time Position Applicants Actions or Behavior RO Step 3 cont.

e. Check neither ESW TO AIR COMPRESSOR valve - LOCALLY OPENED o EF HV-43 o EF HV-44

f. Open INST AIR SPLY CTMT ISO VLV o KA HIS-29 RO 4. Reduce charging flow:

a. Check shutdown sequencers - NOT ACTUATED:

o Annunciator 00-018C, NF039A S/D SEQ ACTUATED - CLEAR o Annunciator 00-021C, NF039B S/D SEQ ACTUATED - CLEAR

b. Stop all but one CCP and place in standby BG HIS-1A or BG HIS-2A When CCP has been stopped or at Lead Examiner direction, terminate scenario.

Booth: Terminate scenario at Lead Examiner direction. FREEZE DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 3 Event No.: 5 Page 54 of 54_

Event

Description:

Brief EMG E-0, ATTACHMENT F, AUTOMATIC SIGNAL VERIFICATION Time Position Applicants Actions or Behavior RO/ BOP F1. Verify Feedwater Isolation F2. Verify Containment Isolation Phase A F3. Verify AFW pumps running F4. Verify EEC pumps running F5. Verify CCW alignment F6. Check ESW pumps - BOTH RUNNING F7. Check Containment Fan Coolers - RUNNING IN SLOW SPEED F8. Verify Containment Purge Isolation F9. Verify both trains of Control Room Ventilation Isolation F10. Verify Main Steamline Isolation not required F11. Verify Containment Spray not required F12. Verify ECCS flow F13. Verify AFW valves - PROPERLY ALIGNED F14. Verify SI - valves - PROPERLY ALIGNED F15. Check if NCP should be stopped F16. Return to procedure and step in effect DRAFT

Appendix D Scenario Outline Form ES-D-1 Facility: ___Wolf Creek_____________ Scenario No.: ___4 Backup_____ Op-Test No.: _______

Examiners: ____________________________ Operators: _____________________________

Initial Conditions: ~74%, EOL Turnover: LaCygne line returned to service. CCP A is DNOd (TEST CAUTION tag) and in Pull to Lock (PTL) for Preventative Maintenance activities (motor PMs). TS 3.5.2 Cond A, 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. Expect return to service in 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. Boron Thermal Regeneration System (BTRS) is in service. Control Rods are in Manual.

Event Malf. Event Event No. No. Type* Description st 1 trACPT0 I - BOP, High Pressure Turbine 1 Stage Pressure AC PT-505 fails high 505 SRO TS determined & entered. TS 3.3.1, Table 3.3.1-1 Fu 18f. Cond A (Immediately) and Cond T (verify P-13 interlock in correct state within one hour) are entered.

2 mSF13K C- Control Rod M4 drops to 96 steps 6 ATC, SRO DRPI indicates changes in control rod position.

mSF04K 6

TS determined & entered. TS 3.1.4 Cond B (restore rod to within alignment limits within one hour) 3 mBB02A M- Primary to Secondary leak on Steam Generator A.

CREW Initially, a 10-gpm leak.

TS determined & entered. TS 3.4.13 d 150 gpd primary to secondary leakage through any one Steam Generator exceeded; Cond B1 and B2 (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 /> and Mode 5 in 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />) 4 R- Decrease power per OFN MA-038, RAPID PLANT SHUTDOWN at CREW 1%/min rate.

5 mBB02A M- Primary to Secondary leakrate increases requiring Reactor trip and CREW Safety Injection signal actuation.

200-350 gpm 6 mBG27 C- Post trip malfunction #1: CCP B autostart failure upon receipt of B ATC, Safety Injection SRO DRAFT 1 of 5

7 mSA27E C- Post trip malfunction #2: Autoclose feature for Service Water/ESW F01 ATC, Train A Cross Connect valves EF HV-0023 and EF HV-0025 fails SRO and the valves remain open.

mSA27E F03 vmodAB Preloaded: These ensure the MSIVs remain open, allowing HV0011 transition to EMG C-31, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED from step vmodAB 5RNO of EMG E-3, STEAM GENERATOR TUBE RUPTURE HV0014 vmodABHV0011 - SG D MSIV fails open vmodAB HV0017 vmodABHV0014 - SG A MSIV fails open (ruptured SG) vmodAB vmodABHV0017 - SG B MSIV fails open HV0020 vmodABHV0020 - SG C MSIV fails open 8 M- Transition to and perform EMG C-31, SGTR WITH LOSS OF CREW REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor DRAFT 2 of 5

Scenario summary:

The unit is at ~74% power, end of life. Turnover items include the LaCygne line has been returned to service. CCP A is DNOd (TEST CAUTION) and in Pull to Lock (PTL) for Preventative Maintenance activities (motor PMs). Technical Specification (TS) 3.5.2 Condition A was entered (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to restore). CCP A return to service expected within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. Boron Thermal Regeneration System (BTRS) is in service. Control Rods are in Manual.

st Event 1: High Pressure Turbine 1 Stage Pressure AC PT-505 fails high. Meter indication change. MCB alarms 00-065D, T REF/T AUCT HI, and 00-130F, LO TEMP AVG/ERR annunciate. OFN SB-008, INSTRUMENT MALFUNCTIONS is entered, and Attachment D performed. OFN SB-008 diagnoses and mitigates the instrument failure.

The Control Room Supervisor determines Technical Specifications.

Event 2: Control Rod M4 drops to 96 steps. DRPI indicates changes in control rod position. The Crew determines that no load rejection in progress and stops rod motion. Main Control Board alarms 00-078A, PR CHANNEL DEV, 00-078B, PR UPPER DETECTOR FLUX DEV PR LOWER DETECTOR DEV, 00-079A, ROD CTRL URG FAIL and 00-080C, RPI ROD DEV annunciate.

OFN SF-011, REALIGNMENT OF DROPPED, MISALIGNED ROD(S) AND ROD CONTROL MALFUNCTIONS, is entered and performed. Instrumentation & Calibration technicians report a loose cable was discovered (regulation failure) and has been restored. The dropped control rod is recovered.

The Control Room Supervisor determines Technical Specifications.

Event 3: The Main Event is a Primary to Secondary leak that becomes a rupture on Steam Generator A. The event is complicated when the MSIVs fail open (see Event 8 below).

Main Control Board alarms 00-061B, PROCESS RAD HI and 00-061A, PROCESS RAD HIHI annunciate. Process radiation monitor GE RE-92, Condenser Off gas monitor, is in Alert/High alarm. A primary to secondary tube leak is suspected and OFN BB-07A, STEAM GENERATOR TUBE LEAKAGE, is entered and performed.

Event 4: A plant shutdown is required. The Crew enters and performs OFN MA-038, RAPID PLANT SHUTDOWN, to perform a power decrease at 1%/min rate.

Event 5: The Crew determines the leak rate has increased and utilizes OFN BB-07A, STEAM GENERATOR TUBE LEAKAGE, Foldout page criteria #1 to direct a Reactor trip and Safety Injection signal actuation.

EMG E-0, REACTOR TRIP OR SAFETY INJECTION, is entered and performed. The Crew transitions to and performs EMG E-3, STEAM GENERATOR TUBE RUPTURE. The ruptured Steam Generator is identified and isolated.

Event 8: Preloaded into the scenario: all four MSIVs remain open. The MSIVs will not close, requiring a transition to EMG C-31, SGTR WITH LOSS OF REACTOR COOLANT -

SUBCOOLED RECOVERY DESIRED. In EMG C-31, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED, the Crew will initiate an RCS cooldown and depressurization.

Post trip malfunctions:

Event 6: CCP B autostart failure upon receipt of Safety Injection signal actuation. Manual start is available. Recall CCP A was tagged out for preventative maintenance activities. This component failure is addressed by either post Immediate Actions performance/ Equipment concerns or during performance of EMG E-0, REACTOR TRIP OR SAFETY INJECTION, Attachment F, step 4RNO.

DRAFT 3 of 5

Event 7: Autoclose feature for Service Water/ESW Train A Cross Connect valves EF HV-0023 and EF HV-0025 fails and the valves remain open. Manual closure is available. This component failure is procedurally addressed during the performance of EMG E-0, REACTOR TRIP OR SAFETY INJECTION, Attachment F, step F14RNO.

Scenario Critical Tasks (CT):

Event 5: CT: Isolate feed flow to the ruptured SG before Steam Generator overfills. Performed at EMG E-0, REACTOR TRIP OR SAFETY INJECTION Foldout page # 4.

Event 8: CT: Initiate Cooldown of the RCS to Cold Shutdown conditions at the highest rate achievable but less that 100°F per hour to minimize leakage of Reactor Coolant and radiological releases from the ruptured Steam Generator. Performed at EMG C-31 SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED, step 22.

DRAFT 4 of 5

Probabilistic Risk Analysis for this scenario includes:

Core Damage Frequency by Initiating Event Initiating Event Core Damage CDF Percent Initiating Event Frequency (/yr) Frequency (/yr) Contribution Loss of Offsite Power 2.88E-02 6.59E-06 36.51%

Small LOCA 29.63%

3.00E-03 5.35E-06 Interfacing Systems LOCA 1.93E-06 10.69%

Very Small LOCA 7.03%

6.20E-03 1.27E-06 Transients With Power Conversion Systems Available 1.05E+00 9.88E-07 5.47%

Steam Generator Tube Rupture 3.67E-03 8.77E-07 4.86%

Reactor Vessel Failure 3.00E-07 3.00E-07 1.66%

Steamline Break 1.13E-02 1.88E-07 1.04%

Transients Without Power Conversion 1.15E-01 1.71E-07 0.95%

Systems Available Medium LOCA 6.10E-05 1.46E-07 0.81%

Loss of All Service Water 6.86E-06 8.30E-08 0.46%

Loss of Component Cooling Water 2.14E-04 5.79E-08 0.32%

Loss of Vital DC Bus NK04 2.64E-03 4.32E-08 0.24%

Large LOCA 7.20E-06 2.80E-08 0.16%

Feedwater Line Break 3.17E-03 2.06E-08 0.11%

Loss of Vital DC Bus NK01 2.64E-03 1.12E-08 0.06%

Technical Specifications exercised:

Event 1: TS determined & entered. TS 3.3.1, Table 3.3.1-1 Fu 18f. Cond A (Immediately) and Cond T (verify P-13 interlock in correct state within one hour) are entered.

Event 2: TS determined & entered. TS 3.1.4 Cond B (restore rod to within alignment limits within one hour)

Event 3: TS determined & entered. TS 3.4.13 d 150 gpd primary to secondary leakage through any one Steam Generator exceeded; Cond B1 and B2 (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 /> and Mode 5 in 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />)

DRAFT 5 of 5

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 1 Page 1 of 45_

Event

Description:

High Pressure Turbine 1st Stage Pressure AC PT-505 fails high Time Position Applicants Actions or Behavior BOOTH: Setup scenario and simulator. At Lead Examiner cue, insert KEY 1 for first event.

Diagnostics: High Pressure Turbine 1st Stage Pressure AC PT-505 fails high. Meter AC PI-505, HP TURBINE 1ST STG PRESSURE indication fails high. Control Rods are in AUTO - and step out. MCB alarms 00-065D, T REF/T AUCT HI, and 00-130F, LO TEMP AVG/ERR annunciate.

CREW Identify and Diagnose High Pressure Turbine 1st Stage Pressure AC PT-505 high failure.

CRS ENTER and DIRECT OFN SB-008, INSTRUMENT MALFUNCTIONS Procedure NOTE: Steps 1 through 8 can be done in any order.

CRS, BOP 1. Check if Secondary System instrument channel is malfunctioning:

a. Determine appropriate attachment for malfunctioning channel from table below:

Turbine Impulse Pressure (AC) P-505 Attachment D

b. Go to appropriate attachment for malfunctioning secondary system channel.

CRS ENTER and DIRECT ATTACHMENT D, TURBINE IMPULSE PRESSURE CHANNEL MALFUNCTION Procedure NOTE: Steps D1 and D2 are Memory Action steps.

BOP D1. Identify failed instrument channel:

a. Compare HP TURBINE 1ST STG PRESS indications to confirm a pressure channel failure:

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 1 Page 2 of 45_

Event

Description:

High Pressure Turbine 1st Stage Pressure AC PT-505 fails high Time Position Applicants Actions or Behavior BOP Step D1 cont.

o AC PI-505 o AC PI-506

b. Determine which channel is failed by comparing actual indications with expected indications using table below:

(Examiner NOTE: partial table)

REACTOR POWER TURBINE IMPULSE PRESSURE (PSIG) 60% 433 70% 505 80% 577 RO D2. Place ROD BANK AUTO/MAN SEL in manual.

o SE HS-9 BOP D3. Check failed HP TURBINE 1ST STG PRESS channel selected on HP TURB 1ST STG PRESS SEL switch.

o AC PS-505Z BOP D4. Select alternate HP TURBINE 1ST STG PRESS channel using HP TURB 1ST STG PRESS SEL switch.

o AC PS-505Z DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 1 Page 3 of 45_

Event

Description:

High Pressure Turbine 1st Stage Pressure AC PT-505 fails high Time Position Applicants Actions or Behavior CRS, RO D5. () Adjust rods to return Tavg equal to programmed Tref for existing plant power. (Examiner NOTE: partial table listed below)

REACTOR POWER (%) Tref (°F) 60% 574.7 70% 577.7 80% 580.6 CRS, RO D6. Check Tavg - WITHIN 1°F OF TREF; if No, Perform RNO D6RNO. Return to step D5 RO D7. Place ROD BANK AUTO/MAN SEL in auto.

o SE HS-9 BOP D8. Place STEAM DUMP BYPASS INTERLOCK to - OFF o AB HS-63 o AB HS-64 RO D9. Monitor Rod Control response to ensure proper control Procedure NOTE: It may take several minutes for the C-7 Loss Of Load interlock to clear after the failed channel is selected out. The time is dependent on how AC PT-505 or AC PT-506 failed.

BOP D10. Check C-7 Loss of Load interlock - NOT LIT; If No, Perform RNO o AB US-500Z D10RNO: Reset C-7 using STEAM DUMP SEL switch (AB US-500Z)

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 1 Page 4 of 45_

Event

Description:

High Pressure Turbine 1st Stage Pressure AC PT-505 fails high Time Position Applicants Actions or Behavior BOP D11. Select Steam Pressure Mode:

a. Set STEAM HDR PRESS CTRL to 7.28 o AB PK-507

b. Place STEAM DUMP SEL in steam pressure mode.

o AB US-500Z BOP D12. Place STEAM DUMP BYPASS INTERLOCK to - ON o AB HS-63 o AB HS-64 CRS D13. Monitor the following Technical Specification for LCOs and comply with Action Statements, as appropriate:

o 3.3.1, REACTOR TRIP SYSTEM INSTRUMENTATION, Table 3.3.1-1, Function 18.f CRS determines: TS 3.3.1, Table 3.3.1-1 Fu 18f. Cond A (Immediately) and Cond T (verify P-13 interlock in correct state within one hour) are entered.

CRS DIRECT RO or BOP to verify P-13 Interlock in correct state (LIT)

Booth cues: If contacted as Call Supt.: acknowledge plant status. If contacted as INC: acknowledge request.

Event termination: When Technical Specifications are determined and P-13 interlock state verified and/or at Lead Examiners discretion, event is terminated. Booth operator inserts KEY 2 for the next event at Lead Examiners direction.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 2 Page 5 of 45_

Event

Description:

Control Rod M4 drops to 96 steps Time Position Applicants Actions or Behavior Booth: Insert KEY 2 for event two at Lead Examiner direction.

Diagnostics: Control Rod M4 drops to 96 steps. DRPI indicates change in control rod position. Main Control Board alarms 00-078A, PR CHANNEL DEV, 00-078B, PR UPPER DETECTOR FLUX DEV PR LOWER DETECTOR DEV, 00-079A, ROD CTRL URG FAIL, 00-079C, RPI DEV OR PR TILT and 00-080C, RPI ROD DEV annunciate.

CREW Identifies control rod M4 dropped to 96 steps.

CRS ENTER and DIRECT OFN SF-011, REALIGNMENT OF DROPPED, MISALIGNED ROD(S) AND ROD CONTROL MALFUNCTIONS Procedure NOTE: Steps 1 through 4 are Memory Action steps.

RO 1. Check two or more rods - DROPPED; No, Perform RNO Two or more rod bottom lights - LIT Annun 00-081A, TWO/MORE RODS AT BOTTOM - LIT 1RNO: Go to step 3 BOP 3. Verify no load rejection in progress:

a. Generator Load MW - STABLE OR INCREASING

b. Generator Load Set MW - STABLE OR INCREASING DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 2 Page 6 of 45_

Event

Description:

Control Rod M4 drops to 96 steps Time Position Applicants Actions or Behavior RO 4. Stop Rod motion:

a. Place ROD BANK AUTO/MAN SEL switch in MAN position.

o SE HS-9

b. Verify Rod motion - STOPPED CRS 5. Stabilize plant:

a. Stop any plant operations requiring rod motion.

b. () Adjust turbine load, as necessary, to maintain Tavg within 3°F of Tref.

c. () Stop any unnecessary borations or dilutions.

Examiner NOTE: BTRS may be verified bypassed.

Procedure NOTE: Per Technical Specification 3.1.4, a rod is considered misaligned if its DRPI indication is not within 12 steps of its group step counter demand position.

CRS 6. Check for dropped rod: No, Perform RNO Rod Bottom Light - LIT or Any of following Annunciators - LIT o 00-081B, ROD AT BOTTOM 6RNO: Perform the following:

a. If two or more rods in different groups are misaligned by more than 12 steps from theist group step counter demand position, then trip the reactor and go to EMG E-0, REACTOR TRIP OR SAFETY INJECTION, step 1. (NOT Applicable)

b. If two or more rods in the same group are misaligned by more than 12 steps from their group step counter demand position, then perform the following:

1) Refer to Technical Specification 3.1.4.

2) Perform plant shutdown to HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, using the following procedures:

GEN 00-004, POWER OPERATION or DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 2 Page 7 of 45_

Event

Description:

Control Rod M4 drops to 96 steps Time Position Applicants Actions or Behavior CRS Step 6RNO cont GEN 00-005, MINIMUM LOAD TO HOT STANDBY or OFN MA-038, RAPID PLANT SHUTDOWN (NOT Applicable)

c. If any control rod(s) are misaligned from remaining rods in their associated group then go to step 16. (APPLICABLE)

CRS 16. Refer to the following applicable Technical Specifications:

o 3.1.4, Rod Group Alignment Limits o 3.1.5, Shutdown Bank Insertion Limits o 3.1.6, Control Bank Insertion Limits o 3.2.3, Axial Flux Difference o 3.2.4, Quadrant Power Tilt Ratio CRS determines: TS 3.1.4 Cond B (restore rod to within alignment limits within one hour)

Procedure NOTE: Technical Specifications require that one of the following be completed within one hour: the misaligned rod must be restored to within limits or STS RE-004, Shutdown Margin Determination must be completed.

Booth Cue: If contacted as Call Supt. - acknowledge plant status. If contacted as INC - acknowledge request. If contacted as RXE - acknowledge request.

CRS 17. Within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and at least once every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> while the rod is misaligned, perform STS RE-004, Shutdown Margin Determination CRS 18. Determine and correct cause of misaligned rod DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 2 Page 8 of 45_

Event

Description:

Control Rod M4 drops to 96 steps Time Position Applicants Actions or Behavior Booth cue: INC reports a loose cable was discovered (regulation failure) and has been restored. Insert KEY 9 to delete all rod malfunctions.

CRS 19. Check if rod can be moved at normal rate:

Rod misaligned by less than 12 steps or Rod misaligned for less than 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Procedure NOTE: Steps 20 through 25 uses DRPI to realign the misaligned rods. The misaligned rod will be positioned to the group by using the point at which DRPI detects the next coil. The direction of movement towards the coil will be in the same direction for both the group and misaligned rod.

RO 20. Initial preparation to realign rod(s)

a. Place ROD BANK AUTO/MAN SEL switch to the bank with the misaligned rod.

o SE HS-9

b. Direct I&C to locally verify rod bank selected by SE HS-9 is aligned properly, by light indications on associated cabinets.

c. At RL003, record position of group step counter for group misaligned.

o Group step counter Booth cue: When contacted as I&C report: selected to Control Bank D and proper lights are lit.

CRS 21. Check rod(s) misaligned high with respect to other rods in group: No, Perform RNO 21RNO: Go to step 22.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 2 Page 9 of 45_

Event

Description:

Retrieval of Control Rod M4 Time Position Applicants Actions or Behavior RO 22. Check rod(s) misaligned low with respect to other rods in group:

a. Check DRPI LEDs for misaligned group - LESS THAN 228 STEPS

b. Withdraw rods until next set of DRPI LEDs for misaligned group are lit.

RO 23. Final preparation to realign rod(s):

a. At lift coil disconnect panel, place all lift coil disconnect switches for other rods in affected bank to ROD DISCONNECTED position.

b. At RL003, record position of group step counter for group misaligned.

o Group step counter ________________

Examiner NOTE: Lift Coil Disconnect Panel is located in the back of the simulator Control Room.

Procedure NOTE: Steps 24 and 25 shall be performed at the same time.

BOP 24. () Adjust turbine load as necessary to maintain Tavg within 3°F of Tref Procedure NOTES:

o When motion is attempted, annunciator 00-079A, ROD CTRL URG FAIL, will be received and the URGENT FAILURE red light will be lit on the local power cabinet containing the other group of the affected bank.

o If misaligned rod is in a control group, the Pulse-to-Analog Converter switch must be held in MANUAL to maintain proper rod position information.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 2 Page 10 of 45_

Event

Description:

Retrieval of Control Rod M4 Time Position Applicants Actions or Behavior RO 25. () Realign misaligned rod(s) to associated group position:

a. Check misaligned rod(s) - IN SHUTDOWN GROUP; No, Perform RNO 25RNOa. At Pulse-to-Analog Converter cabinet, hold AUTO-MANUAL switch in MANUAL.

b. Realign misaligned rod(s) to associated group position using DRPI indication.

c. Check misaligned rod(s) - IN SHUTDOWN GROUP; No Perform RNO 25RNOc. At Pulse-to-Analog Converter cabinet, release AUTO-MANUAL switch.

Booth: For 25RNOa - Insert KEY 10 to ensure PA converter in Manual.

For 25RNOc - Insert KEY 11 to ensure PA converter in AUTO.

Booth cue: When contacted as INC: I will hold AUTO-MANUAL switch in MANUAL. When contacted later, report: I have released the AUTO-MANUAL switch.

RO 26. Reset misaligned rod(s):

a. At lift coil disconnect panel, place all lift coil disconnect switches for affected bank to ROD CONNECTED position.

b. At RL003, open window and reset affected group step counter by hand to position recorded in step 23.b.

c. On RL003, reset rod control urgent failure alarm.

o SF HS-4

d. Verify proper operation of affected rods by moving affected rods 6 steps in each direction.

e. Move affected group to position recorded in step 20.c.

f. Place ROD BANK AUTO/MAN SEL switch in MAN position.

o SE HS-9 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 2 Page 11 of 45_

Event

Description:

Retrieval of Control Rod M4 Time Position Applicants Actions or Behavior Event termination: Lead Examiner may terminate event when M4 has been retrieved.

Booth: Insert KEY 3 for Event three at direction of Lead Examiner.

CRS 27. Perform the following post-alignment checks:

a. Direct I&C to locally verify rod bank selected by SE HS-9 is aligned properly by light indications on associated cabinets.

b. Check Bank D group step counters - AT SAME COUNT (IF not, Perform RNO b) o Direct I&C to ensure the master cycle binary counter is set on 4 or 5 27RNOb. Direct I&C to ensure the master cycler binary counter is set on 1 or 2

c. Update computer rod program, using STN RJ-001, VERIFICATION OF OPERABILITY OF COMPUTER PROCESSES.

d. Compare P/A converter indication for each control bank with the control bank step counter - INDICATIONS MATCH; If NO, Perform RNO CRS 27RNOd. Reset the P/A converter to agree with the current bank step counter indication.

e. Check Bank D - AFFECTED BANK

1) Perform ATTACHMENT A, CONTROL BANK D OVERLAP VERIFICATION

f. Go to step 30 Booth: At step 27a - Respond as I&C; proper light indication on associated cabinets.

Booth: Ensure master cycler is correct on simulator.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 3 Page 12 of 45_

Event

Description:

Primary to secondary leak on Steam Generator A Time Position Applicants Actions or Behavior Booth: Insert KEY 3 for Event three at direction of Lead Examiner.

Diagnostics: RCS pressure decreases. PZR level decreases slowly. Main Control Board alarms 00-061B, PROCESS RAD HI and 00-061A, PROCESS RAD HIHI annunciate. Process radiation monitor GE RE-92, Condenser Off gas monitor, is in Alert/High alarm.

CREW Identifies and diagnoses a primary to secondary leak.

CRS ENTER and DIRECT OFN BB-07A, STEAM GENERATOR TUBE LEAKAGE RO 1. Check PZR level - GREATER THAN 6%

RO 2. Check PZR level - GREATER THAN 17%; If No, Perform RNO 2RNO: Perform the following:

a. Ensure letdown is isolated.

b. Ensure PZR heaters are off.

c. Control charging flow as necessary to maintain PZR level.

RO 3. Check PZR level - STABLE OR INCREASING; If No, Perform RNO 3RNO. If PZR level is less than program level, then perform the following:

a. Control charging flow, as necessary, to maintain PZR level.

b. If PZR level can not be maintained, then close letdown orifice isolation valves, as necessary, to stabilize PZR level.

BG HIS-8149AA BG HIS-8149BA BG HIS-8149CA DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 3 Page 13 of 45_

Event

Description:

Primary to secondary leak on Steam Generator A Time Position Applicants Actions or Behavior FOLDOUT PAGE FOR OFN BB-07A

1. SI ACTUATION CRITERIA If any condition listed occurs, then trip the reactor, actuate SI and go to EMG E-0, REACTOR TRIP OR SAFETY INJECTION step 1.

RCS subcooling based on subcooling monitor - LESS THAN 30°F SUBCOOLING WITH REACTOR TRIPPED or Pressurizer pressure - CANNOT BE MAINTAINED or Pressurizer level - CANNOT BE MAINTAINED GREATER THAN 6% or All of the following conditions exist:

o Normal charging is maximized AND o Letdown is isolated AND o Pressurizer level is decreasing.

CRS 4. Try to identify leaking SG:

Unexpected increase in any SG narrow range level or Radiation from any SG steam line radiation monitor ABS 114 for SG A ABS 113 for SG B ABS 112 for SG C ABS 111 for SG D or Radiation form any SG steamline survey or Radiation from any SG sample Booth cues: If contacted as HP: acknowledge survey request. If contacted as Chemistry, acknowledge sampling request.

Examiner NOTE: SG A may already be identified as the affected Steam Generator.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 3 Page 14 of 45_

Event

Description:

Primary to secondary leak on Steam Generator A Time Position Applicants Actions or Behavior RO 5. Check VCT level - BEING MAINTAINED BY NORMAL MAKEUP CRS 6. Ensure Chemistry is performing the following procedures:

o STS CH-033, PRIMARY TO SECONDARY LEAKAGE DETERMINATION o AI 21D-004, SECONDARY RADIATION MONITOR SETPOINT CALCULATIONS Booth cue: When contacted as Chemistry: Inform CRS that procedures will be performed.

BOP 7. Check Steam Generator blowdown and sampling - NOT ISOLATED CRS 8. Check plant shutdown and monitoring requirements:

a. Monitor Attachment C, STEAM GENERATOR TUBE LEAKAGE MONITORING, action level table and take appropriate actions, as directed by table.

b. Refer to Attachment D, GUIDANCE FOR OPERATION WITH A SG TUBE LEAK

c. Return to step 7.

CRS Determines Technical Specification.

TS 3.4.13 d 150 gpd primary to secondary leakage through any one Steam Generator exceeded; Cond B1 and B2 (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 /> and Mode 5 in 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />)

Booth: If contacted as Call Supt.: Acknowledge plant status.

Examiner NOTE: Crew will start a power reduction before the leak size increases.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 3 Page 15 of 45_

Event

Description:

Primary to secondary leak on Steam Generator A OFN BB-07A, STEAM GENERATOR TUBE LEAKAGE, ATTACHMENT C Time Position Applicants Actions or Behavior ATTACHMENT C, STEAM GENERATOR TUBE LEAKAGE MONITORING NOTES o The increasing leak rate limit is provided to identify the potential need for a rapid power reduction to 50% power. This limit applies to progressively increasing leak rates and does not apply to leak rate spikes followed by decreasing leak rates. To ensure spikes are not included, the increased leakage rate should be sustained over a 30 minute period.

o If there is an increase in the frequency of spikes above 75 gpd, consideration should be given to plant shutdown prior to exceeding the 150 gpd limit.

o The upper leak rate limit of 150 gpd requires plant shutdown independent of whether this limits is exceeded by a leakage spike or progressively increasing leakage.

o To avoid unnecessary shutdown, leakage should be qualitatively confirmed prior to declaration of Action Level 2, 3, or 4.

Booth cue: If contacted as Chemistry to quantify leak report: SG A, approximately 155 gpm.

C1. Action Level Table:

Leak rate Increasing leak rate Required Actions Increased Monitoring 5 gpd NA Perform Step C2 actions

<30 gpd Action Level 1 30 gpd NA Perform Step C3 actions

<75 gpd Action Level 2 75 gpd sustained for 1 <30 gpd/hr Perform Step C4 actions hour Action Level 3 75 gpd 30 gpd/hr for >30 min. Perform Step C5 actions Action Level 4 150 gpd NA Perform Step C6 actions DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 3 Page 16 of 45_

Event

Description:

OFN BB-07A, STEAM GENERATOR TUBE LEAKAGE, ATTACHMENT C Time Position Applicants Actions or Behavior CRS Use Action Level Table to determine Action Level 4; C6 Required Actions.

CRS C6. If leakage is greater than or equal to 150 gpd (Action Level 4), then perform the following:

a. Go to step 9 and be in Mode 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, while continuing with this attachment.

b. Establish and continuously display a NPIS time trend for GE RE-92 and BM RE-25. Monitor time trend at least once every 15 minutes.

c. Determine Emergency Action Level, using EPP 06-005, EMERGENCY CLASSIFICATION Examiner NOTE: Floor Cue: STA surrogate will determine EAL classification? Shift Manager?

CRS Return to step 9 OFN BB-07A:

9. Initiate plant shutdown:

a. Check plant in Mode 1 or Mode 2

b. Perform the following:

1) Initiate a plant shutdown using either of the following procedures:

GEN 00-004, POWER OPERATION or OFN MA-038, RAPID PLANT SHUTDOWN

2) Continue with step 10.

Booth Cue: If necessary, call as Call Supt and state: Use OFN MA-038, RAPID PLANT SHUTDOWN.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 4 Page 17 of 45_

Event

Description:

OFN MA-038, RAPID PLANT SHUTDOWN Time Position Applicants Actions or Behavior CRS ENTER and DIRECT OFN MA-038, RAPID PLANT SHUTDOWN CRS 1. Determine turbine unloading method to be used:

a. Check desired unloading rate - LESS THAN OR EQUAL TO 5%/MINUTE

b. Check automatic turbine unloading desired; if No, Perform RNOb o Go to step 2 1RNOb. Go to step 3 Procedure NOTE: When reducing load with Decrease Loading Rate on, the difference between load set and actual load should be less than 200 MW. Prior to depressing the Hold or Off pushbuttons or establishing Load Limit control, ensure the At Set Load light is on to prevent an uncontrolled load decrease.

BOP 2. () Reduce turbine load in Automatic:

a. Slowly decrease Load Set MW until AT SET LOAD light is on and LOAD LIMIT LIMITING light extinguishes.

b. Raise Load Limit pot slightly.

c. Set Loading/Unloading Rate Limit to desired value and adjust as necessary, during load decrease to maintain desired rate.

d. Select Decrease Loading Rate - ON

e. Decrease Load Set MW to desired load.

f. Continue with step 4 of this procedure while reducing load.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 4 Page 18 of 45_

Event

Description:

OFN MA-038, RAPID PLANT SHUTDOWN Time Position Applicants Actions or Behavior BOP 3. () Reduce turbine load manually:

a. Reduce turbine load using either of the following:

Load Limit set Potentiometer or Standby Load Limit Set Potentiometer

b. Maintain desired turbine unloading rate.

c. Continue with this procedure while reducing turbine load.

RO 4. () Borate RCS and adjust Control rods, as necessary, to maintain the following:

o Target Tavg/ Tref temperature error between 0°F and +5°F o Control rods above the rod insertion limits RO 5. Energize PZR Backup heaters o BB HIS-51A o BB HIS-52A RO 6. Check PZR PORVs:

a. RCS pressure - LESS THAN 2335 PSIG

b. PZR PORVs - CLOSED o BB HIS-455A o BB HIS-456A

c. RCS pressure - GREATER THAN 2185 PSIG

d. PORV Block valves - OPEN o BB HIS-8000A o BB HIS-8000B DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 4 Page 19 of 45_

Event

Description:

OFN MA-038, RAPID PLANT SHUTDOWN Time Position Applicants Actions or Behavior RO 7. Check PZR pressure - STABLE AR OR TRENDING TO 2235 PSIG RO 8. Check PZR level - STABLE AT OR TRENDING TO PROGRAM LEVEL BOP 9. Check SG levels - CONTROLLING BETWEEN 45% AND 55%

CRS 10. Check reactor power - LESS THAN 60%; NO; Perform RNO 10RNO Perform the following:

a. If final desired power level is greater than or equal to 60%, then go to step 38.

b. If final desired power level is less than 60%, then do not continue until reactor power is less than 60%.

Lead Examiner cue to Booth: Insert KEY 5 to increase size of leak once the OFN MA-038 plant shutdown commenced.

Booth: Insert KEY 5 to increase leak size at Lead Examiner direction.

Examiner NOTE: Primary to Secondary leak size increases. Per OFN BB-07A, the Crew uses the Foldout page SI ACTUATION criteria to trip the Reactor and actuate Safety Injection.

CREW Identifies increased leakrate.

Diagnostics: PZR level decreasing, PZR pressure decreasing, SG A level increasing.

CRS DIRECT Reactor Trip and Safety Injection Signal actuation per OFN BB-07A Foldout page criteria.

Examiner NOTE: See page 13 for OFN BB-07A Fold out page criteria.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 6 Page 20 of 45_

Event

Description:

Event 6 - start CCP B (autostart failure)

EMG E-0, REACTOR TRIP OR SAFETY INJECTION Time Position Applicants Actions or Behavior CRS DIRECT performance EMG E-0, REACTOR TRIP OR SAFETY INJECTION, Immediate Actions.

RO, BOP Perform Immediate Actions of EMG E-0.

RO RO reports upon completion of Immediate Actions steps: CCP B autostart failure upon receipt of Safety Injection signal actuation.

CRS may direct RO to start the B CCP now or start the pump later per Attachment F.

If started now:

o BG HIS-2A to RUN CRS ENTER and DIRECT EMG E-0, REACTOR TRIP OR SAFETY INJECTION Procedure NOTE: Steps 1 through 4 are Immediate Action steps RO 1. Verify reactor trip:

a. Check all rod bottom lights - LIT

b. Ensure reactor trip and bypass breakers - OPEN o SB ZL-1 o SB ZL-2 o SB ZL-3 o SB ZL-4

c. Check intermediate range neutron flux - DECREASING o SE NI-35B [GAMMA METRICS]

o SE NI-36B [GAMMA METRICS]

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 5 Page 21 of 45_

Event

Description:

EMG E-0, REACTOR TRIP OR SAFETY INJECTION Time Position Applicants Actions or Behavior BOP 2. Verify Turbine trip:

a. Check the following:

Main Stop valves - ALL CLOSED or Turbine Auto Stop bistable lights - AT LEAST TWO LIT RO 3. Check AC Emergency Busses - AT LEAST ONE ENERGIZED NB01 - ENERGIZED NB02 - ENERGIZED RO 4. Check if Safety Injection is actuated:

a. Check any indication SI is actuated - LIT Annun 00-030A, NF039A LOCA SEQ ACTUATED - LIT Annun 00-031A, NF039B LOCA SEQ ACTUATED - LIT ESFAS status panel SIS section - ANY WHITE LIGHTS LIT Partial Trip Status Permissive/ Block status panel- SI RED LIGHT LIT

b. Check both trains of SI actuated o Annun 00-030A, NF039A LOCA SEQ ACTUATED - LIT o Annun 00-031A, NF039B LOCA SEQ ACTUATED - LIT CRS, BOP When level in ruptured SG is > 6%, DIRECT BOP to isolate ruptured steam Generator using EMG E-0 Foldout page Criteria 4, RUPTURED SG ISOLATION CRITERIA If any SG level increases in an uncontrolled manner or any SG has abnormal radiation, and narrow range level in affected SG(s) is greater than 6% [29%], then the following may be performed.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 5 Page 22 of 45_

Event

Description:

EMG E-0, REACTOR TRIP OR SAFETY INJECTION CT success: Isolate feed flow to the ruptured SG before Steam Generator overfills Time Position Applicants Actions or Behavior CRS, BOP FOLDOUT PAGE CRITERIA 4, RUPTURED SG ISOLATION CRITERIA cont.

a. Close ruptured SG AFW flow control valves - CT actions - see below

b. If any ruptured SG AFW flow control valve cannot be closed AND total AFW flow to intact SGs an be maintained greater than270,000lbm/hr without associated AFW Pump, then perform the following:

1. Stop associated MD AFWP and place in PTL or decrease TD AFWP speed to 2000 rpm.

2. Dispatch an Operator to locally isolate affected AFW flow control valve.

3. When affected AFW flow control valves is isolated, then restart MD AFWP or restore TD AFWP speed as necessary.

BOP (BOP action CT success) When ruptured SG A level is greater than 6%, then isolate AFW to the ruptured steam generator by closing o AL HK-7A, SG A MD AFP AFW REG VLV o AL HK-8A SG A TD AFP AFW REG VLV CTRL CT success: Flow indication on AL FI-2A, AFW TO SG A FLOW indicates zero. CLOSED and ZERO output indication on AL HK-8A and AL HK-7A.

RO 5. Check if SI is required:

SI was manually actuated and was required RCS pressure is currently or has been - LESS THAN OR EQUAL TO 1830 PSIG Any SG pressure is currently or has been - LESS THAN OR EQUAL TO 615 PSIG Containment pressure is currently or has been - GREATER THAN OR EQUAL TO 3.5 PSIG RCS subcooling is currently or has been - LESS THAN 30°F [45°F]

PZR level is currently or has been - LESS THAN 6% [33%]

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 5 Page 23 of 45_

Event

Description:

EMG E-0, REACTOR TRIP OR SAFETY INJECTION Time Position Applicants Actions or Behavior BOP 6. Check Main Generator Breakers and Exciter Breakers - OPEN o MA ZL-3A o MA ZL-4A o MB ZL-2 RO/ BOP 7. Verify Automatic Actions using Attachment F, AUTOMATIC SIGNAL VERIFICATION Examiner NOTE: see page 42 for Attachment F BOP 8. Check total AFW flow - GREATER THAN 270,000 LBM/HR BOP 9. Check RCS cold leg temperatures Stable at or trending to 557°F for condenser steam dumps; if No, Perform RNO Stable at or trending to 561°F for SG ARVs

9. RNO Perform the following:

a. If temperature is less than setpoint and decreasing, then perform the following:

1) Stop dumping steam

2) If any MSIV is open, then close Main turbine Stop and Control Valves Startup Drains o AC HIS-134

3) If cooldown continues then control total feed flow to limit RCS cooldown.

Maintain total feed flow greater than 270,000 lbm/hr until narrow range level greater than 6% [29%] in at least one SG.

4) If cooldown continues due to excessive steam flow, then isolate main steamlines by depressing both MS ISO VLV ALL CLOSE pushbuttons.

o AB HS-79 o AB HS-80

b. If temperature is greater than setpoint and increasing, then perform one of the following:

Dump steam to condenser Dump steam using SG ARVs DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 5 Page 24 of 45_

Event

Description:

EMG E-0, REACTOR TRIP OR SAFETY INJECTION Time Position Applicants Actions or Behavior RO/ BOP 10. Establish SG pressure control:

a. Check condenser - AVAILABLE o C-9 LIT o MSIV - OPEN o Circulating water pumps - RUNNING

b. Place Steam Header Pressure Control in Manual o AB PK-507

c. Manually set Steam Header Pressure Control output to zero o AB PK-507

d. Place Steam Dump Select Switch in STEAM PRESS position o AB US-500Z

e. Place Steam Header Pressure Control in Automatic o AB PK-507 RO/ BOP 11. Check PZR PORVs

a. Check PZR PORVs - CLOSED o BB HIS-455A o BB HIS-456A

b. Power to block valves - AVAILABLE o BB HIS-8000A o BB HIS-8000B

c. RCS pressure - LESS THAN 2185 PSIG RO/ BOP 12. Check Normal PZR Spray valves - CLOSED o BB ZL-455B o BB ZL-455C DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 5 Page 25 of 45_

Event

Description:

EMG E-0, REACTOR TRIP OR SAFETY INJECTION Time Position Applicants Actions or Behavior RO/ BOP 13. Check PZR Safety Valves - CLOSED o BB ZL-8010A o BB ZL-8010B o BB ZL-8010C RO/ BOP 14. Check if RCPs should be stopped:

a. Check RCPs - ANY RUNNING

b. Check RCS pressure - LESS THAN 1400 PSIG; No, Perform RNO 14RNOb. Go to step 15 CRS 15. Direct Operator to monitor Critical Safety Functions, using EMG F-0, CRITICAL SAFETY FUNCTION STATUS TREES (CSFST).

STA STA surrogate performs EMG F-0 and reports to CRS.

BOP 16. Check is SGs are not faulted:

a. Check pressures in all SGs -

o NO SG PRESSURE DECREASING IN AN UNCONTROLLED MANNER o NO SG COMPLETELY DEPRESSURIZED DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 5 Page 26 of 45_

Event

Description:

EMG E-0, REACTOR TRIP OR SAFETY INJECTION Time Position Applicants Actions or Behavior BOP 17. Check if SG tubes are intact:

Direct Health Physics to survey steamlines in Area 5 of the Aux. Bldg.

Condenser Air Discharge radiation - NORMAL BEFORE ISOLATION; No, Perform RNO o GEG 925 SG blowdown and sample radiation - NORMAL BEFORE ISOLATION o BML 256 o SJL 026 Turbine driven auxiliary feedwater pump exhaust radiation - NORMAL o FCT 381 SG steamline radiation - NORMAL o ABS 114 for SG A o ABS 113 for SG B o ABS 112 for SG C o ABS 111 for SG D 17RNO. Perform the following:

a. Ensure BIT inlet and outlet valves are open o EM HIS-8803A o EM HIS-8803B o EM HIS-8801A o EM HIS-8801B

b. Go to EMG E-3, STEAM GENERATOR TUBE RUPTURE, step 1.

Booth: If contacted as Health Physics: acknowledge request to survey steam lines.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 5 Page 27 of 45_

Event

Description:

EMG E-3, STEAM GENERATOR TUBE RUPTURE Time Position Applicants Actions or Behavior CREW Transition to EMG E-3, STEAM GENERATOR TUBE RUPTURE Examiner NOTE: No Transition Brief is performed.

CRS ENTER and DIRECT EMG E-3, STEAM GENERATOR TUBE RUPTURE RO/ BOP 1. Check if RCPs should be stopped:

a. Check RCPs - ANY RUNNING

b. Check RCS pressure - LESS THAN 1400 PSIG; No, Perform RNOb 1RNOb. OBSERVE CAUTION PRIOR TO STEP 2 and go to step 2.

BOP 2. Identify ruptured SGs:

Level increasing in an uncontrolled manner or High turbine driven AFW exhaust radiation or o FCT 381 High radiation from any SG steam line radiation monitor or o ABS 114 for SG A o ABS 113 for SG B o ABS 112 for SG C o ABS 111 for SG D High radiation from any SG steam line survey High radiation from any SG sample Booth cue: If contacted as Chemistry: acknowledge sampling request.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 5 Page 28 of 45_

Event

Description:

EMG E-3, STEAM GENERATOR TUBE RUPTURE Time Position Applicants Actions or Behavior BOP 3. Isolate flow from rupture SG

a. Adjust ruptured SG ARV controller setpoint to 1160 psig

b. Check ruptured SG ARVs - CLOSED

c. Locally close steam supply to turbine driven AFW pump from ruptured SGs AB-V085 for SG B AB-V087 for SG C

d. Locally isolate main steam line low point drain valves from ruptured SGs Close AB-V062 for SG A Close AB-V072 for SG B Close AB-V082 for SG C Close AB-V052 for SG D Booth cue: When contacted, respond as Building Watch to close AB-V062. Insert KEY 13 to close AB-V062.

When closed, report back to Control Room that valve is closed.

RO 4. Verify blowdown and upper sampling isolated on ruptured SGs:

a. SG blowdown Containment Isolation valves - CLOSED BM HIS-1A for SG A BM HIS-2A for SG B BM HIS-3A for SG C BM HIS-4A for SG D

b. SG upper sample isolation valves - CLOSED BM HIS-19 for SG A BM HIS-20 for SG B BM HIS-21 for SG C BM HIS-22 for SG D DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 5 Page 29 of 45_

Event

Description:

EMG E-3, STEAM GENERATOR TUBE RUPTURE MSIVs will not close, Crew transitions to EMG C-31, SGTR WITH LOSS OF REACTOR COOLANT -

SUBCOOLED RECOVERY DESIRED Time Position Applicants Actions or Behavior RO/ BOP 5. Isolate steamline on ruptured SGs

a. Close main steamline isolation valve AB HIS-14 for SG A; No, will not close, Perform RNO AB HIS-17 for SG B AB HIS-20 for SG C AB HIS-11 for SG D 5RNO: Perform the following:

1. Ensure main steamline isolation valves closed.

AB HS-79 AB HS-80

2. If ruptured SG MSIV is not closed, then in SA075A or SA075B, disconnect A and B solenoid fuses (4 fuses total) for the affected valve(s):

Fuses for AB HV See Examiner NOTE on next page

3. Close main steamline isolation bypass valves and drain valves.

4. If ruptured SG MSIV is not closed, then perform the following:

a. Isolate steam header using Attachment A, MAIN STEAM HEADER ISOLATION - CONTROL ROOM, while continuing with this procedure.

b. Direct operator to locally isolate steam header using Attachment B, MAIN STEAM HEADER ISOLATION, LOCAL

5. Use intact SG ARVs for steam dump.

6. If any ruptured SG can not be isolated from at least one intact SG, then go to EMG C-31, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED, step 1.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 5 Page 30 of 45_

Event

Description:

Attachment A, MAIN STEAM HEADER ISOLATION - CONTROL ROOM Time Position Applicants Actions or Behavior Examiner NOTE: Panels SA075A and SA075B are located in the back of the simulator Control Room on a computer soft panel. Once the candidate shows you the soft panel and describes their actions, CUE the Booth operator to insert KEY 12 to remove the fuses. Once KEY 12 is inserted, the fuses are removed BUT the MSIVs will not close.

Booth cue: Insert KEY 12 upon cue from Examiner.

Booth cue: When contacted, respond as Building Watch(es) to perform Attachment B, MAIN STEAM HEADER ISOLATION, LOCAL RO/BOP A1. Ensure Main Turbine Stop valves - CLOSED RO/BOP A2. Ensure Main Feed Water Pumps - TRIPPED o FC HIS-18 for MFWP A o FC HIS-118 for MFWP B RO/BOP A3. Close Condenser Steam Dump valves:

a. Set intact SG ARV controller setpoints to 1100 psig

b. Place Steam Dump Bypass Interlock switches in OFF position o AB HS-63 o AB HS-64

c. Ensure condenser steam dump valves - CLOSED Examiner NOTE: SG ARVs for B, C and D are set to 1100 psig.

RO/ BOP A4. Close Main Steam Supply to MSR 2nd Stage valves o AB HIS-32 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 5 Page 31 of 45_

Event

Description:

ATTACHMENT A, MAIN STEAM HEADER ISOLATION - CONTROL ROOM Time Position Applicants Actions or Behavior RO/ BOP A5. Close Warmup Steam Supply to MSR 2nd Stage valve o AB-V738 o AB-V739 Booth cue: Respond as Building Watch to close the valves. Insert KEY 14 to close AB-V738 and AB-V739.

Report to Control Room that the valves are closed.7 RO/ BOP A6. Transfer Steam Seal Supply to Auxiliary Steam:

a. Check auxiliary steam - AVAILABLE; if Yes, continue .. if NO, Perform RNO

b. Open Steam Seal System Auxiliary Steam Supply valve o CA HIS-4

c. Close Steam Seal System Main Steam Supply valve o CA HIS-1

d. Close Steam Seal System Main Steam Supply Bypass valve o CA HIS-2 A6RNO Break vacuum:

1. Open Condenser Vacuum Breaker valves o AD HIS-113

2. Place all condenser vacuum pumps in Pull-To-Lock position o CG HIS-1 o CG HIS-2 o CG HIS-3

3. Close Main Steam to Steam Seal System o AB HIS-46

4. Close Steam Seal System Auxiliary Steam Supply valve o CA HIS-4

5. Go to step A7 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 8 Page 32 of 45_

Event

Description:

EMG C-31, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED Time Position Applicants Actions or Behavior RO/ BOP A7. Return to procedure and step in effect Examiner NOTE: No Transition Brief should occur.

CREW Transition to EMG C-31, EMG C-31, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED CRS ENTER and DIRECT EMG C-31, SGTR WITH LOSS OF REACOTR COOLANT - SUBCOOLED RECOVERY DESIRED RO 1. Reset SI o SB HS-42A o SB HS-43A RO 2. Reset Containment Isolation Phase A and Phase B o SB HS-56 for phase A o SB HS-53 for phase A o SB HS-55 for phase B o SB HS-52 for phase B BOP 3. Verify Instrument Air alignment:

a. Ensure at least one ESW TRN TO AIR COMPRESSOR valve - OPEN EF HIS-43 EF HIS-44

b. Check AIR COMPRESSOR BRKR RESET switch associated with open ESW valve - CLOSED; if No, Perform RNO:

3RNOb Reset and close AIR COMPRESSOR BRKR RESET switch KA HIS-2C KA HIS-3C DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 8 Page 33 of 45_

Event

Description:

EMG C-31, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED Time Position Applicants Actions or Behavior BOP Step 3 cont.

c. Check INST AIR PRESS - GREATER THAN 105 PSIG o KA PI-40

d. Check PZR PRESS MASTER CTRL output - LESS THAN 50%

o BB PK-455A

e. Check neither ESW TO AIR COMPRESSOR valve - LOCALLY OPENED

f. Open INST AIR SPLY CTMT ISO VLV o KA HIS-29 RO 4. Check if Diesel Generators should be stopped:

a. Check NB01 - ENERGIZED BY OFFSITE POWER

b. Depress START/RESET pushbutton for diesel generator NE01 o KJ HS-8A

c. Depress STOP pushbutton for diesel generator NE01 o KJ HS-8A

d. Check NB02 - ENERGIZED BY OFFSITE POWER

e. Depress START/RESET pushbutton for diesel generator NE02 o KJ HS-108A

f. Depress STOP pushbutton for diesel generator NE02 o KJ HS-108A

g. Place all previously running diesels in standby using SYS KJ-121, DIESEL GENERATOR NE01 AND NE02 LINEUP FOR AUTOMATIC OPERATION, while continuing with this procedure.

Booth: When contacted as Building Watch - Acknowledge request to place Diesels in standby. Insert KEY 6 to place EDG A in standby. Insert KEY 7 to place EDG B in standby. Report to Control Room when tasks complete DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 8 Page 34 of 45_

Event

Description:

EMG C-31, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED Time Position Applicants Actions or Behavior RO 5. Deenergize PZR heaters:

a. Place PZR BU heater switches in trip and PZR CTRL heaters in PTL position o BB HIS-51A o BB HIS-52A o BB HIS-50

b. Direct TSC to determine minimum PZR water level that will ensure PZR heaters are covered.

Booth cue: TSC cue: Acknowledge request.

RO/ BOP 6. Load equipment on energized AC emergency busses:

a. Locally reset and close boric acid transfer pump breakers o NG01AHF4 for pump A o NG02AAF4 for pump B

b. Locally reset and close emergency borated valve breaker o NG04CPF2 for BG HV-8104 Booth cue: Respond as Building Watches when called. Insert KEY 8 for breakers. Report back to Control Room when complete RO 7. Restore power to PZR Backup heaters:

a. Check NB01 - ENERGIZED BY OFFSITE POWER

b. Close supply breaker for PG21 o PG HIS-19

c. Check NB02 - ENERGIZED BY OFFSITE POWER

d. Close supply breaker for PG22 o PG HIS-21 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 8 Page 35 of 45_

Event

Description:

EMG C-31, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED Time Position Applicants Actions or Behavior RO 8. Close Non-Class 1E Battery Charger Breakers o PK HIS-2 for PK-21 o PK HIS-3 for PK-22 o PK HIS-4 for PK-23 o PK HIS-5 for PK-24 RO 9. Check all Non-class 1E AC busses and load centers - ENERGIZED BY OFFSITE POWER o PA o PB o PG o SL RO 10. Check if Containment Spray should be stopped:

a. Check spray pumps - ANY RUNNING; No, Perform RNO 10RNOa. OBSERVE CAUTION PRIOR TO STEP 11 and go to step 11 BOP 11. Check ruptured SG level:

a. Check ruptured SG(s) pressure:

STABLE or INCREASING; No, Perform RNO 11RNOa If ruptured SG pressure decreasing in an uncontrolled manner, then go to step 11c Step 11c. Stop feed flow to ruptured SG Examiner NOTE: Performed earlier using Foldout Page of EMG E-0.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 8 Page 36 of 45_

Event

Description:

EMG C-31, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED Time Position Applicants Actions or Behavior RO 12. Check if RHR pumps should be stopped:

a. Check RHR pumps - ANY RUNNING WITH SUCTION ALIGNED TO RWST

b. Check RCS pressure:

1) Pressure - GREATER THAN 325 PSIG

2) Pressure - STABLE OR INCREASING; if NO, Perform RNO - if YES, continue with c.

12RNOb2 If RCS pressure is expected to decrease below 325 psig within 2.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />, then go to step 13.

c. Stop RHR pumps and place in standby o EJ HIS-1 o EJ HIS-2

d. Check RCS pressure greater than 325 psig during subsequent recovery actions; if NO, Perform RNOd 12RNOd If RCS pressure decreases in an uncontrolled manner to less than 325 psig, then manually restart RHR pumps to provide injection to the RCS.

RO 13. Align CCW to sampling systems

a. Open CCW to radwaste supply/return isolation valves o EG HS-69 o EG HS-70 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 8 Page 37 of 45_

Event

Description:

EMG C-31, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED Time Position Applicants Actions or Behavior RO/BOP 14. Place Hydrogen Analyzers in service:

a. On RL011, place power lockout switches for Containment sample valves in NON-ISO position o GS HIS-40 o GS HIS-41 o GS HIS-42 o GS HIS-43

b. On RL011, open one Hydrogen Analyzer Supply Inner Containment Isolation valve per train o GS HIS-13 or GS HIS-14 for red train o GS HIS-4 or GS HIS-5 for yellow train

c. On RL011, open remaining hydrogen analyzer Containment isolation valves o GS HIS-12 o GS HIS-17 o GS HIS-18 o GS HIS-3 o GS HIS-8 o GS HIS-9

d. On RL020, place Containment hydrogen analyzer control switches in ANALYZE position o GS HIS-16A o GS HIS-11A

e. On RL020, monitor Containment hydrogen concentration o GS AI-19 o GS AI-10 DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 8 Page 38 of 45_

Event

Description:

EMG C-31, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED Time Position Applicants Actions or Behavior RO/BOP 15. Check Fuel/Auxiliary Building radiation - NORMAL

a. Shift Fuel/Auxiliary Building Exhaust sample to EMERGENCY o GG HIS-27 o GG HIS-28

b. Direct Health Physics to survey Fuel and Auxiliary Buildings with priority being pipe penetration areas and piping tunnels

c. Check Fuel/Auxiliary Building radiation monitors - NONE ALARMING o GGP 271 o GGI 272 o GGG 273 o GGP 281 o GGI282 o GGP 283 o GLP 604 o Area radiation monitors Booth cue: If contacted as Health Physics: Acknowledge survey request.

RO/BOP 16. Obtain samples

a. Request Chemistry to obtain boron and activity samples for the following:

o RCS o PZR liquid space o Steam generators Booth cue: If contacted as Chemistry: acknowledge sample requests.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 8 Page 39 of 45_

Event

Description:

EMG C-31, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED Time Position Applicants Actions or Behavior CRS 17. Initiate Evaluation of Plant Status:

a. Evaluate plant equipment to ensure availability o Condenser o SG ARVs o PZR PORVs and block valves o Containment hydrogen recombiners o Containment atmosphere control units o Steamline radiation monitors o Boric acid storage tanks

b. Start additional plant equipment as necessary to assist in recovery Hydrogen mixing fans Auxiliary boiler Radwaste processing Spent Fuel pool cooling Booth cue: Respond as Building watch if dispatched to start the Aux Boiler.

If TSC contacted: Inform CRS that step 17 evaluations are in progress, continue with EMG C-31 to cooldown the unit.

BOP 18. Check if SGs are not faulted:

a. Check pressures in all SGs o NO PRESSURE DECREASING IN AN UNCONTROLLED MANNER o NO SG COMPLETELY DEPRESSURIZED DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 8 Page 40 of 45_

Event

Description:

EMG C-31, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED Time Position Applicants Actions or Behavior BOP 19. Check intact SG levels:

a. Check narrow range level in at least one SG - GREATER THAN 6%; if No, Perform RNOa 19RNOa. Maintain total feed flow greater than 270,000 lbm/hr until narrow range level greater than 6% [29%] in at least one SG Step 19b

b. Control feed flow to maintain narrow range level in all SGs between 29%

[29%] and 50%

BOP 20. Check if Condenser Air Removal should be returned to normal:

a. Check the following:

o Main steamline isolation valves - AT LEAST ONE OPEN o Condensate pumps -AT LEAST ONE RUNNING o Circulating water pumps - AT LEAST ONE RUNNING o Condenser vacuum - ESTABLISHED; if NO, Perform RNOa 20RNOa. OBSERVE NOTE PRIOR TO STEP 21 and go to step 21 RO 21. Check if Low Steamline Pressure SI should be blocked:

a. Check RCS pressure - LESS THAN 1970 PSIG o P-11 light -LIT; if NO, Perform RNO a.

b. Block low steamline pressure SI o SB HS-9 o SB HS-10 21RNOa. When RCS pressure is less than 1970 psig, then block low steamline pressure SI. OBSERVE NOTE PRIOR TO STEP 22 and continue with step 22.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 8 Page 41 of 45_

Event

Description:

EMG C-31, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED CT success: Initiate cooldown of the RCS to Cold Shutdown conditions at the highest rate achievable but less that 100°F per hour to minimize leakage of Reactor Coolant and radiological releases from the ruptured Steam Generator. (Performance of step 22)

Time Position Applicants Actions or Behavior BOP 22. Initiate RCS cooldown to cold shutdown: (CT performance of step 22)

a. Maintain cooldown rate in RCS cold legs - LESS THAN 100°F/HR

b. Check RHR System - IN SHUTDOWN COOLING MODE; No, Perform RNOb 22RNOb Go to Step 22d Step 22 cont

d. Dump steam to condenser from intact SGs; if No, Perform RNOd

1) Ensure STM HDR PRESS CTRL in manual o AB PK-507

2) Adjust STM HDR PRESS CTRL to achieve desired cooldown rate o AB PK-507

3) When P-12 interlock actuates, then place both STEAM DUMP BYPASS INTERLOCK switches in BYP/INTLK o AB HS-63 o AB HS-64 22RNOd a) Manually dump steam from intact SGs Use SG ARV or Operate turbine driven AFW pump at maximum load CT success: Highest achievable but less than 100°F per hour cooldown rate is initiated using steam dumps or SG ARVs.

Lead Examiner terminates scenario when cooldown is established.

Booth FREEZE scenario at Lead Examiner direction.

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 6 Page 42 of 45_

Event

Description:

EMG E-0, Attachment F, AUTOMATIC SIGNAL VERIFICATION (Step F4 will start the CCP B. Note that the pump may have been started at the completion of the Immediate Actions of EMG E-0.)

Time Position Applicants Actions or Behavior RO/BOP F1. Verify feedwater isolation:

a. Main feedwater pumps - TRIPPED

b. Main feedwater reg valves - CLOSED

c. Main feedwater reg bypass valves - CLOSED

d. Main feedwater isolation valves - CLOSED

e. Main feedwater chemical injection valves - CLOSED

f. Check ESFAS status panel SGBSIS section - ALL WHITE LIGHTS LIT RO/BOP F2.Verify Containment Isolation Phase A:

a. Check ESFAS status panel CISA section - ALL WHITE LIGHTS LIT RO/BOP F3. Verify AFW pumps running:

a. Check motor driven AFW pumps- BOTH RUNNING

b. Check turbine driven AFW pump - RUNNING RO/BOP F4. Verify ECCS pumps running:

a. Check CCPs - BOTH RUNNING; No, Perform RNO

b. Check SI pumps - BOTH RUNNING

c. Check RHR pumps - BOTH RUNNING F4RNOa. Manually start pumps o BG HIS-1A (CCP A: recall it is tagged out) o BG HIS-2A (CCP B)

DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 5 Page 43 of 45_

Event

Description:

EMG E-0, Attachment F, AUTOMATIC SIGNAL VERIFICATION Time Position Applicants Actions or Behavior RO/BOP F5. Verify CCW alignment:

a. Check CCW pumps - ONE RUNNING IN EACH TRAIN

b. Check one pair of CCW service loop Supply and Return valves for an operating CCW pump - OPEN EG ZL-15 AND EG ZL-53 or EG ZL-16 AND EG ZL-54 RO/BOP F6. Check ESW pumps - NOT RUNNING RO/BOP F7. Check Containment Fan Coolers - RUNNING IN SLOW SPEED RO/BOP F8 Verify Containment Purge Isolation:

a. Check ESFAS status panel CPIS section - ALL WHITE LIGHTS LIT RO/BOP F9. Verify both trains of Control Room Ventilation Isolation:

a. Check ESFAS status panel CRVIS section - ALL WHITE LIGHTS LIT

b. Ensure Control Room outer door - CLOSED RO/BOP F10. Verify Main Steamline Isolation not required:

a. Check Containment pressure - HAS REMAINED LESS THAN 17 PSIG B. Check either condition below - SATISFIED Low steamline pressure SI - NOT BLOCKED AND steamline pressure -

HAS REMAINED GREATER THAN 615 PSIG or Low steamline pressure SI - BLOCKED AND steamline pressure rate -

HAS REMAINED LESS THAN 100 PSI/50SEC DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 7 Page 44 of 45_

Event

Description:

EMG E-0, Attachment F, AUTOMATIC SIGNAL VERIFICATION Manual closure: Service Water/ESW Train A Cross Connect valves EF HV-0023 and EF HV-0025 Time Position Applicants Actions or Behavior RO/BOP F11. Verify Containment Spray not required:

a. Containment pressure - HAS REMAINED LESS THAN 27PSIG RO/BOP F12. Verify ECCS flow:

a. Check Centrifugal Charging Pump to Boron Injection Tank Flow Meters -

FLOW INDICATED

b. Check RCS pressure - LESS THAN 1700 PSIG; No, Perform RNO F12RNOb. Go to step F13.

RO/BOP F13. Verify AFW valves - PROPERLY ALIGNED:

a. Check ESFAS section panel AFAS section - ALL WHITE LIGHTS LIT

b. Check white train ESFAS section panel AFAS section - ALL WHITE LIGHTS LIT RO/BOP F14. Verify SI valves - PROPERLY ALIGNED

a. Check ESFAS section panel SIS section - SYSTEM LEVEL WHITE LIGHTS ALL LIT; No Perform RNO F14RNO: If any SIS section component not properly aligned, then manually align associated component to establish proper SIS lineup.

Using ESFAS status panels, SA 066-Y and SA 066-X, Candidate determined Service Water/ESW Train A Cross Connect valves EF HV-0023 and EF HV-0025 remain open. At Panel RL019, Candidate depressed the OPEN pushbutton for SERVICE WTR/ESW TRN A CROSS CONNECT, EF HIS-25. Green Light will EXTINGUISH, and RED light will LITE. At Panel RL019, Candidate depressed the OPEN pushbutton for SERVICE WTR/ESW TRN A CROSS CONNECT, EF HIS-23. Green Light will EXTINGUISH and RED light will LITE.

Candidate re-checks both ESFAS status panels - SYSTEM LEVEL WHITE LIGHTS ALL LIT; yes DRAFT

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Scenario No.: 4 Event No.: 5 Page 45 of 45_

Event

Description:

EMG E-0, Attachment F, AUTOMATIC SIGNAL VERIFICATION Time Position Applicants Actions or Behavior RO/BOP F15. Check if NCP should be stopped:

a. CCPs - ANY RUNNING

b. Stop NCP RO/BOP F16. Return to procedure and step in effect.

DRAFT

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Evaluate Time To Core Boiling And JPM No.: R.A.1.a Complete Core Uncovery K/A

Reference:

2.1.25 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing: Classroom Simulated Performance: Actual Performance: x Classroom x Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: Plant is in MODE 5 six (6) days after shutdown from full power EOL for a refueling outage. The unit is in Reduced Inventory. All RHR cooling was lost 10 minutes ago at 0700.

Task Standard: Upon completion the Candidate will estimate time to boil, onset to boiling and core uncovery using Figures 5 AND 6 per step 31 of OFN EJ-015, LOSS OF RHR COOLING.

o Time to Boil is 27 +/- 1 minute from 0700 hours0.0081 days <br />0.194 hours <br />0.00116 weeks <br />2.6635e-4 months <br /> OR Candidate may report 17 +/- 1 minutes remain to time to boil.

o Time to Onset of Core Uncovery 105 minutes +/- 1 minute OR Candidate may report ~95 +/- 1 minutes remain to onset of core uncovery.

o Time to Complete Core Uncovery 223 minutes +/- 2 minutes OR Candidate may report ~213 +/- 2 minutes remain until complete core uncovery.

Required Materials: OFN EJ-015 Figure 5 and Figure 6 General

References:

OFN EJ-015, LOSS OF RHR COOLING Handouts: OFN EJ-015 Figure 5 and Figure 6 Initiating Cue: The CRS directs you to estimate time to boil, onset of core uncovery and complete core uncovery per step 31 of OFN EJ-015, LOSS OF RHR COOLING.

DRAFT 1 of 5

Appendix C Job Performance Measure Form ES-C-1 Worksheet Time Critical Task: No (Yes or No)

Alternate Success No Path: (Yes or No)

Validation Time: 15 minutes DRAFT 2 of 5

Appendix C Page 3 of 5 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

• Performance Step: 1 Estimate time to boil using Figure 5 Standard: Using the graph estimated time to boil is approx. 27 minutes (Acceptable range 26 to 28 minutes)

OR Candidate may report that 17 +/- 1 minutes remain.

Comment: Step 31. b.

Examiner NOTE: To correctly perform candidate must use the Vessel Capable Of Being Pressurized line on figure 5

• Performance Step: 2 Estimate time to onset of core uncovery using Figure 6 Standard: Using the graph estimated time to uncovery is approx. 105 minutes. (Acceptable range is 104 minutes to 106 minutes.

OR Candidate may report that ~95 +/- 1 minutes remain.

Comment: Step 31. c.

Examiner NOTE: To correctly perform candidate must use the Onset Of Core Uncovery line on figure 6

• Performance Step: 3 Estimate time to complete core uncovery using Figure 6 Standard: Using the graph estimated time to uncovery is approx. 223 minutes. (Acceptable range is 221 minutes to 225 minutes.

OR Candidate may report that ~213 +/- 2 minutes remain.

Comment: Step 31.d Examiner NOTE: To correctly perform candidate must use the Complete Core Uncovery line on figure 6 Terminating Cue: JPM is complete DRAFT 3 of 5

Appendix C Page 4 of 5 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: R.A.1.a.

Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 4 of 5

Appendix C Page 5 of 5 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: Plant is in MODE 5 six (6) days after shutdown from full power EOL for a refueling outage. The unit is in Reduced Inventory. All RHR cooling was lost 10 minutes ago at 0700.

INITIATING CUE: The CRS directs you to estimate time to boil, onset of core uncovery and complete core uncovery per step 31 of OFN EJ-015, LOSS OF RHR COOLING.

DRAFT 5 of 5

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Determine Shutdown Margin Using JPM No.: R.A.1.b STS RE-004, SHUTDOWN MARGIN CALCUALTION K/A

Reference:

2.1.37 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing: Classroom Simulated Performance: Actual Performance: x Classroom x Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: Plant tripped 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> ago after 120 days of full power operation. All systems functioned as designed. Core Burnup is 1000 MWD/MTU.

Current boron concentration is 1440 ppm. The date is August 25.

Current time is 1000. Plant is stable at 557.4°F using steam dumps.

Task Standard: Candidate performed Shutdown Margin Attachment A and determined Shutdown Margin is NOT met.

Required Materials: Attachment A, SHUTDOWN MARGIN CALCULATION SHORT FORM of STS RE-004, SHUTDOWN MARGIN DETERMINATION Calculator WCRX-23 Rev. 27, CONTROL ROOM OPERATING CURVES AND TABLES REFERENCE MANUAL General

References:

WCRX-23 CONTROL ROOM OPERATING CURVES AND TABLES REFERENCE MANUAL STS RE-004, SHUTDOWN MARGIN DETERMINATION Handouts: STS RE-004, SHUTDOWN MARGIN DETERMINATION WCRX-23 CONTROL ROOM OPERATING CURVES AND TABLES REFERENCE MANUAL DRAFT 1 of 7

Appendix C Job Performance Measure Form ES-C-1 Worksheet Initiating Cue: CRS directs you to perform Attachment A, SHUTDOWN MARGIN CALCULATION SHORT FORM of STS RE-004, SHUTDOWN MARGIN DETERMINATION. Use references provided.

Notify the CRS of results when Attachment A is complete.

Time Critical Task:

(Yes or No) No Alternate Success Path: (Yes or No) No Validation Time: 30 minutes DRAFT 2 of 7

Appendix C Page 3 of 7 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: 1 Step A.1.1 Current Date/Time Standard: Candidate entered date and time from initial conditions.

Comment: Step A.1.1 Performance Step: 2 Step A.1.2 Shutdown Date/Time Standard: Candidate entered Shutdown date and time from initial conditions.

Comment: Examiner NOTE: Step A.1.2 is used in step A.2.4 to determine how long the margin calculation is accurate.

Performance Step: 3 Step A.1.3 Core Average Burnup Standard: Candidate entered Burnup MWD/MTU from initial conditions.

Comment: Examiner NOTE: Step A.1.3 determines the MINIMUM boron concentration for the given burnup in A.2.1.

Performance Step: 4 Step A.1.4 Current Core Average Temperature Standard: Candidate entered RCS Average temperature from initial conditions.

Comment: Examiner NOTE: Step A.1.4 determines what boron concentration is needed for a given RCS density (see A.2.1).

Performance Step: 5 Step A.1.5 Current boron concentration Standard: Candidate entered concentration from initial conditions.

Comment: Examiner NOTE: Step A.1.5 determines if current concentration and required concentration meet shutdown margin requirements.

DRAFT 3 of 7

Appendix C Page 4 of 7 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 6 Step A.1.6 Boron-10 Correction Factor Standard: Candidate entered Correction Factor 0.991 from page 5.8 WCRX-23 for 1000 MWD/MTU Comment: Examiner NOTE: Step A.1.6 is used to determine minimum boron concentration for shutdown margin (see A.2.3).

• Performance Step: 7 Step A.2.1 Minimum Boron Concentration Standard: Candidate entered concentration from WCRX-23 page 7.1 for 1000 MWD/MTU of 1770 ppm Comment: Examiner NOTE: Step A.2.1 is the required minimum concentration with no adjustments.

Performance Step: 8 Step A.2.2 Apply Xenon Credit Standard: Candidate entered Xenon credit because both conditions:

Reactor operated 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> continuously prior to trip and present time is within 20 hours2.314815e-4 days <br />0.00556 hours <br />3.306878e-5 weeks <br />7.61e-6 months <br /> from time of trip, are met.

Candidate uses 300 ppm credit from page 7.1 of WCRX-23.

Comment: Examiner NOTE: Step A.2.2 provides a credit for xenon reactivity addition to the core for shutdown margin determination.

• Performance Step: 9 Step A.2.3 Minimum Boron Concentration Standard: Candidate determined 1483 ppm boron concentration by calculating: minimum concentration minus the xenon credit plus the current boron concentration times one minus the boron correction factor.

Comment: Examiner NOTE: Step A.2.3 determines the required concentration to meet shutdown margin all rods in at NOT/NOP.

DRAFT 4 of 7

Appendix C Page 5 of 7 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 10 Step A.2.4 Determine time and date Shutdown Margin is Accurate.

Standard: Candidate entered 0300 for 20 hours2.314815e-4 days <br />0.00556 hours <br />3.306878e-5 weeks <br />7.61e-6 months <br /> from time of Shutdown and 8/26/2011 as the date.

Comment: Examiner NOTE: A.2.4 determines how long the Shutdown margin calculation is accurate for current conditions held constant.

• Performance Step: 11 Step A.3.1 Shutdown Margin Determination Standard: Candidate answered No to question.

Candidate recommended to CRS to either borate the RCS or perform a long form calculation using Attachment B.

Comment: Examiner NOTE: A.3.1 determines if the current boron concentration is equal to or greater than that required to meet shutdown margin.

Terminating Cue: Attachment A is complete; Shutdown margin is NOT MET.

DRAFT 5 of 7

Appendix C Page 6 of 7 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: R.A.1.b Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 6 of 7

Appendix C Page 7 of 7 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: Plant tripped 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> ago after 120 days of full power operation.

All systems functioned as designed.

Core Burnup is 1000 MWD/MTU.

Current boron concentration is 1440 ppm.

The date is August 25. Current time is 1000.

Plant is stable at 557.4°F using steam dumps.

INITIATING CUE: CRS directs you to perform Attachment A, SHUTDOWN MARGIN CALCULATION SHORT FORM of STS RE-004, SHUTDOWN MARGIN DETERMINATION. Use the references provided.

Notify the CRS of results when Attachment A is complete.

DRAFT 7 of 7

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Complete STS AL-211, TURB JPM No.: R.A.2 DRIVEN AUX FDWTR SYS FLOW PATH VERIFICATION &

INSERVICE CHECK VALVE TEST K/A

Reference:

2.2.12 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: x Classroom x Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: The following conditions exist:

• Unit in MODE 1 at 88% RTP

• No equipment is Out of Service

• CRS and BOP have been performing STS AL-211, TURB DRIVEN AUX FDWTR SYS FLOW PATH VERIFICATION &

INSERVICE CHECK VALVE TEST

• The BOP has been called away for a random Fitness for Duty assessment.

• The BOP failure to document SAT/UNSAT at each step will be addressed using a Condition Report.

Task Standard: Upon completion of this JPM, the Candidate determined pump vibration for PIV - V2 has exceeded the MAXIMUM ACCEPTABLE limit. The Required Action 1 is to inform the SM/CRS that the TDAFW pump has failed the surveillance test and is inoperable. Corrective action must be initiated.

Required Materials: STS AL-211, TURB DRIVEN AUX FDWTR SYS FLOW PATH VERIFICATION & INSERVICE CHECK VALVE TEST, Calculator General

References:

STS AL-211, TURB DRIVEN AUX FDWTR SYS FLOW PATH VERIFICATION & INSERVICE CHECK VALVE TEST Handouts: Partially completed STS AL-211, TURB DRIVEN AUX FDWTR SYS FLOW PATH VERIFICATION & INSERVICE CHECK VALVE TEST DRAFT 1 of 7

Appendix C Job Performance Measure Form ES-C-1 Worksheet Initiating Cue: The CRS directs you to complete the STS to determine pump Operability status. Data required are documented in the procedure at the applicable steps.

Time Critical Task:

(Yes or No) No Alternate Success Path: (Yes or No) No Validation Time: 25 minutes DRAFT 2 of 7

Appendix C Page 3 of 7 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: 1 Determine TDAFP seal leakage.

Standard: Candidate reviewed the seal leakoff values and determined leakage was acceptable (circled S in Sat/Unsat column).

Comment: Step 8.1.19 Examiner NOTE: Candidate determined pump seal leakage within acceptable range.

Performance Step: 2 Verify TDAFP parameters are SAT.

Standard: Using Attachment A data sheet:

Candidate verified pump dynamic suction pressure is SAT (circled S in Sat/Unsat column).

Candidate verified pump speed is SAT (circled S in Sat/Unsat column).

Comment: Step 8.1.20

• Performance Step: 3 Determine Pump Operability using vibration data.

Standard: Using Attachment A Candidate verified V2 is above the MAXIMUM ACCEPTABLE and informed the CRS:

• Required Action 1 - notify SM/CRS that the TDAFW pump has failed the surveillance and is inoperable; initiate corrective action.

Comment: Step 8.1.21 Examiner NOTE: Candidate determined pump operability is in question based on exceeding the MAXIMUM ACCEPTABLE on Pump Inboard Vertical (PIV) V-2.

DRAFT 3 of 7

Appendix C Page 4 of 7 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 4 Determine AFW Flow is SAT.

Standard: Using Attachment A:

Candidate verified AFW flow values recorded on Attachment A to all four SGs were within acceptable range (circled S in Sat/Unsat column).

Candidate verified total AFW flow recorded on Attachment A was within acceptable range (circled S in Sat/Unsat column).

Comment: Step 8.1.22 Performance Step: 5 Verify TDAFP speed is SAT.

Standard: Candidate verified speed recorded on Attachment A is within acceptable limits (circled S in Sat/Unsat column).

Comment: Step 8.1.25 Performance Step: 6 Verify Total Flow is SAT.

Standard: Candidate verified flow recorded on Attachment A was within the acceptable limits (circled S in Sat/Unsat column).

Comment: Step 8.1.26

• Performance Step: 7 Calculate TDAFP and record on Attachment A.

Standard: Candidate used Attachment A to find discharge pressure of 1462 and dynamic suction pressure of 12.8 and calculated the differential at 1449.2 psid.

Comment: Step 9.8.1 Examiner NOTE: Candidate used Attachment A to find P2 pressure and subtract P1 pressure to determine pump psid.

DRAFT 4 of 7

Appendix C Page 5 of 7 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 8 Record calculated DP on Attachment A and verify SAT.

Standard: Candidate recorded 1449.2 on Attachment A at step 9.8.2 slot.

Candidate determined psid within acceptable range and circled SAT Comment: Step 9.8.2 Terminating Cue: Pump is NOT verified Operable.

DRAFT 5 of 7

Appendix C Page 6 of 7 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: R.A.2 Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 6 of 7

Appendix C Page 7 of 7 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: The following conditions exist:

• Unit in MODE 1 at 88% RTP

• No equipment is Out of Service

• CRS and BOP have been performing STS AL-211, TURB DRIVEN AUX FDWTR SYS FLOW PATH VERIFICATION

& INSERVICE CHECK VALVE TEST

• The BOP has been called away for a random Fitness for Duty assessment.

• The BOP failure to document SAT/UNSAT at each step will be addressed using a Condition Report.

INITIATING CUE: The CRS directs you to complete the STS to determine pump Operability status. Data required are documented in the procedure at the applicable steps.

DRAFT 7 of 7

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Determine power supply RK045B JPM No.: R.A.4 lost and percentage of affected annunciators K/A

Reference:

2.4.32 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: x Classroom x Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: Given the following conditions:

• Plant is 97% RTP and stable

• Multiple alarms have actuated

• CRS enters OFN PK-029, LOSS OF NON VITAL 125 VDC BUS PK01, PK02, PK03, PK04, AND ANNUNCIATORS

• NPIS is not available Task Standard: Candidate determined RK045B (PK5222) is the affected power supply and 9.7% of Annunciators were lost.

Required Materials: OFN PK-029, LOSS OF NON VITAL 125 VDC BUS PK01, PK02, PK03, PK04, AND ANNUNCIATORS General

References:

OFN PK-029, LOSS OF NON VITAL 125 VDC BUS PK01, PK02, PK03, PK04, AND ANNUNCIATORS Handouts: OFN PK-029, LOSS OF NON VITAL 125 VDC BUS PK01, PK02, PK03, PK04, AND ANNUNCIATORS Color screen shots of selected Main Control Board (MCB) panels in alarm.

DRAFT 1 of 5

Appendix C Job Performance Measure Form ES-C-1 Worksheet Initiating Cue: Using OFN PK-029, LOSS OF NON VITAL 125 VDC BUS PK01, PK02, PK03, PK04, AND ANNUNCIATORS, Attachment L, AFFECTED ANNUNCIATOR WINDOWS, the CRS directs you to:

1) Determine the affected power supply, and

2) The total percentage of annunciation that has been lost.

Time Critical Task:

(Yes or No) No Alternate Success Path: (Yes or No) No Validation Time: 25 minutes DRAFT 2 of 5

Appendix C Page 3 of 5 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

• Performance Step: 1 Determine from annunciators LIT a RK045B power supply failure.

Standard: Candidate used MCB panel screen shots and Attachment L pages 20, 21, and 22 to determine RK045B power supply failure.

The Candidate may report that PK5222 has failed - this is acceptable.

Comment: Examiner NOTES:

Step L.1 States RK045A/B have no NPIS indication; candidate must use the affected window drawings to determine which power supply is lost.

Step L.3 Determines affected annunciators using the attachment.

Step L.3.1 Compare lit annunciators with annunciators shown on associated attachment.

• Performance Step: 2 Determine percentage of lost annunciators Standard: Candidate determined RK045B (PK5222) lost power and uses Table at step L.2 to determine 9.7% of annunciators are affected.

Comment: Examiner NOTE:

L.2 has three tables, the last table states the % of annunciation affected for RK045B.

Terminating Cue: RK045B (PK5222) power supply is lost and 9.7% of annunciation is affected.

DRAFT 3 of 5

Appendix C Page 4 of 5 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: R.A.4 Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 4 of 5

Appendix C Page 5 of 5 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: Given the following conditions:

• Plant is 97% RTP and stable

• Multiple alarms have actuated

• CRS enters OFN PK-029, LOSS OF NON VITAL 125 VDC BUS PK01, PK02, PK03, PK04, AND ANNUNCIATORS

• NPIS is not available INITIATING CUE: Using OFN PK-029, LOSS OF NON VITAL 125 VDC BUS PK01, PK02, PK03, PK04, AND ANNUNCIATORS, Attachment L, AFFECTED ANNUNCIATOR WINDOWS, the CRS directs you to:

1) Determine the affected power supply, and

2) The total percentage of annunciation that has been lost.

DRAFT 5 of 5

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Evaluate the Reactor Operators JPM No.: S.A.1.a completed manual calculation of reactor thermal power per STS SE-002, MANUAL CALCULATION OF REACTOR THERMAL POWER K/A

Reference:

2.1.20 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: x Classroom x Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: You are the Control Room Supervisor. The Reactor Operator (RO) reports that the power calculation between STS SE-001, POWER RANGE ADJUSTMENT TO CALORIMETRIC and STS SE-002, MANUAL CALCULATION OF REACTOR THERMAL POWER, do not agree within +/- 1% as required per step 8.9.2.3.

STS SE-001, POWER RANGE ADJUSTMENT TO CALORIMETRIC, calculated results are 97.1%.

Feedwater temperature is 430°F.

A personal computer is not available.

DRAFT 1 of 11

Appendix C Job Performance Measure Form ES-C-1 Worksheet Task Standard: Upon completion of the JPM:

SRO discovered the following errors:

1. Attachment B, CALORIMETRIC DATA COLLECTION: Average SG Pressure of 950.56 psig instead of 965.26 psia

2. Attachment C, FEEDWATER CALORIMETRIC CALCULATION:

• C.2.1: Incorrect Steam Enthalpy (hg) and Latent Heat of Vaporization (hfg) determined because RO used incorrect pressure value

• C.2.2: Incorrect Feedwater Enthalpy (hFW) because RO used incorrect pressure value

• C.2.3: Incorrect Heat Transfer (H) because pressure error carried through and the wrong values were used to calculate Heat Transfer

• C.3: Incorrect SGBD Correction factor because RO used an incorrect Latent Heat of Vaporization (hfg)

• C.4: Incorrect Power because the RO used the Total Average Feedwater flow instead of the Compensated Feedwater flow and an incorrect Heat Transfer and SGBD Correction factor.

SRO did not Approve STS SE-002, MANUAL CALCULATION OF REACTOR THERMAL POWER Required Materials: Scratch paper, calculator, partially completed STS SE-002 rev 26, MANUAL CALCULATION OF REACTOR THERMAL POWER General

References:

STS SE-002 rev 26, MANUAL CALCULATION OF REACTOR THERMAL POWER Handouts: Partially completed STS SE-002 rev 26, MANUAL CALCULATION OF REACTOR THERMAL POWER Initiating Cue: Evaluate the ROs performance of STS SE-002, MANUAL CALCULATION OF REACTOR THERMAL POWER, Attachment B, CALORIMETRIC DATA COLLECTION, and Attachment C, FEEDWATER CALORIMETRIC CALCULATION.

Evaluate the ROs work and approve or disapprove the results.

Circle your response: Approve or Disapprove the results.

If there are any errors, list the errors.

Time Critical Task:

(Yes or No) No DRAFT 2 of 11

Appendix C Job Performance Measure Form ES-C-1 Worksheet Alternate Success Path: (Yes or No) No Validation Time: 30 minutes DRAFT 3 of 11

Appendix C Page 4 of 11 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: 1 Obtain partially completed STS SE-002, MANUAL CALCULATION OF REACTOR THERMAL POWER, Attachments B, Calorimetric Data Collection, Attachment C, Feedwater Calorimetric Calculation and Attachment E, Calorimetric Comparison and NIS Power Range Adjustment Standard: Candidate received procedure and attachments.

Comment:

Performance Step: 2 Using Attachment B, Calorimetric Data Collection, page 1 of 2, candidate evaluates RO work: Total Average Feedwater flow 15.02E6 lbm/hr Standard: Using Attachment B, Calorimetric Data Collection, page 1 of 2, candidate calculated Total Average Feedwater flow 15.02E6 lbm/hr Comment: Step 8.3 and 8.4 Performance Step: 3 Using Attachment B, Calorimetric Data Collection, page 2 of 2, candidate evaluates RO work: Average Feedwater temperature 432.5°F Standard: Using Attachment B, Calorimetric Data Collection, page 2 of 2, candidate calculated Average Feedwater temperature 432.5°F Comment: Step 8.3 and 8.4

• Performance Step: 4 Using Attachment B, Calorimetric Data Collection, page 2 of 2, candidate evaluates RO work: RO calculation was 950.56 psig.

Average SG Pressure Total Average 965.26 psia Standard: Using Attachment B, Calorimetric Data Collection, page 2 of 2, candidate calculated Average SG Pressure Total Average as 965.26 psia.

Candidate discovered RO error (950.56 psig vice 965.26 psia).

Comment: This is an RO error discovery point. RO used 950 psig in subsequent calculations. Step 8.3 and 8.4 DRAFT 4 of 11

Appendix C Page 5 of 11 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 5 Using Attachment B, Calorimetric Data Collection, page 2 of 2, candidate evaluates RO work: Average SG Blowdown 126.33 Klbm/hr Standard: Using Attachment B, Calorimetric Data Collection, page 2 of 2, candidate calculated Average SG Blowdown 126.33 Klbm/hr Comment: Step 8.3 and 8.4 Performance Step: 6 Using Attachment B, Calorimetric Data Collection, page 2 of 2, candidate evaluates RO work: Average Indicated Power per Quadrant N-41 97.2 N-42 96.6 N-43 96.9 N-44 97.7 Standard: Using Attachment B, Calorimetric Data Collection, page 2 of 2, candidate calculated Average Indicated Power per Quadrant as N-41 97.2 N-42 96.6 N-43 96.9 N-44 97.7 Comment: Step 8.3 and 8.4 Performance Step: 7 Using Attachment C, Feedwater Calorimetric Calculation, page 1 of 1 candidate evaluates RO work: Feedwater Density Standard: Using Attachment F, Density of Compressed Water at 1042.6 psia, candidate determined Feedwater Density 52.521 lbm/cu.ft. for a temperature of 432.5°F.

Comment: Step 8.7 - Recall no personal computer is available; Attachment C was performed using data collected and calculated from Attachment B.

See Attachment C, step C.1.1 and Attachment F DRAFT 5 of 11

Appendix C Page 6 of 11 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 8 Using Attachment C, Feedwater Calorimetric Calculation, page 1 of 1 candidate evaluates RO work: Density Correction Factor (DCF)

Standard: Using Attachment C, Feedwater Calorimetric Calculation, candidate calculated DCF 1.006 DCF = (52.521 ÷ 51.913)1/2 Comment: See Attachment C, step C.1.2 Performance Step: 9 Using Attachment C, Feedwater Calorimetric Calculation, page 1 of 1 candidate evaluates RO work: Compensated Feedwater flow Standard: Using Attachment C, Feedwater Calorimetric Calculation, candidate calculated Compensated Feedwater flow 15.11E6 15.02E6 x 1.006 15.11E6 Comment: See Attachment C, step C.1.3

• Performance Step: 10 Using Attachment C, Feedwater Calorimetric Calculation, page 1 of 1 and Attachment G, Properties of Saturated Steam/Water, candidate evaluates RO work: Steam Enthalpy (hg) and Latent Heat of Vaporization (hfg)

Standard: Using Attachment C, Feedwater Calorimetric Calculation, page 1 of 1 and Attachment G, Properties of Saturated Steam/Water, candidate determined Steam Enthalpy (hg) 1194.2 Latent Heat of Vaporization (hfg) 657.05 Candidate discovered RO error: RO determined Steam Enthalpy and Latent Heat of Vaporization using 950 psig instead of 965 psia.

Comment: This is an RO error discovery point.

See Attachment C, step C.2.1 DRAFT 6 of 11

Appendix C Page 7 of 11 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 11 Using Attachment C, Feedwater Calorimetric Calculation, page 1 of 1 and Attachment H, Properties of Compressed Water, candidate evaluates RO work: Feedwater Enthalpy (hFW)

Standard: Using Attachment C, Feedwater Calorimetric Calculation, page 1 of 1 and Attachment H, Properties of Compressed Water, candidate determined Feedwater Enthalpy (hFW) 411.2 Candidate discovered RO error: The RO has continued using 950 psig instead of 965 psia. The hFW at 950 psig 410.6.

Comment: This is an RO error discovery point.

See Attachment C, step C.2.2

• Performance Step: 12 Using Attachment C, Feedwater Calorimetric Calculation, page 1 of 1, candidate evaluates RO work: Heat Transfer (H)

Standard: Using Attachment C, Feedwater Calorimetric Calculation, page 1 of 1, candidate determined Heat Transfer (H) hg - hFW = H 1194.2 - 411.2 783 Candidate discovered RO error: The RO used an incorrect set of values (hg and hFW) to calculate Heat Transfer. The values were based on 950 psig.

Comment: This is an RO error discovery point.

See Attachment C, step C.2.3 DRAFT 7 of 11

Appendix C Page 8 of 11 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 13 Using Attachment C, Feedwater Calorimetric Calculation, page 1 of 1, candidate evaluates RO work: Steam Generator Blowdown (SGBD) Correction Standard: Using Attachment C, Feedwater Calorimetric Calculation, page 1 of 1, candidate determined SGBD Correction 0.682%

((Avg SGBD rate) x (hfg) x (100)) ÷ 12.166E9 = SGBD correction (126.33 x 1000 x 657.05 x 100) ÷ 12.166E9 0.682%

Candidate discovered RO error: The RO used an incorrect hfg (based on 950 psig) to calculate the SGDB correction factor.

Comment: This is an RO error discovery point.

See Attachment C, step C.3

• Performance Step: 14 Using Attachment C, Feedwater Calorimetric Calculation, page 1 of 1, candidate evaluates RO work: Power calculation Standard: Using Attachment C, Feedwater Calorimetric Calculation, page 1 of 1, candidate determined: Power

(((Comp FW Flow) x (H) x (100)) ÷ 12.166E9) - RCP heat -

SGBD corr = Power

((15.11E6 x 783 x100) ÷ 12.166E9) - 0.415% - 0.682% 96.2%

power SRO calculates a Power of 96.2% - which is within the Acceptable Range for the surveillance.

Candidate discovered RO error: In the Power calculation, The RO did not use Compensated Feedwater flow, the Heat Transfer was incorrect and the SGBD correction was incorrect. All of these errors culminated in an erroneous Power Calculation.

Comment: This is an RO error discovery point.

See Attachment C, step C.4 DRAFT 8 of 11

Appendix C Page 9 of 11 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 15 Does not approve ROs performance of STS SE-002, MANUAL CALCULATION OF REACTOR THERMAL POWER.

Standard: SRO discovered the following errors:

Attachment B, CALORIMETRIC DATA COLLECTION:

Average SG Pressure of 950.56 psig instead of 965.26 psia Attachment C, FEEDWATER CALORIMETRIC CALCULATION:

• C.2.1: Incorrect Steam Enthalpy (hg) and Latent Heat of Vaporization (hfg) determined because RO used incorrect pressure value

• C.2.2: Incorrect Feedwater Enthalpy (hFW) because RO used incorrect pressure value

• C.2.3: Incorrect Heat Transfer (H) because pressure error carried through and the wrong values were used to calculate Heat Transfer

• C.3: Incorrect SGBD Correction factor because RO used an incorrect Latent Heat of Vaporization (hfg)

• C.4: Incorrect Power because the RO used the Total Average Feedwater flow instead of the Compensated Feedwater flow and an incorrect Heat Transfer and SGBD Correction factor.

SRO did not Approve STS SE-002, MANUAL CALCULATION OF REACTOR THERMAL POWER Comment:

Terminating Cue: JPM complete DRAFT 9 of 11

Appendix C Page 10 of 11 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: S.A.1.a Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 10 of 11

Appendix C Page 11 of 11 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: You are the Control Room Supervisor. The Reactor Operator (RO) reports that the power calculation between STS SE-001, POWER RANGE ADJUSTMENT TO CALORIMETRIC and STS SE-002, MANUAL CALCULATION OF REACTOR THERMAL POWER, do not agree within +/- 1% as required per step 8.9.2.3.

STS SE-001, POWER RANGE ADJUSTMENT TO CALORIMETRIC, calculated results are 97.1%.

Feedwater temperature is 430°F.

A personal computer is not available.

INITIATING CUE: Evaluate the ROs performance of STS SE-002, MANUAL CALCULATION OF REACTOR THERMAL POWER, Attachment B, CALORIMETRIC DATA COLLECTION, and Attachment C, FEEDWATER CALORIMETRIC CALCULATION.

Evaluate the ROs work and approve or disapprove the results.

Circle your response: Approve or Disapprove the results.

If there are any errors, list the errors.

DRAFT 11 of 11

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Approve a completed manual JPM No.: S.A.1.b calculation of shutdown margin per STS RE-004, SHUTDOWN MARGIN DETERMINATION K/A

Reference:

2.1.37 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: x Classroom x Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: You are the Control Room Supervisor (CRS).

Plant conditions are:

• Plant had been operating for 325 days

• Shutdown occurred on 8-29-11 at 0800 hours0.00926 days <br />0.222 hours <br />0.00132 weeks <br />3.044e-4 months <br />

• Currently: 8-29-11 at 1000 hours0.0116 days <br />0.278 hours <br />0.00165 weeks <br />3.805e-4 months <br />

• MODE 3, 557°F

• All control and shutdown rods are inserted

• Core average burnup is 20143 MWD/MTU

• Current boron is 490 ppm Task Standard: Upon completion, the candidate disapproved the ROs shutdown margin calculation and recommendation. Shutdown margin is met and an Immediate Boration was not required. The candidate discovered the following errors:

1. At step A.2.1, the RO used an incorrect temperature column and determined an incorrect minimum boron concentration.

2. At step A.2.3, the RO calculated the minimum boron concentration correctly using the wrong values. The minimum boron concentration is wrong.

3. At step A.2.4, the RO used the incorrect date & time when calculating the shutdown margin accuracy length of time.

4. At step A.3.1, the RO determined that the shutdown margin was not met and an Immediate Boration was required. This is incorrect. Shutdown margin is met (490 ppm boron 219 ppm boron) and an Immediate Boration is not required.

DRAFT 1 of 8

Appendix C Job Performance Measure Form ES-C-1 Worksheet Required Materials: Completed Attachment A, SHUTDOWN MARGIN CALCULATION SHORT FORM, from STS RE-004, SHUTDOWN MARGIN DETERMINATION, CONTROL ROOM OPERATING CURVES AND TABLES REFERENCE MANUAL, Cycle 18, WCRX-23 rev 27, calculator General

References:

STS RE-004, SHUTDOWN MARGIN DETERMINATION, and CONTROL ROOM OPERATING CURVES AND TABLES REFERENCE MANUAL, Cycle 18, WCRX-23 Handouts: Completed Attachment A, SHUTDOWN MARGIN CALCULATION SHORT FORM, from STS RE-004, SHUTDOWN MARGIN DETERMINATION, CONTROL ROOM OPERATING CURVES AND TABLES REFERENCE MANUAL, Cycle 18, WCRX-23 Initiating Cue: The Reactor Operator (RO) has completed Attachment A, SHUTDOWN MARGIN CALCULATION SHORT FORM. The RO reports that shutdown margin is not met and an Immediate boration is required.

Perform the verification and approve or disapprove the ROs results.

Show all work.

Circle your response: Approve or Disapprove the results.

If there are any errors, list the errors.

Time Critical Task:

(Yes or No) No Alternate Success Path: (Yes or No) No Validation Time: 20 minutes DRAFT 2 of 8

Appendix C Page 3 of 8 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: 1 Candidate receives handout materials to perform verification of shutdown margin.

Standard: Candidate received ROs completed Attachment A, SHUTDOWN MARGIN CALCULATION SHORT FORM, from STS RE-004, SHUTDOWN MARGIN DETERMINATION and CONTROL ROOM OPERATING CURVES AND TABLES REFERENCE MANUAL, Cycle 18, WCRX-23.

Comment: Step 8.2.9 Performance Step: 2 Candidate verifies Current Date/Time Standard: Candidate verified Current Date/Time written on Attachment A was correct.

Current Date/Time: 8-29-11 1000 hours0.0116 days <br />0.278 hours <br />0.00165 weeks <br />3.805e-4 months <br /> (see Initial Conditions)

Comment: Step A.1.1 Performance Step: 3 Candidate verifies Shutdown Date/Time Standard: Candidate verified Shutdown Date/Time written on Attachment A was correct.

Current Date/Time: 8-29-11 0800 hours0.00926 days <br />0.222 hours <br />0.00132 weeks <br />3.044e-4 months <br /> (see Initial Conditions)

Comment: Step A.1.2 Performance Step: 4 Candidate verifies Core Average Burnup Standard: Candidate verified Core Average Burnup written on Attachment A was correct.

Core Average Burnup: 20143 MWD/MTU (see Initial Conditions)

Comment: Step A.1.3 DRAFT 3 of 8

Appendix C Page 4 of 8 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 5 Candidate verifies Current Core Average Temperature Standard: Candidate verified Current Core Average Temperature written on Attachment A was correct.

Current Core Average Temperature: 557°F (see Initial Conditions)

Comment: Step A.1.4 Performance Step: 6 Candidate verifies Current Boron Concentration Standard: Candidate verified Current Boron Concentration written on Attachment A was correct.

Current Boron Concentration: 490 ppm boron (see Initial Conditions)

Comment: Step A.1.5 Performance Step: 7 Candidate verifies Boron-10 Correction Factor Standard: Candidate verified Boron-10 Correction Factor written on Attachment A was correct.

Boron-10 Correction Factor: 0.927 (see Curve Book, Table on page #5.8)

Comment: Step A.1.6

• Performance Step: 8 Candidate verifies Minimum Boron Concentration Standard: Candidate determined ROs Minimum Boron Concentration at A.2.1 was incorrect (483 ppm boron).

Candidate determined correct Minimum Boron Concentration was 805 ppm boron by using Curve Book page #7.1 (Burnup and temperature).

Comment: Step A.2.1 DRAFT 4 of 8

Appendix C Page 5 of 8 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 9 Candidate verifies Xenon credit.

Standard: Candidate verified Xenon credit by using Curve Book page

1. 4.13.

Xenon credit = 300 ppm Comment: Step A.2.2

• Performance Step: 10 Candidate verifies Minimum Boron Concentration calculation.

Standard: Candidate determined ROs Minimum Boron Concentration calculation was incorrect.

ROs work: 805 - 300 + [490 x (1 - 0.927)] = 541 ppm boron Candidates work: 483 - 300 + [490 x (1 - 0.927)] = 219 ppm boron Comment: Step A.2.3

• Performance Step: 11 Candidate verifies length of time shutdown margin will be accurate.

Standard: Candidate determined ROs Date and Time for shutdown margin accuracy was incorrect. (RO used the Current Date and Time instead of the Shutdown Date and Time)

ROs work: 8-29-11 and 1000 hours0.0116 days <br />0.278 hours <br />0.00165 weeks <br />3.805e-4 months <br /> plus twenty hours 8 11 and 0600 hours0.00694 days <br />0.167 hours <br />9.920635e-4 weeks <br />2.283e-4 months <br /> Candidates work: 8-29-11 and 0800 hours0.00926 days <br />0.222 hours <br />0.00132 weeks <br />3.044e-4 months <br /> plus twenty hours 8-30-11 and 0400 hours0.00463 days <br />0.111 hours <br />6.613757e-4 weeks <br />1.522e-4 months <br /> Comment: Step A.2.4 DRAFT 5 of 8

Appendix C Page 6 of 8 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 12 Candidate verifies ROs shutdown margin determination (is the Current Boron Concentration greater than or equal to the Minimum Boron Concentration?)

Standard: Candidate determined ROs shutdown margin determination and Immediate Boration recommendation was incorrect.

ROs work: 490 ppm boron current < 541 ppm boron minimum; therefore shutdown margin not met and an Immediate Boration was required.

Candidates work: 490 ppm boron current 219 ppm boron minimum; therefore shutdown margin was met and no Immediate Boration was required.

Comment: Step A.3.1 Terminating Cue: JPM complete DRAFT 6 of 8

Appendix C Page 7 of 8 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: S.A.1.b Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 7 of 8

Appendix C Page 8 of 8 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: You are the Control Room Supervisor (CRS).

Plant conditions are:

• Plant had been operating for 325 days

• Shutdown occurred on 8-29-11 at 0800 hours0.00926 days <br />0.222 hours <br />0.00132 weeks <br />3.044e-4 months <br />

• Currently: 8-29-11 at 1000 hours0.0116 days <br />0.278 hours <br />0.00165 weeks <br />3.805e-4 months <br />

• MODE 3, 557°F

• All control and shutdown rods are inserted

• Core average burnup is 20143 MWD/MTU

• Current boron is 490 ppm INITIATING CUE: The Reactor Operator (RO) has completed Attachment A, SHUTDOWN MARGIN CALCULATION SHORT FORM. The RO reports that shutdown margin is not met and an Immediate boration is required.

Perform the verification and approve or disapprove the ROs results. Show all work.

Circle your response: Approve or Disapprove the results.

If there are any errors, list the errors.

DRAFT 8 of 8

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Review and Approve completed JPM No.: S.A.2 Attachment A Data Sheet of STS EF-100B, ESW SYSTEM INSERVICE PUMP A & ESW A DISCHARGE CHECK VALVE TEST K/A

Reference:

2.2.12 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: x Classroom x Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: You are the Control Room Supervisor (CRS).

Task Standard: Upon completion, the candidate discovered three Reactor Operator errors on Attachment A, Test Data.

1. At 8.1.23, Train A flow (EF FI-53) is UNSAT. 7.0 E6 lbm/hr <

7.1 E6 lbm/hr minimum acceptable. Required action 1 (surveillance is failed, ESW A is inoperable, corrective action initiated)

2. At 8.1.24, Major Outboard Southwest (MOS) is UNSAT. 0.4311 in/sec > 0.4296 in/sec (maximum acceptable). Required action 1 and 3 (surveillance is failed, ESW A is inoperable, corrective action initiated; Support Eng contacted for further evaluation)

NOTE: The UNSAT may not be circled per Required Action 3 direction.

3. At 9.15.2, Calculated pump dP is SAT. 145.8 psid > 145.5 psid.

The surveillance was failed. ESW A declared inoperable. Support Engineering was contacted for further evaluations. Corrective actions were initiated.

DRAFT 1 of 7

Appendix C Job Performance Measure Form ES-C-1 Worksheet Required Materials: Completed STS EF-100B, ESW SYSTEM INSERVICE PUMP A & ESW A DISCHARGE CHECK VALVE TEST and Attachment A Test Data, calculator General

References:

STS EF-100B, ESW SYSTEM INSERVICE PUMP A & ESW A DISCHARGE CHECK VALVE TEST Handouts: Completed STS EF-100B, ESW SYSTEM INSERVICE PUMP A & ESW A DISCHARGE CHECK VALVE TEST and Attachment A Test Data Initiating Cue: The Reactor Operator (RO) has completed Attachment A Test Data for surveillance STS EF-100B, ESW SYSTEM INSERVICE PUMP A &

ESW A DISCHARGE CHECK VALVE TEST. The RO reports the surveillance is SAT.

Perform a review of the surveillance and Test Data and approve or disapprove the ROs results.

1. Circle your response: Approve or Disapprove the results.

2. If there are any errors, list the errors.

Time Critical Task:

(Yes or No) No Alternate Success Path: (Yes or No) No Validation Time: 30 minutes DRAFT 2 of 7

Appendix C Page 3 of 7 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: 1 Candidate receives handout materials to perform review of surveillance.

Standard: Candidate received completed STS EF-100B, ESW SYSTEM INSERVICE PUMP A & ESW A DISCHARGE CHECK VALVE TEST and Attachment A Test Data Comment:

Performance Step: 2 Candidate verifies Lake Level on Attachment A.

Standard: Candidate verified Lake level on Attachment A - SAT 1087.7 ft Comment: Step 8.1.2.3 Performance Step: 3 Candidate verifies calculation (converting Lake Level to an ESW Pump Suction Lift Pressure).

Standard: Candidate verified calculation (converting Lake Level to an ESW Pump Suction Lift Pressure) - SAT 6.81 psig Comment: Step 8.1.3 Performance Step: 4 Candidate verifies Suction Lift Pressure transferred to Attachment A Standard: Candidate verified Suction Lift Pressure transferred to Attachment A - SAT 6.81 psig Comment: Step 8.1.3.1 DRAFT 3 of 7

Appendix C Page 4 of 7 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 5 Candidate verifies ESW Pump A differential pressure calculation.

Standard: Candidate verified ESW Pump A differential pressure calculation.

6.81 psig + 139 psig = 145.81 psig Comment: Step 8.1.20.c Performance Step: 6 Candidate verifies Discharge pressures and Pressure difference on Attachment A.

Standard: Candidate verified Discharge pressures and Pressure difference Attachment A - SAT.

EF PI-11 139 psig EF PI-1 135 psig Pressure difference 4 psig - SAT Comment: Step 8.1.22

• Performance Step: 7 Candidate verifies Train A Flow as indicated on EF FI-53 on Attachment A.

Standard: Candidate verified Train A Flow = 7.0E6 lbm/hr - UNSAT 7.0 E6 lbm/hr < 7.1 E6 lbm/hr minimum acceptable Required action 1 (surveillance is failed, ESW A is inoperable, corrective action initiated)

Comment: This is an RO error discovery point. Step 8.1.23 DRAFT 4 of 7

Appendix C Page 5 of 7 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 8 Candidate verifies Pump Vibration Amplitudes on Test Data sheet.

Standard: Candidate verified Pump Vibration Amplitudes on Test Data sheet.

Candidate discovered Major Outboard Southwest (MOS) is UNSAT.

0.4311 in/sec > 0.4296 in/sec (maximum acceptable).

Required action 1 and 3 (surveillance is failed, ESW A is inoperable, corrective action initiated; Support Eng contacted for further evaluation)

Comment: This is an RO error discovery point. Step 8.1.24 Performance Step: 9 Candidate verifies ESW Pump dP calculation.

Standard: Candidate verified calculation.

6.81 psid + 139 psid = 145.8 psig Comment: Step 9.15.1

• Performance Step: 10 Candidate verifies ESW Pump dP calculation on Test Data sheet.

Standard: Candidate verified ESW Pump dP calculation on Test Data sheet

- SAT (6.81 + 139 = 145.81 psid) 145.8 psid > 145.5 psid Comment: This is an RO error discovery point. Step 9.15.2 Terminating Cue: JPM is complete DRAFT 5 of 7

Appendix C Page 6 of 7 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: S.A.2 Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 6 of 7

Appendix C Page 7 of 7 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: You are the Control Room Supervisor (CRS).

INITIATING CUE: The Reactor Operator (RO) has completed Attachment A Test Data for surveillance STS EF-100B, ESW SYSTEM INSERVICE PUMP A & ESW A DISCHARGE CHECK VALVE TEST. The RO reports the surveillance is SAT.

Perform a review of the surveillance and Test Data and approve or disapprove the ROs results.

1. Circle your response: Approve or Disapprove the results.

2. If there are any errors, list the errors.

DRAFT 7 of 7

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Authorize the restart of a JPM No.: S.A.3 Containment Purge Permit K/A

Reference:

2.3.6 Examinee

NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: x Classroom x Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: You are the Control Room Supervisor.

A Containment Purge Permit was performed on 8-28-11 at 62% power.

A second Containment Purge has been requested to support a Containment Entry on 8-30-11 at 0000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br />.

Current conditions: 50% power; Dayshift on 8-29-11 RM-11 Data:

GT RE-31, Containment Atmosphere Containment Particulate Channel, GTP311: 6.55E-016 µCi/cc Containment Iodine Channel, GTI312: 3.12E-015 µCi/cc Containment Noble Gas Channel, GTG313: 2.25E-06 µCi/cc GT RE-32, Containment Atmosphere Containment Particulate Channel, GTP321: 6.33E-012 µCi/cc Containment Iodine Channel, GTI322: 2.12E-013 µCi/cc Containment Noble Gas Channel, GTG323: 2.19E-06 µCi/cc Task Standard: Upon completion of the JPM, the candidate determined the following:

1. Yes, the radioactivity in Containment was within the restart limits of the Containment Purge Permit. WHY: The Containment atmospheric Noble Gas concentration did not increase by more than 10% from the original sample.

2. Yes, this Containment Purge permit can be used for the scheduled entry. WHY: The Containment Purge Permit will not expire before the scheduled Containment entry.

DRAFT 1 of 6

Appendix C Job Performance Measure Form ES-C-1 Worksheet Required Materials: Completed APF 07B-001-09-08, CONTAINMENT PURGE PERMIT, calculator General

References:

AP 07B-001, RADIOACTIVE RELEASES, APF 07B-001-09-08, CONTAINMENT PURGE PERMIT, AI 07B-024 INSTRUCTIONS FOR CONTAINMENT PURGE PERMITS Handouts: Completed APF 07B-001-09-08, CONTAINMENT PURGE PERMIT Initiating Cue: Determine the following:

1. Is the radioactivity in Containment within the restart limits of the Containment Purge Permit? Yes or No, Explain your answer.

2. Can this Containment Purge Permit be used to support the scheduled Containment Entry? Yes or No, Explain your answer.

Time Critical Task:

(Yes or No) No Alternate Success Path: (Yes or No) No Validation Time: 10 minutes DRAFT 2 of 6

Appendix C Page 3 of 6 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: 1 Candidate receives a completed Containment Purge Permit and calculator.

Standard: Candidate received a completed Containment Purge Permit and calculator.

Comment: Candidate used current revision of AP 07B-001 located in room 235.

• Performance Step: 2 Candidate determines if the radioactivity in Containment is within the restart limits.

Standard: Candidate determined radioactivity in Containment was within AP 07B-001 restart limits.

From Initial Conditions:

Containment Noble Gas Channel, GTG313: 2.25E-06 µCi/cc 2.25E-06 µCi/cc < 2.52E-06 µCi/cc or Containment Noble Gas Channel, GTG323: 2.19E-06 µCi/cc 2.19E-06 µCi/cc < 4.62E-06µCi/cc Therefore atmospheric noble gas concentration did not increase by more than 10% from the original sample.

Comment: Step 6.2.4.6 DRAFT 3 of 6

Appendix C Page 4 of 6 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 3 Candidate determines whether or not this Containment Purge Permit can be used to support the scheduled Containment Entry.

Standard: Candidate determined expiration date.

From Initial Conditions:

Unit is in MODE 1.

Scheduled Containment entry: 8-30-11 at 0000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> Permit expiration date: 8-30-11 at 0930 hours0.0108 days <br />0.258 hours <br />0.00154 weeks <br />3.53865e-4 months <br /> The current Containment Purge Permit is still valid.

Comment: Step 6.2.4.4 Terminating Cue: JPM complete.

DRAFT 4 of 6

Appendix C Page 5 of 6 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: S.A.3 Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 5 of 6

Appendix C Page 6 of 6 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: You are the Control Room Supervisor.

A Containment Purge Permit was performed on 8-28-11 at 62%

power. A second Containment Purge has been requested to support a Containment Entry on 8-30-11 at 0000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br />.

Current conditions: 50% power; Dayshift on 8-29-11 RM-11 Data:

GT RE-31, Containment Atmosphere Containment Particulate Channel, GTP311: 6.55E-016 µCi/cc Containment Iodine Channel, GTI312: 3.12E-015 µCi/cc Containment Noble Gas Channel, GTG313: 2.25E-06 µCi/cc GT RE-32, Containment Atmosphere Containment Particulate Channel, GTP321: 6.33E-012 µCi/cc Containment Iodine Channel, GTI322: 2.12E-013 µCi/cc Containment Noble Gas Channel, GTG323: 2.19E-06 µCi/cc INITIATING CUE: Determine the following:

1. Is the radioactivity in Containment within the restart limits of the Containment Purge Permit? Yes or No. Explain your answer.

2. Can this Containment Purge Permit be used to support the scheduled Containment Entry? Yes or No. Explain your answer.

Use the following to document answers:

1. Is the radioactivity in Containment within the restart limits of the Containment Purge Permit?

2. Can this Containment Purge Permit be used to support the scheduled Containment Entry?

DRAFT 6 of 6

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Classify an Event Using the JPM No.: S.A.4 Emergency Plan and make Protective Action Recommendations K/A

Reference:

2.4.41 / 2.4.44 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: x Classroom x Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: You are the Shift Manager. The following initial plant conditions exist:

• Plant tripped on Loss Of Off-site Power

• SYS OPS reports power will be restored in three hours

• Area rad monitor R39, CTMT RX SEAL TABLE indicates increasing radiation

• Containment pressure is 10 psig

• EMG E-0, REACTOR TRIP OR SAFETY INJECTION was entered Subsequently:

• Conditions degraded over the next 93 minutes to EMG FR-C2, RESPONSE TO DEGRADED CORE COOLING CONDITIONS, entry

• RVLIS level is 40% and decreasing

• B SG is faulted inside CTMT and indicates 9% WR level and decreasing

• At step 14, Depressurize All Intact S/Gs To 160 PSIG, C SG level was noted as increasing in an uncontrolled manner

• RCS pressure is 1600 psig and decreasing

• B SIP is the only ECCS pump operating (with 250 gpm flow)

• GT RR-60, CTMT RAD RECORDER, is 3.0 X 101 R/hr and stable

• All other indications are stable DRAFT 1 of 6

Appendix C Job Performance Measure Form ES-C-1 Worksheet Task Standard: Upon completion, the candidate correctly classified Site Area Emergency on Steam Generator Tube Failure tree, blocks 1, 2, 3, 4, 6, 7, and 8, determined a Protective Action Recommendation to evacuate John Redmond Reservoir (JRR) and Coffey County Lake (CCL) and completed the Immediate Notification form, sections 3, 4, 5 and 8.

Required Materials: APF 06-002-01, EMERGENCY ACTION LEVELS EPP 06-006, PROTECTIVE ACTION RECOMMENDATIONS EPF 06-007-01, WOLF CREEK GENERATING STATION EMERGECNY NOTIFICATION General

References:

APF 06-002-01, EMERGENCY ACTION LEVELS EPP 06-006, PROTECTIVE ACTION RECOMMENDATIONS EPF 06-007-01, WOLF CREEK GENERATING STATION EMERGECNY NOTIFICATION Handouts: APF 06-002-01, EMERGENCY ACTION LEVELS EPP 06-006, PROTECTIVE ACTION RECOMMENDATIONS EPF 06-007-01, WOLF CREEK GENERATING STATION EMERGECNY NOTIFICATION Initiating Cue: Classify the event based on conditions at this time and determine protective action recommendations, if any, and enter the Required data on the Immediate Notification form.

Required data is sections 3, 4, 5, and 8 on the Immediate Notification form.

Time Critical Task:

(Yes or No) No Alternate Success Path: (Yes or No) No Validation Time: 15 minutes DRAFT 2 of 6

Appendix C Page 3 of 6 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

• Performance Step: 1 Using the Emergency Action Level flowchart, diagnose plant conditions and classify the event.

Standard: EAL No Action this Category EAL SGTR: 1, 2, 3, 4, 6, 7, and 8 Site Area Emergency (SAE)

EAL LRCB: 1, 2, 3, 4, 8 Site Area Emergency EAL MSLB: 1, 2, 3, 9, 10, 11, 12 Site Area Emergency EAL FEF: 1, 2, 3, 5 Site Area Emergency EAL LEP/AC: 1, 2, 5 Notification of Unusual Event EAL No Action this Category EAL No Action this Category EAL No Action this Category EAL No Action this Category EAL No Action this Category EAL No Action this Category EAL No Action this Category Candidate classified the event: EAL SGTR: 1, 2, 3, 4, 6, 7, and 8 Site Area Emergency (SAE)

Comment:

• Performance Step: 2 Using EPP 06-006, PROTECTIVE ACTION RECOMMENDATIONS, determine any Protective Action Recommendations.

Standard: From Attachment A, PROTECTIVE ACTION RECOMMENDATION CHART, candidate determined a Protective Action Recommendation to evacuate John Redmond Reservoir (JRR) and Coffey County Lake (CCL).

Comment: Attachment A, Note A.

DRAFT 3 of 6

Appendix C Page 4 of 6 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 3 Completes the required sections of the Emergency Notification form.

Standard: Candidate completed the required data on the Immediate Notification form.

Section 3: Type: Immediate Section 4: Emergency Classification: correct date, time candidate classified and SAE Section 5: Reason for Classification: 2-SGTF, EAL Flowpath: 1, 2, 3, 4, 6, 7, and 8 Section 8: Protective Action Recommendation: Evacuate CCL and JRR Comment:

Terminating Cue: JPM complete when candidate determines EAL classification, protective action recommendations, if any and completes required data on Immediate Notification form.

DRAFT 4 of 6

Appendix C Page 5 of 6 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: S.A.4 Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 5 of 6

Appendix C Page 6 of 6 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: You are the Shift Manager. The following initial plant conditions exist:

• Plant tripped on Loss Of Off-site Power

• SYS OPS reports power will be restored in three hours

• Area rad monitor R39, CTMT RX SEAL TABLE indicates increasing radiation

• Containment pressure is 10 psig

• EMG E-0, REACTOR TRIP OR SAFETY INJECTION was entered Subsequently:

• Conditions degraded over the next 93 minutes to EMG FR-C2, RESPONSE TO DEGRADED CORE COOLING CONDITIONS, entry

• RVLIS level is 40% and decreasing

• B SG is faulted inside CTMT and indicates 9% WR level and decreasing

• At step 14, Depressurize All Intact S/Gs To 160 PSIG, C SG level was noted as increasing in an uncontrolled manner

• RCS pressure is 1600 psig and decreasing

• B SIP is the only ECCS pump operating (with 250 gpm flow)

• GT RR-60, CTMT RAD RECORDER, is 3.0 X 101 R/hr and stable

• All other indications are stable INITIATING CUE: Classify the event based on conditions at this time and determine protective action recommendations, if any, and enter the Required data on the Immediate Notification form.

Required data is sections 3, 4, 5, and 8 on the Immediate Notification form.

DRAFT 6 of 6

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Perform local actions to borate the JPM No.: P1 Reactor Coolant System.

K/A

Reference:

004 A2.14 and APE 024 AA1.04 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: x Actual Performance:

Classroom Simulator Plant x READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: You are the Auxiliary Building Operator. A Reactor trip has recently occurred from 100% power.

Task Standard: Upon completion of this JPM, the Candidate will have locally established emergency boration by opening BG HV-8104, Immediate Borate Valve to Charging Pump Suction, and verified greater than 30 gpm flow on BG FI-183B, Emergency Boration Flow Indicator.

Required Materials: OFN BG-009, EMERGENCY BORATION, Attachment A, Establishing Alternate Boration Flowpath, Personal Protective Equipment General

References:

OFN BG-009, EMERGENCY BORATION, Attachment A, Establishing Alternate Boration Flowpath Handouts: OFN BG-009, EMERGENCY BORATION, Attachment A, Establishing Alternate Boration Flowpath Initiating Cue: The Control Room Supervisor informs you that OFN BG-009, EMERGENCY BORATION, Attachment A, is being performed and that BG FCV-110A, Boric Acid Blending Tee Inlet Isolation Valve, will not open from the Control Room at step A2. The CRS directs you to locally perform actions to establish Emergency Boration.

DO NOT OPERATE ANY EQUIPMENT IN THE PLANT.

Time Critical Task:

(Yes or No) No DRAFT 1 of 7

Appendix C Job Performance Measure Form ES-C-1 Worksheet Alternate Success Path: (Yes or No) Yes Validation Time: 20 minutes DRAFT 2 of 7

Appendix C Page 3 of 7 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: 1 Open Boric Acid Blending Tee Inlet Isolation Valve.

o BG HIS-110A Fail open valve:

Standard: Candidate went to the A Safety Injection pump room on the 1974' level of the Aux. Bldg, and located valve BG HV-110A and its air isolations.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step A.2 Performance Step: 2 a. Locally isolate instrument air to valve.

Standard: Candidate closed instrument air isolation ball valves to the valve positioner by turning the handles perpendicular to the airline.

Cue: Cue: Valves are closed.

Score: SAT or UNSAT SAT or UNSAT Comment: Step A.2 RNOa NOTE: Handles are perpendicular to isolate airlines.

• Performance Step: 3 b. Locally vent air pressure from valve.

Standard: Candidate vented air by opening regulator air petcock located at the bottom of the air regulator in a counter-clockwise direction.

Cue: After Candidate described venting and expected responses:

No air is heard venting from regulator. BG FCV-110A does not move. Valve indications remain closed.

Score: SAT or UNSAT SAT or UNSAT Comment: Step A.2 RNOb

• Performance Step: 4 c. IF valve can NOT be opened, THEN go to step A8.

Standard: Candidate determined the valve cannot be locally opened by failing air and proceeded to step A8.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step A.2 RNOc DRAFT 3 of 7

Appendix C Page 4 of 7 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 5 Establish Manual Emergency Boration:

Standard: Candidate completed step A.8.a.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: A.8

• Performance Step: 6 a. () Locally open Emergency Boration Valve, BG HV-8104 Standard: Candidate located BG HV-8104 near BG-FCV-110A, in the A Safety Injection pump room.

Candidate described:

a. Engaging the manual operator by pulling down on the declutch lever.

b. Turning the handwheel until the clutch key is engaged.

c. Releasing the declutch lever.

d. Turning the handwheel in the counter-clockwise direction

e. The handwheel stops turning.

f. Indications of valve full open.

Cue: Cues (if necessary):

a. Declutch lever is pulled down.

b. Declutch lever is engaged.

c. Declutch lever released.

d. Handwheel is turning in the counter-clockwise direction.

e. Handwheel stops turning (when valve is full open).

f. Local position indication is full open.

Score: SAT or UNSAT SAT or UNSAT Comment: A.8.a NOTE: This is a reactivity step.

DRAFT 4 of 7

Appendix C Page 5 of 7 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 7 b. Check Emergency Boration flow - GREATER THAN 30 GPM o BG FI-183A Standard: Candidate contacted the Control Room to inform them BG HV-8104 is OPEN and for the Control Room to check flow on BG FI-183A.

Cue: After simulated Control Room contact by Gai-tronics:

BG FI-183A is erratic, check your local flow indicator BG FI-183B, Emergency Borate Flow meter and report.

NOTE: Candidate may call Control Room to verify flow. Cue from Control Room: flow is SAT.

Score: SAT or UNSAT SAT or UNSAT Comment: A.8.b Performance Step: 8 Candidate checks local flow indicator BG FI-183B for flow.

Standard: Candidate located local flow indicator BG FI-183B in 1974 Auxiliary Building hallway and described the expected reading was greater than 30 gpm.

Cue: When meter is located and expected indication is described:

Meter is reading greater than 90 gpm and stable.

Score: SAT or UNSAT SAT or UNSAT Comment: Step A.8.b Candidate may simulate contact with the Control Room with local reading.

Performance Step: 9 Return to procedure, step 2 Standard:

Cue: Candidate has completed JPM.

Score: SAT or UNSAT SAT or UNSAT Comment: A.8.c Terminating Cue: JPM is complete when candidate completes step A.8.

Candidate has opened BG-8104 and determined flow is 90 gpm.

DRAFT 5 of 7

Appendix C Page 6 of 7 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: P1 Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 6 of 7

Appendix C Page 7 of 7 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: You are the Auxiliary Building operator. A Reactor trip has recently occurred from 100% power.

INITIATING CUE: The Control Room Supervisor informs you that OFN BG-009, EMERGENCY BORATION, Attachment A, is being performed and that BG FCV-110A, Boric Acid Blending Tee Inlet Isolation Valve, will not open from the Control Room at step A2. The CRS directs you to locally perform actions to establish Emergency Boration.

DO NOT OPERATE ANY EQUIPMENT IN THE PLANT.

DRAFT 7 of 7

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Perform the local trip and reset of JPM No.: P2 the TDAFW Pump per STN FC-002 AUX FEEDWATER TURBINE OVERSPEED TEST, section 8.1.6 K/A

Reference:

061 2.1.20 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: x Actual Performance:

Classroom Simulator Plant x READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: You are a spare Operator assisting the Balance of Plant Operator in performance of STN FC-002, AUX FEEDWATER TURBINE OVERSPEED TEST.

Task Standard: Upon completion the Candidate tripped and reset the Auxiliary Feedwater Pump Turbine Mechanical Trip Mechanism.

Required Materials: STN FC-002, AUX FEEDWATER TURBINE OVERSPEED TEST, Personal Protective Equipment General

References:

STN FC-002 AUX FEEDWATER TURBINE OVERSPEED TEST Handouts: Field copy STN FC-002 AUX FEEDWATER TURBINE OVERSPEED TEST Initiating Cue: All procedure Prerequisites are met. The Reactor Operator directs you to perform step 8.1.6, Pre-Start Trip Check.

DO NOT OPERATE ANY EQUIPMENT IN THE PLANT.

Time Critical Task:

(Yes or No) No Alternate Success Path: (Yes or No) No DRAFT 1 of 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet Validation Time: 22 minutes DRAFT 2 of 10

Appendix C Page 3 of 10 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: 1 Candidate receives procedure and reviews procedure.

Standard: Candidate received procedure and reviewed procedure.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.1.6 Performance Step: 2 1. Establish communication between Control Room and local operator.

Standard: Candidate located nearest Gaitronics and (simulated) contact with Control Room.

Cue: After call is made:

Communication established.

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.1.6.1 Performance Step: 3 2. Close AUXILIARY STEAM SUPPLY TO TURBINE DRIVEN AUX FDW PUMP ISO.

o FC-V004 - CLOSED Standard: Candidate located FC-V004 in Turbine Driven Aux Feed Pump Room.

Candidate rotated valve handle in the clockwise direction until the stem was fully inserted and the handwheel stopped.

Cue: After the candidate described closing FC-V004:

Valve handle rotated in clockwise direction, valve is closed.

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.1.6.2 Note: Candidate may describe safety precautions necessary before manipulating this valve. This valve requires a ladder to access.

Examiner NOTE: Step 8.1.2 opened this valve to drain condensate from TDAFP steam supply piping.

DRAFT 3 of 10

Appendix C Page 4 of 10 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 4 3. Locally, manually open FC HV-312, AFP TURB MECH TRIP/THROT VLV fully and observe for turbine rotation.

Standard: Candidate located and opened FC HV-312:

1. Candidate described pulling down the valve operator declutch lever.

2. Candidate described turning the handwheel in a clockwise manner.

3. Candidate described the trip/latch pawl engagement as the stem traveled downward.

4. Candidate described rotating the handwheel in a counter-clockwise manner.

5. Candidate described indications of valve fully open.

Candidate observed for turbine rotation.

Cue: If necessary:

1. Declutch lever pulled down.

2. Handwheel is rotating clockwise.

3. Trip Latch Pawl is engaged.

4. Handwheel is rotating in the counter-clockwise direction.

5. Valve is open.

After valve is described as open:

No turbine rotation is occurring.

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.1.6.3 CAUTION prior to step: Initial turbine rotation could occur due to steam trapped between FC-V004 and FC HV-312.

Examiner NOTE: If Candidate does NOT go in closed direction first the trip/latch will not engage and the valve will not open.

• Performance Step: 5 4. Trip FC HV-312, by depressing the manual trip lever.

Standard: Candidate simulated depressing manual trip lever located on top of the turbine housing.

Cue: Turbine is tripped.

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.1.6.4 DRAFT 4 of 10

Appendix C Page 5 of 10 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 6 5. Close AFP TURB MECH TRIP/THROT VLV.

o FC HIS-312A Standard: Candidate simulated contact to Control Room to close FC HV-312A.

Cue: When Control Room contacted:

FC HIS-312A, AFP TURB MECH TRIP/THROT VLV, is CLOSED Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.1.6.5

• Performance Step: 7 6. Perform tappet nut drop test, by lifting tappet nut and letting it fall while ensuring smooth movement.

Standard: 1) Candidate located the tappet nut at the trip lever.

2) Candidate described moving the spring loaded emergency connecting rod toward the trip/throttle valve to allow free movement of tappet nut.

3) Candidate described lifting the tappet nut and releasing.

4) Candidate described smooth operation of the tappet nut.

Cue: After the candidate described movement of tappet nut drop test:

Tappet nut operated smoothly.

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.1.6.6 NOTES prior to procedure step 8.1.6.6:

• The spring loaded emergency connecting rod must be moved toward the Trip/Throttle Valve and held to keep the mechanical trip mechanism from interfering with the tappet nut drop test.

• Stem movement of FC HV-312 must stop prior to proceeding with this procedure [3.2.3]

• The following step resets limit switch LS-5, which will allow turbine operation.

DRAFT 5 of 10

Appendix C Page 6 of 10 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 8 7. Reset Mechanical Trip Mechanism, by moving spring-loaded emergency connecting rod toward trip throttle valve with just enough force to overcome spring tension, release the connecting rod.

Standard: 1. Candidate described moving the spring loaded emergency connecting rod toward the trip/throttle valve.

2. Candidate described the tappet nut falling into place with the washer flat side against the trip lever.

3. Candidate described the trip lever rising slightly.

4. Candidate described releasing the connecting rod and the rod resting against the opposing flat of the tappet nut.

Cue: After Candidate resets valve:

Head lever is seated against tappet.

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.1.6.7 CAUTION prior to step 8.1.6.7: LS-5 limit switch actuator arm may slide under the roller plate if the connecting rod is moved too far toward the AFP Turbine Trip/Throttle Valve.

DRAFT 6 of 10

Appendix C Page 7 of 10 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 9 7.a Verify the following:

• Tappet nut full down and flat side against the lever (refer to Operator Aid 96-14).

• Ann. 00-129C, TD AFP OVSP TRIP not lit

• Red light FC ZL-312DA, AFP TURB MECH TRIP not lit Standard: Candidate verified

1. Candidate referred to Operator Aid - Candidate checked tappet nut was full down and flat side was against the head lever.

2. Candidate simulated contact to Control Room and verified window 129C was not lit.

3. Candidate contacted Control Room and verified FC ZL-312DA was not lit.

Cue: 1.: Tappet nut is full down and flat side is against the head lever 2.: Annunciator 129C, TD AFP OVSP TRIP is NOT LIT 3.: Red light FC ZL-312DA, AFP TURB MECH TRIP is NOT LIT Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.1.6.7a Operator Aid 96-14 is located on South wall.

Performance Step: 10 8. IF AFP Turbine Mechanical Trip Mechanism does NOT reset, THEN perform the following:

a. Verify LS-5 limit actuation arm is on the inside (west) of the connecting rod roller plate.

b. Try to reset Mechanical Trip Mechanism, by repeating performance of step 8.1.6.7.

c. IF AFP Turbine Mechanical Trip Mechanism does NOT reset after second attempt, THEN notify SM/CRS.

Standard: Candidate determined step not applicable as the Mechanical Trip Mechanism was reset correctly in step 8.1.6.7.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.1.6.8 DRAFT 7 of 10

Appendix C Page 8 of 10 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 11 9. Slowly re-open FC-V004, AUXILIARY STEAM SUPPLY TO TURBINE DRIVEN AUX FDW PUMP ISO and observe for rotation.

Standard: Candidate located FC-V004 in Turbine Driven Aux Feed Pump Room.

1. Candidate described rotating the handwheel in the counter-clockwise direction until hearing steam flow and waiting for system to pressurize.

2. Candidate described flow noise disappearing then fully OPENED FC-V004

3. Candidate described observing for turbine rotation.

Cue: After Candidate performs:

2: Slow opening FC-V004: Valve is open.

3. Observation of rotation: No turbine rotation.

Score: SAT or UNSAT SAT or UNSAT Comment: Note: Candidate may describe safety precautions necessary before manipulating this valve. Step 8.1.6.9 Performance Step: 13 Section 8.1, Pre-test Alignment and Actions, complete Standard: Candidate determined that JPM is complete; step 8.1.6 was performed.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.1.7 Terminating Cue: JPM is complete when candidate completes Step 8.1.6.

DRAFT 8 of 10

Appendix C Page 9 of 10 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: P2 Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 9 of 10

Appendix C Page 10 of 10 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: You are a spare Operator assisting the Balance of Plant Operator in performance of STN FC-002, AUX FEEDWATER TURBINE OVERSPEED TEST.

INITIATING CUE: All procedure Prerequisites are met. The Reactor Operator directs you to perform section 8.1.6, Pre-Start Trip Check.

DO NOT OPERATE ANY EQUIPMENT IN THE PLANT.

DRAFT 10 of 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Respond to Emergency Diesel JPM No.: P3 Generator alarm K/A

Reference:

064 K1.03 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: x Actual Performance:

Classroom Simulator Plant x READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: You are a spare Operator. The plant is stable at 100% power. STS KJ-005A, MANUAL/AUTO START, SYNC & LOADING OF EDG NE01 is in progress. Control Room has received Annunciator 20D, DG NE01 TROUBLE.

Task Standard: Upon completion of this JPM the Candidate performed actions to correct a high strainer d/p by shifting fuel oil strainers per ALR 501, STANDBY DIESEL ENGINE SYSTEM CONTROL PANEL KJ-121.

Required Materials: ALR 501, STANDBY DIESEL ENGINE SYSTEM CONTROL PANEL KJ-121, Personal Protective Equipment General

References:

ALR 501, STANDBY DIESEL ENGINE SYSTEM CONTROL PANEL KJ-121 Handouts: ALR 501, STANDBY DIESEL ENGINE SYSTEM CONTROL PANEL KJ-121 Initiating Cue: The Control Room Supervisor directs you to investigate and correct the alarm condition.

DO NOT OPERATE ANY EQUIPMENT IN THE PLANT.

Time Critical Task:

(Yes or No) No DRAFT 1 of 9

Appendix C Job Performance Measure Form ES-C-1 Worksheet Alternate Success Path: (Yes or No) Yes Validation Time: 20 minutes DRAFT 2 of 9

Appendix C Page 3 of 9 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: 1 Candidate locates alarm panel KJ-121 in Emergency Diesel Generator (EDG) room A, northeast side.

Candidate checks local alarm panel KJ-121.

Standard: 1. Candidate located alarm panel KJ-121 in Emergency Diesel Generator (EDG) room A, northeast side.

2. Candidate described checking and acknowledging local alarm panel KJ-121.

Cue: 2. After candidate described checking KJ-121 panel alarms:

Annunciators "FUEL OIL PRESS. LOW," and "FUEL STRAIN.

DIFF. PRESS. HI" are locked in alarm.

Score: SAT or UNSAT SAT or UNSAT Comment:

Performance Step: 2 Candidate enters ALR 501.

Determine Attachments For Lit Annunciators From Table Below:

Standard: 1. Candidate located Alarm response procedure

2. Candidate used the Table to determine Attachment A for alarm window FUEL OIL PRESS. LOW lit Annunciator.

Cue: 1. When local ALR is located hand the Candidate a copy of ALR 501.

Score: SAT or UNSAT SAT or UNSAT Comment: ALR 501 Step 1 DRAFT 3 of 9

Appendix C Page 4 of 9 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 3 Check Fuel Oil Pressure From Fuel Filter - LESS THAN 10 PSIG

• KJ PI-13 Black Needle Standard: Candidate located and checked pressure gauge KJ PI-13 Black needle on KJ-121 Panel.

Cue: After the candidate described checking the pressure gauge:

Black Needle indicates 6 psig.

Score: SAT or UNSAT SAT or UNSAT Comment: ALR 501 Att. A step A1 NOTE: The Black needle is the "FROM" pressure and the Red needle is the "TO" pressure.

Performance Step: 4 Check Fuel Oil Filter Differential Pressure - LESS THAN 15 PSID

• KJ PI-13 Standard: Candidate located and checked pressure gauge KJ PI-13 Red Needle on KJ-121 Panel and determined the delta between the Black needle and the Red needle.

After cue Candidate determined fuel oil dP is 2 psid.

8 - 6 = 2 psid Cue: After the candidate described checking the pressure gauge:

Red needle indicates 8 psig.

Score: SAT or UNSAT SAT or UNSAT Comment: ALR 501 Att. A step A2 NOTE: The Black needle is the "FROM" pressure and the Red needle is the "TO" pressure.

DRAFT 4 of 9

Appendix C Page 5 of 9 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 5 Check Fuel Oil Strainer Differential Pressure - LESS THAN 2 PSID

• KJ PDI-10 Standard: 1. Candidate located and checked differential pressure gauge KJ PDI-10.

2. Candidate realized 4.5 psid exceeded 2 psid limit.

3. Candidate Performed RNO.

Cue: 1. After the candidate located & described check of differential pressure gauge:

KJ DPI-10 indicates 4.5 psid.

Score: SAT or UNSAT SAT or UNSAT Comment: ALR 501 Att. A step A3 Examiner NOTE: The dP gauge is under the Fuel Oil Strainers, on the southeast side of the engine.

Performance Step: 6 Candidate transitions to Attachment C, FUEL STRAIN. DIFF.

PRESS. HIGH Standard: Candidate transitioned to Attachment C, FUEL STRAIN. DIFF.

PRESS. HIGH Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: ALR 501 Attachment C DRAFT 5 of 9

Appendix C Page 6 of 9 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 7 Check Fuel Oil Strainer Differential Pressure - GREATER THAN 2 PSID

• KJ PDI-10 Standard: Candidate recalled differential pressure gauge KJ PDI-10 at 4.5 psid.

Procedure: Candidate realized 4.5 psid exceeded 2 psid limit.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: ALR 501 Att. C step C1 The dP gauge is under the Fuel Oil Strainers, on the southeast side of the engine.

• Performance Step: 8 Shift to Backup Fuel Oil Basket Strainer:

• KJBS01A Standard: Candidate located handwheel basket strainer KJBS01A.

Candidate shifted to backup strainer:

1. Simulated rotating the handwheel in the counterclockwise or clockwise direction.

2. Candidate described the stem and position indicator movement.

3. Candidate described arrow on stem indicating KJBS01A strainer was In Use.

Cue: After candidate describes shifting the strainer:

Backup strainer is in service.

If asked:

KJ PDI-10 indicates 0.5 psid, alarms are clear.

Score: SAT or UNSAT SAT or UNSAT Comment: ALR 501 Att. C step C2 Examiner NOTE: The handwheel will only turn in one direction when movement is attempted. Therefore the only way a Candidate will know which direction is to actually reposition the valve.

DRAFT 6 of 9

Appendix C Page 7 of 9 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 9 Inform The Control Room That The Fuel Oil Strainers Have Been Shifted Standard: Candidate located nearest Gaitronics and simulated a call to the Control Room informing them the fuel oil strainers were shifted per ALR 501 Attachment C.

Cue: After candidate describes actions to Control Room:

Understand backup strainer in service, the CRS will initiate a Condition Report, and Maintenance will be contacted.

Score: SAT or UNSAT SAT or UNSAT Comment: ALR 501 Att. C step C3 Performance Step: 10 Initiate A Condition Report To Have Mechanical Maintenance Clean The Dirty Fuel Oil Strainer After The Engine Is Shutdown Standard: Candidate recognized Control Room will perform this activity.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: ALR 501 Att. C step C4 Performance Step: 11 Return to Step 1 Standard: Candidate recognized JPM is complete.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: ALR 501 Att. C step C5 Examiner NOTE: If Candidate checks Alarm Panel status, Cue:

Alarms are clear.

Terminating Cue: JPM is complete when candidate placed the backup strainer in service.

DRAFT 7 of 9

Appendix C Page 8 of 9 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: P3 Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 8 of 9

Appendix C Page 9 of 9 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: You are a spare Operator. The plant is stable at 100% power.

STS KJ-005A, MANUAL/AUTO START, SYNC & LOADING OF EDG NE01 is in progress. Control Room has received Annunciator 20D, DG NE01 TROUBLE.

INITIATING CUE: The Control Room Supervisor directs you to investigate and correct the alarm condition.

DO NOT OPERATE ANY EQUIPMENT IN THE PLANT.

DRAFT 9 of 9

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Perform STS SF-001 CONTROL JPM No.: S1 AND SHUTDOWN ROD OPERABILITIY VERIFICATION for the Control Bank A K/A

Reference:

001 2.2.12 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: x Classroom Simulator x Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: You are the Reactor Operator. The plant is in MODE 1, steady state conditions. Tavg and Tref are within 1.5°F. No Load changes are planned. The Reactor Makeup System is in AUTO. There is no testing or maintenance being performed on the Rod Control System. Reliable communications are established and I&C personnel have been briefed and are stationed at the Rod Control Power Cabinets.

No fuel conditioning limits.

All Prerequisites for STS SF-001, CONTROL AND SHUTDOWN ROD OPERABILITIY VERIFICATION have been met.

Task Standard: Upon completion of the JPM, the candidate has exercised Control Bank A ten steps (ten steps inserted and ten withdrawn) using steps 8.2 through 8.10 of STS SF-001, CONTROL AND SHUTDOWN ROD OPERABILITIY VERIFICATION.

Required Materials: STS SF-001, CONTROL AND SHUTDOWN ROD OPERABILITIY VERIFICATION Simulator setup: IC 311; Run JPM S1 concurrent with S3.

Ensure the Reactor Makeup System is in AUTO.

Ensure Tavg and Tref are within 1.5°F.

DRAFT 1 of 12

Appendix C Job Performance Measure Form ES-C-1 Worksheet General

References:

STS SF-001, CONTROL AND SHUTDOWN ROD OPERABILITIY VERIFICATION Handouts: STS SF-001, CONTROL AND SHUTDOWN ROD OPERABILITIY VERIFICATION Initiating Cue: The Control Room Supervisor directs you to perform steps 8.2 through 8.10 of STS SF-001, CONTROL AND SHUTDOWN ROD OPERABILITIY VERIFICATION for Control Bank A (CBA).

Step 8.1 has been performed.

Time Critical Task:

(Yes or No) No Alternate Success Path: (Yes or No) No Validation Time: 20 minutes DRAFT 2 of 12

Appendix C Page 3 of 12 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: 1 Candidate receives procedure and reviews procedure.

Standard: Candidate received and reviewed procedure.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: STS SF-001, CONTROL AND SHUTDOWN ROD OPERABILITIY VERIFICATION NOTE prior to step 8.1: Annunciators 00-079C, RPI DEV OR PR TILT, and 00-081D, ROD BANK LO LIMIT are expected during performance of this test.

• Performance Step: 2 Place SE HS-9, ROD BANK AUTO/MAN SEL to the bank to be tested.

Standard: Candidate placed SE HS-9, ROD BANK AUTO/MAN SEL to CBA position.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.2 Performance Step: 3 Have I&C locally verify that the rod bank selected by SE HS-9 is lined up properly by light indication on the associated cabinet.

Refer to Attachment A, VERIFICATION OF LIGHT INDICATION for proper indication.

Standard: 1. Candidate contacted I&C. (Cue 1, if needed)

2. I&C verified proper light indication for CBA.

3. Candidate initialed Attachment A that correct group lamp was illuminated on the associated Rod Control Power Cabinet Cue: Cue 1: After candidate contacts I&C: On Power Cabinet Sierra Foxtrot 110 Charlie Lima slash Foxtrot Lima the Alpha lamp is illuminated.

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.3 using Attachment A step A.2 for CBA, SF110CL/FL - A lamp is lit.

DRAFT 3 of 12

Appendix C Page 4 of 12 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 4 Record the Initial Step Counter and Digital RPI Indications for the bank being tested on Attachment B, ROD OPERABILITY VERIFICATION DATA SHEET.

Standard: Candidate recorded current Step Counter and Digital RPI values for Control Bank A group 1 and Group 2 on Attachment B, ROD OPERABILITY VERIFICATION DATA SHEET (page 2 of 3).

Candidate wrote:

• Step Counter position - 227

• Digital RPI Indications - 228 Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.4 Candidate recorded 228 steps for rods H-6 and H-10 for Group 1 and 228 steps for F-8 and K-8 for Group 2.

Performance Step: 5 Monitor rod speed indication on SC SI-412, ROD SPEED, while inserting or withdrawing rods.

Standard: Candidate monitored rod speed indication on SC SI-412, ROD SPEED, while inserting or withdrawing rods.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.5 Rod speed will indicate 48 Steps/Min DRAFT 4 of 12

Appendix C Page 5 of 12 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 6 Insert selected bank rods, at the desired rate, as follows:

Standard: Candidate performed steps 8.6.1 through 8.6.4 Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.6 is a reactivity step.

NOTES prior to step 8.6:

• Rod movement should be made with due consideration of differential rod worth and the effects of temperature.

• For rods in the full out position, the reactivity insertion is bounded by a differential rod worth of 6 pcm/step CAUTIONs prior to step 8.6:

• Rod speed is 64 steps per minute for Shutdown Rods and 48 steps per minute for Control Rods.

• Rod speed indication is not available for shutdown banks C, D, and E.

• The amount of time that rods exceed the physical insertion limits specified in the CORE OPERATING LIMITS REPORT (COLR) should be minimized.

Performance Step: 7 Adjust turbine load as necessary, to maintain Tavg within 1°F of Tref.

Standard:

Cue: Turbine load adjustments will be made by the BOP.

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.6.1 Booth operator will ensure Tavg remains within 1°F of Tref.

DRAFT 5 of 12

Appendix C Page 6 of 12 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 8 Using SF HS-2, MAN ROD CTRL move rods IN, until the selected step counters indicate a change of 10 steps.

Standard: Candidate monitored Control Bank A step counters and inserted Control Bank A 10 steps.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.6.2 Candidate may check rod speed prior to moving rods.

Annunciators 00-079C, RPI DEV OR PR TILT and 00-081D, ROD BANK LO LIMIT are expected alarms.

Performance Step: 9 Record rod speed on ATTACHMENT B, ROD OPERABILITY VERIFICATION DATA SHEET.

Standard: Candidate recorded 48 on the IN block on ATTACHMENT B, ROD OPERABILITY VERIFICATION DATA SHEET (page 2 of 3).

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.6.3 Performance Step: 10 Record inserted rod positions on ATTACHMENT B, ROD OPERABILITY VERIFICATION DATA SHEET.

Standard: Candidate recorded 217 for Control Bank A Group 1 and Group 2 rod positions for Step Counters and 216 for rods H-6, H-10, F-8, and K-8 in the INSERTED column on ATTACHMENT B, ROD OPERABILITY VERIFICATION DATA SHEET (page 2 of 3).

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.6.4 DRAFT 6 of 12

Appendix C Page 7 of 12 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 11 IF the NPIS Computer is available, THEN verify the computer points listed below for all rod groups agree with the associated group step counter.

Standard: NPIS is available. Candidate used RBU turn on code to verify rod group agreement with the associated step counter.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.7 Performance Step: 12 Withdraw selected bank rods, at the desired rate, as follows:

Standard: Candidate performed steps 8.8.1 through 8.8.7 Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.8 is a reactivity step.

Performance Step: 13 Adjust turbine load as necessary, to maintain Tavg within 1°F of Tref.

Standard:

Cue: Turbine load adjustments will be made by the BOP.

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.8.1 Booth operator will ensure Tavg within 1°F of Tref.

• Performance Step: 14 Using SF HS-2, MAN ROD CTRL, move rods OUT, until the selected step counters indicate the position recorded in step 8.4.

Standard: Candidate monitored rod speed and withdrew CBA until the step counters indicated 227 steps.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.8.2 Annunciators 00-079C, RPI DEV OR PR TILT and 00-081D, ROD BANK LO LIMIT clear.

DRAFT 7 of 12

Appendix C Page 8 of 12 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 15 IF the Rods are withdrawn greater than 231 steps, THEN perform ATTACHMENT C, OVERSTEP RECOVERY, prior to selecting new bank.

Standard: Candidate recognized rods were not withdrawn greater than 231 steps - Step 8.8.3 was not applicable.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.8.3 Performance Step: 16 IF a control bank is restored to 222 steps AND 00-081D, ROD BANK LO LIMIT did NOT clear, THEN withdraw the bank a maximum of two additional steps to clear the alarm.

Standard: Candidate announced 00-081D, ROD BANK LO LIMIT clear and recognized Step 8.8.4 was not applicable.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.8.4 Performance Step: 17 IF the rods are withdrawn to a step greater than the position recorded in step 8.4 and 231 steps has NOT been exceeded, THEN step rods in to obtain the required position.

Standard: Candidate withdrew rods to position recorded in step 8.4, and recognized step 8.8.5 was not applicable.

OR IF candidate withdrew rods greater than recorded position at step 8.4 AND less than 231 steps: Then candidate stepped the rods IN to obtain 227 steps recorded in step 8.4.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.8.5 DRAFT 8 of 12

Appendix C Page 9 of 12 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 18 Record rod speed on ATTACHMENT B, ROD OPERABILITY VERIFICATION DATA SHEET.

Standard: Candidate wrote 48 in the OUT block for Control Bank A Group 1 and Group 2 on ATTACHMENT B, ROD OPERABILITY VERIFICATION DATA SHEET (page 2 of 3).

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.8.6 Performance Step: 19 Record final rod positions on ATTACHMENT B, ROD OPERABILITY VERIFICATION DATA SHEET.

Standard: Candidate recorded 227 steps for Step Counters Group 1 and group 2 and 228 steps for Digital RPI H-6, H-10, F-8 and K-8 in the FINAL column on ATTACHMENT B, ROD OPERABILITY VERIFICATION DATA SHEET (page 2 of 3).

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.8.7 Performance Step: 20 IF the NPIS Computer is available, THEN verify the computer points listed below for all rod groups agree with the associated group step counter.

Standard: Candidate recalled Initial Condition statement: NPIS is unavailable.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.9 Performance Step: 21 Initial and date the appropriate bank on ATTACHMENT B, ROD OPERABILITY VERIFICATION DATA SHEET.

Standard: Candidate initialed and dated the appropriate blocks for Control Bank A Group 1 and Group 2 on ATTACHMENT B, ROD OPERABILITY VERIFICATION DATA SHEET.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.10 DRAFT 9 of 12

Appendix C Page 10 of 12 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 22 Using SE HS-9, ROD BANK AUTO/MAN SEL select an unexercised rod bank and repeat steps 8.3 through 8.10, until all rod banks not fully inserted in the core have been tested.

Standard:

Cue: That completes this JPM.

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8.11 Terminating Cue: JPM is complete after candidate inserted and withdrew Control Bank A ten steps.

DRAFT 10 of 12

Appendix C Page 11 of 12 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: S1 Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 11 of 12

Appendix C Page 12 of 12 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: You are the Reactor Operator. The plant is in MODE 1, steady state conditions. Tavg and Tref are within 1.5°F. No Load changes are planned. The Reactor Makeup System is in AUTO.

There is no testing or maintenance being performed on the Rod Control System. Reliable communications are established and I&C personnel have been briefed and are stationed at the Rod Control Power Cabinets.

No fuel conditioning limits.

All Prerequisites for STS SF-001, CONTROL AND SHUTDOWN ROD OPERABILITIY VERIFICATION have been met.

INITIATING CUE: The Control Room Supervisor directs you to perform steps 8.2 through 8.10 of STS SF-001, CONTROL AND SHUTDOWN ROD OPERABILITIY VERIFICATION for Control Bank A (CBA).

Step 8.1 has been performed.

DRAFT 12 of 12

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Perform actions to ensure CRVIS JPM No.: S2 actuation using ALR 00-062D FBIS K/A

Reference:

013 A4.01 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: x Classroom Simulator x Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: You are the Reactor Operator. The plant has experienced a spurious FBIS and CRVIS.

Task Standard: Upon completion the candidate started Control Room A/C Unit 4B GK HIS-40 and Control Room Filtration Fan 3A GK HIS-19. Candidate checked dampers to and from Units 4B and 3A properly aligned.

Required Materials: ALR 00-062D, FBIS ALR 00-063A, CRVIS Simulator setup: IC 315 ACTUATE FBIS - both trains.

IC already includes malfunctions:

Use Defeat auto actuations for Yellow train:

IMF mSA27GK11A IMF mSA27GK11B Use Defeat auto actuations for Red train:

IMF mSA27GK05 General

References:

ALR 00-062D, FBIS ALR 00-063A, CRVIS Handouts: ALR 00-062D, FBIS ALR 00-063A, CRVIS DRAFT 1 of 9

Appendix C Job Performance Measure Form ES-C-1 Worksheet Initiating Cue: The Control Room Supervisor directs you to perform ALR 00-063A, CRVIS.

Time Critical Task:

(Yes or No) No Alternate Success Path: (Yes or No) Yes Validation Time: 10 minutes DRAFT 2 of 9

Appendix C Page 3 of 9 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: 1 Candidate receives ALR 00-063A, CRVIS Standard: Candidate received and reviewed ALR 00-063A, CRVIS.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment:

Performance Step: 2 Check EMGs - NOT IN EFFECT Standard: Candidate checked:

a. Unit at power

b. GEN 00-004 Power Operations - IN EFFECT Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 1 Performance Step: 3 Check Annunciator 00-063C, CTRL RM CL2 CRVIS - CLEAR Standard: Candidate observed alarm window 063C - NOT LIT Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 2 Performance Step: 4 Check Annunciator 00-063B, CTRL RM RAD HI CRVIS - CLEAR Standard: Candidate checked alarm window 063B - NOT LIT Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 3 DRAFT 3 of 9

Appendix C Page 4 of 9 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 5 Check Annunciator 00-059D, CPIS - CLEAR Standard: Candidate checked alarm window 059D - NOT LIT Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 4 Performance Step: 6 Check Annunciator 00-062D, FBIS - CLEAR Standard: Candidate checked alarm window 062D - LIT

a. Candidate performed the RNO - Go to ALR 00-062D, FBIS Step 1 Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 5 Examiner NOTE: Once the Candidate determines ALR 00-062D is to be performed, handout to Candidate the Alarm Response Procedure ALR 00-062D.

Performance Step: 7 Candidate receives ALR 00-062D, FBIS Standard: Candidate received and reviewed ALR 00-062D, FBIS Cue:

Score: SAT or UNSAT SAT or UNSAT Comment:

DRAFT 4 of 9

Appendix C Page 5 of 9 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 8 Verify Both Trains Of Control Room Ventilation Isolation:

a. Check ESFAS Status Panel CRVIS Section - ALL WHITE LIGHTS LIT o Red Train o Yellow Train Standard: Candidate checked SA 066-X Red Train All White Lights - LIT; NO

• CTRL ROOM FILTRATION FAN CGK03A

• CTRL RM FLTR SYS INLET DMPR

• CTR RM FLTR DISCH DMPR

• CTRL RM RECIRC DMPR

• CTRL RM A/C UNIT DISCH DMPR Candidate checked SA 066-Y Yellow Train All White Lights - LIT; NO

• CTRL RM A/C UNIT SGK04B

• CTRL RM A/C UNIT B DMPR GKHZ40A

• CTR RM A/C UNIT B DMPR GKHZ40B Candidate performed the RNO 1.a Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 1 DRAFT 5 of 9

Appendix C Page 6 of 9 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 9 Perform the following:

1) IF any CRVIS component NOT properly aligned, THEN manually align associated component.

Standard: Candidate noted components not LIT on both status panels and proceeded to RP-068 Panel in the back of the Control Room (Simulator) and performed the following on RED TRAIN:

1. Candidate started Control Room Filtration Fan (Red Train) by placing GK HIS-19 J-handle to RUN and observed RUN Red light - LIT and Green light -

EXTINGUISHED

2. Candidate observed GK HIS-19 INLET DAMPER -

Red light - LIT and Green light - EXTINGUISHED

3. Candidate observed GK ZL-19B Red light - LIT and Green light - EXTINGUISHED

4. Candidate observed GK ZL-19C Red light - LIT and Green light - EXTINGUISHED

5. Candidate observed GK ZL-19D Red light - LIT and Green light - EXTINGUISHED Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 1.a RNO Examiner Note: Trains separated for performance standards.

Candidate may check Status panel SA 066-X at this time to verify all white lights lit DRAFT 6 of 9

Appendix C Page 7 of 9 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 10 Perform the following:

IF any CRVIS component NOT properly aligned, THEN manually align associated component.

Standard: Candidate noted components not LIT on both status panels and proceeded to RP-068 Panel in the back of the Control Room (Simulator) and performed the following on YELLOW TRAIN:

1. Candidate started Control Room A/C Unit 4B by placing handswitch GK HIS-40, CTRL RM A/C UNIT 4B FAN &

DAMPER, to RUN and observed RUN Red light - LIT and Green light - EXTINGUISHED

2. Candidate observed SUPPLY DAMPER on handswitch Red light - LIT and Green light - EXTINGUISHED

3. Candidate observed CTRL RM A/C UNIT 4B DAMPER, limit lights - Red light - LIT, and Green light -

EXTINGUISHED Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 1.a RNO Examiner Note: Trains separated for performance standards.

Candidate may check Status panel SA 066-Y at this time to verify all white lights lit Performance Step: 11 JPM is complete Standard: Candidate completed actions to align CRVIS Cue:

Score: SAT or UNSAT SAT or UNSAT Comment:

Terminating Cue: JPM complete when Candidate completes step 1.a RNO of ALR 00-062D, FBIS, ensuring all components of CRVIS have actuated.

DRAFT 7 of 9

Appendix C Page 8 of 9 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: S2 Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 8 of 9

Appendix C Page 9 of 9 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: You are the Reactor Operator. The plant has experienced a spurious FBIS and CRVIS.

INITIATING CUE: The Control Room Supervisor directs you to perform ALR 00-063A, CRVIS.

DRAFT 9 of 9

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Diagnose and Mitigate Safety JPM No.: S3 Injection Pump Gas Voiding using OFN BG-045, GAS BINDING OF CCPS OR SI PUMPS K/A

Reference:

006 A2.04, 006 A2.05, 006 A4.01 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: x Classroom Simulator x Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: You are the Reactor Operator. The plant is stable in MODE 1.

Accumulator C level is 50% due to Chemistry sampling.

Task Standard: Upon completion of this JPM, the candidate has diagnosed SI Pump B gas binding and secured the pump.

Required Materials: SYS EP-200, SAFETY INJECTION ACCUMULATOR OPERATIONS, OFN BG-045, GAS BINDING OF CCPS OR SI PUMPS DRAFT 1 of 13

Appendix C Job Performance Measure Form ES-C-1 Worksheet General

References:

SYS EP-200, SAFETY INJECTION ACCUMULATOR OPERATIONS, OFN BG-045, GAS BINDING OF CCPS OR SI PUMPS Booth setup: IC 311 -- JPM S3 is run concurrent with S1 Ensure: EJ HIS-8890A is closed.

Enter: set asisal(3)=52275 Enter this file: for S3

Disch press oscillates

{x17i112r} IOR P17010A f:705 r:1 d:1

{x17i112r} IOR P17011A f:1805 r:1 d:1

{nemp01b & hwx17d113m < 0.041} IOR P17011A f:1805 r:1

{nemp01b & hwx17d113m > 0.9} IOR P17011A f:0 r:1

Disch flow oscillates

{nemp01b & hwx17d114m < 0.01} IOR P17010A f:705 r:1

{nemp01b & hwx17d114m < 0.01} IRF rEM01B f:5 r:1

{nemp01b & hwx17d114m > 0.6} IOR P17010A f:0 r:1

{nemp01b & hwx17d114m > 0.6} IRF rEM01B f:0 r:1

Pump amps oscillate

{nemp01b & hwx17d114m < 0.01} ICM trEMIIN018 t:3 f:0 r:1

{nemp01b & hwx17d114m > 0.4} ICM trEMIIN018 t:3 f:508 r:1

Pump in PTL

{!nemp01b} COR

{!nemp01b} DCM trEMIIN018

{!nemp01b} IRF rEM01B f:69.38 r:1 Booth: Verify Per SYS EP-200 Prereq 5.4: IC 311 - ensure CCW B for SIP B is running Per SYS EP-200 Prereq 5.8: historical trend for EP Accumulator pressure and level on NPIS available (EP1)

Handouts: Partially completed SYS EP-200, SAFETY INJECTION ACCUMULATOR OPERATIONS, OFN BG-045, GAS BINDING OF CCPS OR SI PUMPS Initiating Cue: The Control Room Supervisor provides you the following brief:

• You are to use Safety Injection Pump B to increase Safety Injection Accumulator "C" level to 58% using section 6.1 of SYS EP-200, SAFETY INJECTION ACCUMULATOR OPERATIONS.

• Safety Injection Pump discharge relief valves are expected to lift on pump start.

• Depressurizing the RHR header is not necessary.

• Procedure prerequisites have been completed.

Time Critical Task:

(Yes or No) No DRAFT 2 of 13

Appendix C Job Performance Measure Form ES-C-1 Worksheet Alternate Success Path: (Yes or No) Yes Validation Time: 20 minutes DRAFT 3 of 13

Appendix C Page 4 of 13 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: 1 Candidate receives and reviews SYS EP-200, SAFETY INJECTION ACCUMULATOR OPERATIONS Standard: Candidate received and reviewed SYS EP-200, SAFETY INJECTION ACCUMULATOR OPERATIONS Cue:

Score: SAT or UNSAT SAT or UNSAT Comment:

Performance Step: 2 IF Accumulator level is less than 45% AND Accumulator pressure is greater than 619 psig, THEN adjust Accumulator pressure to less than 619 psig, using section 6.7, Decreasing Accum Pressure.

Standard: Candidate recognized this step is not applicable.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: SYS EP-200 section 6.1 step 6.1.1 Performance Step: 3 Record RCS pressure read on any of the following indicators:

Standard: Candidate located indicators on Panel RL002.

Candidate recorded one RCS pressure from:

BB PI-455A BB PI-456 BB PI-457 BB PI-458 Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.1.2 Candidate may use NPIS display on RL022 panel - digital pressure is displayed using BBP0456 DRAFT 4 of 13

Appendix C Page 5 of 13 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 4 IF desired, THEN depressurize RHR header, as follows Standard: Candidate referred to Initiating Cue.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.1.3 NOTE prior to step: Depressurizing the RHR header should reduce back pressure on check valves EP-8818A, B, C and D, allowing the check valves to seat while the SI Pump is running.

This step should be performed at SM/CRS discretion and system engineering should be contacted.

Depressurization is not required for this JPM.

Performance Step: 5 IF using SI Pump A to fill Accumulators, THEN perform the following Standard: Candidate recognized this step is not applicable, Initiating Cue stated to use SI Pump B to fill the Accumulator.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.1.4 Performance Step: 6 IF using SI Pump B to fill Accumulators, THEN perform the following:

Standard: Candidate commenced steps 6.1.5.1 through 6.1.5.5.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.1.5 Performance Step: 7 Ensure SI PUMP B RECIRC TO RWST is open

• EM HIS 8814B - OPEN Standard: Candidate located EM HIS-8814B on RL017 Panel.

Candidate checked EM HIS-8814B was OPEN (Red Light LIT).

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.1.5.1 DRAFT 5 of 13

Appendix C Page 6 of 13 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 8 Ensure SI PUMPS RECIRC TO RWST is open

• BN HIS-8813 - OPEN Standard: Candidate located BN HIS-8813 on RL017 Panel.

Candidate checked BN HIS-8813 was OPEN (Red Light LIT).

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.1.5.2

• Performance Step: 9 IF SI Pump Discharge Relief valves are expected to lift on pump start, THEN close SI PUMP B DISCH TO COLD LEG INJ.

• EM HIS-8821B - CLOSED Standard: Candidate referred to Initiating Cue.

Candidate notified CRS of NOTE referring to TS 3.5.2 entry.

(See Cue)

Candidate located EM HIS-8821B on RL017 Panel.

Candidate depressed CLOSE pushbutton on EM HIS-8821B.

Candidate checked EM HIS-8821B Green Light was LIT and the Red Light EXTINGUISHED.

Cue: After candidate notified CRS of TS 3.5.2 reference: CRS and STA will refer to Technical Specification 3.5.2.

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.1.5.3 NOTE prior to step: Closing EM HIS-8821B, SI PUMP B DISCH TO COLD LEG INJ causes the SI Pump B C/L Injection path to be inoperable, refer to Technical Specification 3.5.2.

Performance Step: 10 Ensure NPIS computer trend has been started to monitor proper pump operation and system response. These points should include amps, suction pressure, discharge pressure, flow and any other available points.

Standard: Candidate used NPIS Computer to display desired point trends.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.1.5.4 DRAFT 6 of 13

Appendix C Page 7 of 13 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 11 Start SI PUMP B.

• EM HIS NORMAL AFTER RUN Standard: Candidate located EM HIS-5 on RL017 Panel.

Candidate announced starting the pump.

Candidate manipulated J-handle switch EM HIS-5 to the right (RUN).

Candidate verified Red Light - LIT, (Green Light -

EXTINGUISHED)

Cue: Cue if Building Watch contacted for pre-start pump checks: Pre-start pump checks are SAT.

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.1.5.5

• Performance Step: 12 If closed to prevent discharge relief valve lift, THEN open SI PUMP B DISCH TO COLD LEG INJ.

• EM HIS-8821B - OPEN Standard: Candidate located EM HIS-8821B on RL017 Panel.

Candidate depressed EM HIS-8821B OPEN pushbutton.

Candidate checked the Red Light was LIT and the Green Light EXTINGUISHED.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: STEP 6.1.5.6 DRAFT 7 of 13

Appendix C Page 8 of 13 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 13 On RL017 SI Pump B pressure and flow begin oscillating:

• EM PI-923 DISCH PRESS

• EM FI-922 DISCH FLOW

• NPIS trends on EM1 oscillating Standard: Candidate finds oscillating SI Pump B flow and pressure.

Candidate notified CRS of possible gas binding in SI Pump B.

Cue: EXAMINER QUERY after candidate notified CRS of oscillating SI Pump B flow and pressure and DOES NOT refer to gas binding:

What do you think the problem is?

After candidate notes oscillating SI Pump B flow and pressure and DOES refer to gas binding: Perform OFN BG-045, GAS BINDING OF CCPS OR SI PUMPS Score: SAT or UNSAT SAT or UNSAT Comment:

Performance Step: 14 Candidate receives and enters OFN BG-045, GAS BINDING OF CCPS OR SI PUMPS Standard: Candidate received and entered OFN BG-045, GAS BINDING OF CCPS OR SI PUMPS Cue:

Score: SAT or UNSAT SAT or UNSAT Comment:

Performance Step: 15 Check Charging Pump Affected Standard: Candidate checked CCP NOT affected - performed RNO: Go to step 12 Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: OFN BG-045 step 1 DRAFT 8 of 13

Appendix C Page 9 of 13 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 16 Stop The Affected SI Pump and Place In PTL EM HIS-4 For Pump A - PTL EM HIS-5 For Pump B - PTL Standard: Candidate confirmed SI Pump B is affected pump.

Candidate located EM HIS-5 on RL017 Panel.

Candidate stopped affected pump with EM HIS-5 J-handle rotated left to STOP.

Candidate checked Green light - LIT Candidate checked Red Light - EXTINGUISHED Candidate placed EM HIS-5 For Pump B - PTL (Candidate manipulated J-handle switch EM HIS-5 to the full left and raise (PTL). Handle remained pointed at PTL.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: OFN BG-045 step 12 DRAFT 9 of 13

Appendix C Page 10 of 13 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 17 Check SI Flow Required:

Any SI actuation setpoint exceeded RCS Subcooling - LES THAN 30°F [45°F]

PZR Level - LESS THAN 6% [33%]

Standard: Candidate checked:

Any SI actuation setpoint exceeded -- NO RCS Subcooling - LESS THAN 30°F [45°F] -- NO PZR Level - LESS THAN 6% [33%] - NO Candidate performed RNO: Go to step 15 Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: OFN BG-045 step 13 Examiner NOTE: SI actuation setpoints/ Subcooling/ PZR level:

RCS pressure is greater than 1830 psig No SG pressure is less than or equal to 615 psig Containment pressure is less than 3.5 psig RCS subcooling is greater than 30°F PZR level is greater than 6%

Performance Step: 18 Check No Signs Of Mechanical Damage To Affected SI Pump

• Dispatch operator to perform visual inspection of SI Pump.

Standard: Candidate contacted Aux Building Watch to perform a visual inspection of SI Pump B.

Cue: After candidate contacted Building Watch: I will perform the visual inspection of the SI Pump B.

Score: SAT or UNSAT SAT or UNSAT Comment: OFN BG-045 step 15 Examiner NOTE: The candidate may perform this action through the Control Room Supervisor.

DRAFT 10 of 13

Appendix C Page 11 of 13 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 19 Check Suction Path From RWST.

Ensure suction path to SI pump A

• EM HIS-8923A - OPEN BN HIS-8806A - OPEN BN HIS-8806B - OPEN Ensure suction path to SI pump B

• EM HIS-8923B - OPEN BN HIS-8806B - OPEN BN HIS-8806A - OPEN Standard: Candidate performed checks for SI Pump B

• Candidate located EM HIS-8923B on RL017 Panel.

Checked Red Light LIT Green Light EXTINGUISHED.

Candidate located BN HIS-8806B on RL017 Panel.

Checked Red Light LIT Green Light EXTINGUISHED.

Candidate located BN HIS-8806A on RL017 Panel.

Checked Red Light LIT Green Light EXTINGUISHED.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: OFN BG-045 step 16 Note: Either BN HIS-8806B or BN HIS-8806A open satisfies the step but Candidate may check both.

Performance Step: 20 Vent Affected SI Pump And/Or SI Piping, Using ATTACHMENT B, VENTING SAFETY INJECTION PUMPS, As Directed By The SM/CRS Standard: Candidate notified SM/CRS to vent affected SI Pump and Piping.

Cue: After candidate informs SM/CRS to vent affected SI Pump and Piping: JPM is concluded.

Score: SAT or UNSAT SAT or UNSAT Comment: OFN BG-045 step 17 Terminating Cue: The JPM is complete when candidate informs SM/CRS to vent affected SI Pump and Piping.

DRAFT 11 of 13

Appendix C Page 12 of 13 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: S3 Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 12 of 13

Appendix C Page 13 of 13 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: You are the Reactor Operator. The plant is stable in MODE 1.

Accumulator C level is 50% due to Chemistry sampling.

INITIATING CUE: The Control Room Supervisor provides you the following brief:

• You are to use Safety Injection Pump B to increase Safety Injection Accumulator "C" level to 58% using section 6.1 of SYS EP-200, SAFETY INJECTION ACCUMULATOR OPERATIONS.

• Safety Injection Pump discharge relief valves are expected to lift on pump start.

• Depressurizing the RHR header is not necessary.

• Procedure prerequisites have been completed.

DRAFT 13 of 13

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Perform actions to establish a JPM No.: S4 maximum rate cooldown using the ARVs per EMG E-3, STEAM GENERATOR TUBE RUPTURE K/A

Reference:

041 A4.06 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: x Classroom Simulator x Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: Plant was at full power with TDAFP tagged out when a SG Tube Rupture occurred on D SG. The crew is performing actions in EMG E-3, STEAM GENERATOR TUBE RUPTURE.

Task Standard: Upon completion of this JPM, the candidate performed a maximum rate cooldown - using Steam Generator Atmospheric Relief Valves

• AB PIC-1A, SG A STEAM DUMP TO ATMS CTRL

• AB PIC-2A, SG B STEAM DUMP TO ATMS CTRL

• AB PIC-3A, SG C STEAM DUMP TO ATMS CTRL DRAFT 1 of 9

Appendix C Job Performance Measure Form ES-C-1 Worksheet Required Materials: EMG E-3, STEAM GENERATOR TUBE RUPTURE Sim setup: IC 313 -- Run concurrent with JPM S8 Run simgroup Tag file for TDAFW pump - tagout.

Ensure MSIVs are ALL CLOSED.

Place ORANGE ISOLATED mag tags next to the following valves on RL005:

AL HIS-32A AL HIS-33A AL HIS-36A AB HIS-6A AB HIS-5A Place a TEST/CAUTION tag on FC HIS-312A.

Adjust SG D ARV to 1160 psig.

Place a FUB on RL006 next to SG D placard.

Verify steps 1-10 of EMG E-3 are completed.

General

References:

EMG E3, STEAM GENERATOR TUBE RUPTURE.

Handouts: EMG E-3, STEAM GENERATOR TUBE RUPTURE.

Initiating Cue: The CRS directs you to complete steps 11 through 17 of EMG E-3, STEAM GENERATOR TUBE RUPTURE.

Time Critical Task:

(Yes or No) No Alternate Success Path: (Yes or No) No Validation Time: 20 minutes DRAFT 2 of 9

Appendix C Page 3 of 9 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: 1 Candidate receives and reviews EMG E-3, STEAM GENERATOR TUBE RUPTURE.

Standard: Candidate received and reviewed EMG E-3, STEAM GENERATOR TUBE RUPTURE Cue:

Score: SAT or UNSAT SAT or UNSAT Comment:

Performance Step: 2 Check If Low Steam Line SI Should Be Blocked:

a. Check RCS pressure - LESS THAN 1970 PSIG

• P-11 light - LIT

b. Block low steamline pressure SI

• SB HS-9

• SB HS-10 Standard: Candidate checked P-11 light - LIT on SB069 Partial Trip Status Permis/Bloc Panel - if NO, Candidate continues on to step 12 If YES, Candidate performed the following:

Candidate depressed SB HS-9 on RL02 Candidate depressed SB HS-10 on RL02 Candidate checked STM LINE SI TRN A BLOC - LIT on SB069 Candidate checked STM LINE SI TRN B BLOC - LIT on SB069 Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 11 When RCS pressure is less than 1970, then the Candidate will block Low Steam line SI.

DRAFT 3 of 9

Appendix C Page 4 of 9 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 3 Determine target plant conditions from the table below.

Standard: Ruptured SG should be between 1100 and 1199 psig.

Target conditions should be:

• 508°F Core Exit TC and

• 717 psig using the ARV on intact S/Gs for ruptured D S/G pressure equal to 1150 psig.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 12 Examiner NOTE: Depending on the ruptured S/G pressure, target values may be different than those in the standard.

Performance Step: 4 Determine Method Used To Cooldown RCS At Maximum Rate:

• Check Steam Dumps - AVAILABLE Standard: Candidate checked MSIVs OPEN - NO.

Candidate performed RNO - Went to step 15.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 13 Examiner NOTE: RCPs are not running.

Caution prior to step 13: If RCPs are NOT running, the cooldown and depressurization steps may cause a red or orange path condition on the integrity status tree for the ruptured loop. Step 52 shall be completed before reevaluating the red or orange path condition and transition to EMG FR-P1, RESPONSE TO IMMINENT PRESSURIZED THERMAL SHOCK CONDITIONS, if required.

Note: After operator initiated RCS cooldown has been started, RCP trip criteria no longer applies.

DRAFT 4 of 9

Appendix C Page 5 of 9 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 5 Initiate RCS Cooldown Using ARVs or TDAFP:

a. Check Intact S/G(s) - AVAILABLE

1) Dump steam at maximum rate:

Set intact S/G ARV controllers to target intact S/G pressure Use intact S/G ARVs in manual Operate turbine driven AFW pump at maximum load Standard:

• Candidate checked ARV controllers in AUTO:

AB PIC-1A SG A STEAM DUMP TO ATMS CTRL AB PIC-2A SG B STEAM DUMP TO ATMS CTRL AB PIC-3A SG C STEAM DUMP TO ATMS CTRL

• Candidate used thumbwheel to reduce controller pressure setting between 700 and 720 psig increments on:

AB PIC-1A SG A STEAM DUMP TO ATMS CTRL AB PIC-2A SG B STEAM DUMP TO ATMS CTRL AB PIC-3A SG C STEAM DUMP TO ATMS CTRL Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 15 Examiner NOTE: Acceptable to depress the MAN button ARV controllers and fully open ARVs using the joystick. The candidate must stop the cooldown below S/G pressure AND RCS Target temperature if this method is used.

DRAFT 5 of 9

Appendix C Page 6 of 9 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 6 Maintain Maximum Rate Cooldown:

a. Check Steam Dumps - AVAILABLE; NO, Perform RNO Standard: Candidate performed RNO:

• Candidate checked ARVs throttling closed as target pressure is approached or that maximum rate was achieved.

• Candidate informed the CRS maximum rate cooldown in progress Cue: Once the cooldown has been established: Understand Max Rate Cooldown in progress.

Score: SAT or UNSAT SAT or UNSAT Comment: Step 16 Examiner NOTE: Once the maximum rate cooldown is started RCS pressure will decrease; the Candidate should return to step 11 and block low steamline SI when RCS pressure is less than 1970 psig.

Performance Step: 7 Check Intact SG Levels:

a. Check narrow range level in at least on SG - GREATER THAN 6% [29%]

b. Control feed flow to maintain narrow range level in all SGs between 295 [29%] and 50%

Standard: Candidate performed:

a. Checked narrow range level - the ruptured steam generator level is greater than 6%, the intact steam generator levels are less than 6%.

b. Candidate increased AFW flow to the intact steam generators using

• SG A MD AFP AFW REG VLV CTRL, AL HK-7A for SG A

• SG B MD AFP AFW REG VLV CTRL, AL HK-9A for SG B

• SG C MD AFP AFW REG VLV CTRL, AL HK11A for SG C Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 17 DRAFT 6 of 9

Appendix C Page 7 of 9 Form ES-C-1 PERFORMANCE INFORMATION Terminating Cue: JPM is terminated when candidate establishes the cooldown by opening the intact S/G ARVs and establishing additional AFW flow to the intact steam generators.

DRAFT 7 of 9

Appendix C Page 8 of 9 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: S4 Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 8 of 9

Appendix C Page 9 of 9 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: Plant was at full power with TDAFP tagged out when a SG Tube Rupture occurred on D SG. The crew is performing actions in EMG E-3, STEAM GENERATOR TUBE RUPTURE.

INITIATING CUE: The CRS directs you to complete steps 11 through 17 of EMG E-3, STEAM GENERATOR TUBE RUPTURE.

DRAFT 9 of 9

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Align Alternate Seal Injection and JPM No.: S5 Place Excess Letdown Into Service Per OFN KA-019, Loss Of Instrument Air K/A

Reference:

003 A4.01 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom Simulator X Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: You are the Reactor Operator. The plant is at ~44% power and Xenon is approaching equilibrium. An air leak downstream of KA-V584, TURB BLDG INSTRUMENT AIR HDR TO AUX BLDG ISO, has caused valves in the Auxiliary and Containment buildings to fail. The CRS has entered OFN KA-019 LOSS OF INSTRUMENT AIR.

Task Standard: Upon completion of this JPM, the candidate aligned alternate RCP seal injection flow and stabilized Pressurizer level with excess letdown.

Required Materials: OFN KA-019, LOSS OF INSTRUMENT AIR, step 5.

Simulator set-up: IC 316. Run JPM concurrent with S7 (File used: aovEFHV0043 failed open, mKA01J at maximum SCFM for S5)

General

References:

OFN KA-019, LOSS OF INSTRUMENT AIR Handouts: OFN KA-019, LOSS OF INSTRUMENT AIR, step 5 Initiating Cue: The CRS directs you to perform step 5 of OFN KA-019, LOSS OF INSTRUMENT AIR.

Time Critical Task:

(Yes or No) No DRAFT 1 of 9

Appendix C Job Performance Measure Form ES-C-1 Worksheet Alternate Success Path: (Yes or No) Yes Validation Time: 20 minutes DRAFT 2 of 9

Appendix C Page 3 of 9 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: 1 Candidate receives and reviews OFN KA-019, LOSS OF INSTRUMENT AIR, step 5.

Standard: Candidate received and reviewed OFN KA-019, LOSS OF INSTRUMENT AIR, step 5.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment:

Performance Step: 2 Check PZR Level - STABLE USING NORMAL CHARGING AND LETDOWN Standard: Candidate checked BG FI-121A, CHG HDR FLOW, at maximum flow.

Candidate checked BG FI-132 LTDN HX OUTLET flow at 0 gpm.

Candidate checked BB LR-459, PZR PROGRAM LEV RECORDER trend is INCREASING above program.

Candidate performed the RNO.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 5 Performance Step: 3 Stabilize PZR level as follows:

a. Ensure a CCW pump is running in the train containing the CCP with the discharge valve closed.

Standard: Candidate located Train A CCW pump handswitches on RL019.

Candidate started either A or C CCW pump using handswitch:

EG HIS-21 EG HIS-23 Cue: If Candidate requests which pump to start:

Start A CCW Pump.

Score: SAT or UNSAT SAT or UNSAT Comment: Step 5 RNO a.

DRAFT 3 of 9

Appendix C Page 4 of 9 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 4 b. Start standby CCP with discharge valve closed.

Standard: Candidate located A CCP handswitch BG HIS-1A on RL001.

Candidate started A CCP using BG HIS-1A.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 5 RNO b.

Examiner NOTE: The A CCP Handswitch will have a blue placard over the J-handle identifying the discharge valve is closed.

• Performance Step: 5 c. Establish seal injection through alternate seal injection line.

BG HIS-8357A for CCP A BG HIS-8357B for CCP B Standard: Candidate located handswitch BG HIS-8357A on RL001 Candidate throttled open BG HIS-8357A by holding the OPEN pushbutton until seal injection flow increased on BG FI-215A and BG FI-215B CHG PUMP TO RCP SEAL FLOW, meters.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 5 RNO c.

Examiner NOTE: Both meters will indicate increased seal flow.

Performance Step: 6 d. Stop previously running charging pump Standard: Candidate located BG HIS-3, NORMAL CHARG PMP handswitch.

Candidate turned J-handle on BG HIS-3 to STOP - Green light -

LIT, Red light - EXTINGUISHED Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 5 RNO d.

Candidate may increase or adjust seal injection flow as necessary after NCP is secured based on flow change after pump is secured.

DRAFT 4 of 9

Appendix C Page 5 of 9 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 7 e. Establish excess letdown:

1) Open EXCESS Letdown Heat Exchanger Outlet Isolation To PRT valves BB HIS-8157A BB HIS-8157B Standard: Candidate located BB HIS-8157A and BB HIS 8157B Candidate pushed and held BB HIS-8157A until Red light - LIT and Green light - EXTINGUISHED Candidate pushed and held BB HIS-8157B until Red light - LIT and Green light - EXTINGUISHED Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 5 RNO e.1 Performance Step: 8 2) IF aligning train A valves THEN open the following:

a) BG HIS-8153A b) BG HIS-8154A Standard: Candidate located BG HIS-8154A on RL001.

Candidate pushed BG HIS-8154A OPEN pushbutton to the latch position - Red light - LIT, Green light - EXTINGUISHED Candidate located BG HIS-8153A on RL001.

Candidate pushed BG HIS-8153A OPEN pushbutton to the latch position - Red light - LIT, Green light - EXTINGUISHED Cue: If asked by Candidate for desired train:

Align Alpha Train.

Score: SAT or UNSAT SAT or UNSAT Comment: Step RNO e.2 Examiner NOTE: Only one train of excess letdown should be aligned. Either train may be aligned to satisfy this JPM.

DRAFT 5 of 9

Appendix C Page 6 of 9 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 9 3) IF aligning train B valves THEN open the following:

a) BG HIS-8153B b) BG HIS-8154B Standard: Candidate located BG HIS-8154B on RL001.

Candidate pushed BG HIS-8154A OPEN pushbutton to the latch position - Red light - LIT, Green light - EXTINGUISHED Candidate located BG HIS-8153B on RL001.

Candidate pushed BG HIS-8153B OPEN pushbutton to the latch position - Red light - LIT, Green light - EXTINGUISHED Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 5 RNO e.3 Examiner NOTE: Only one train of excess letdown should be aligned.

• Performance Step: 10 4) Adjust Excess Letdown Heat Exchanger Outlet Isolation Valves as necessary to control excess letdown flow.

BB HIS-8157A BB HIS-8157B Standard: Candidate adjusted BB HIS-8157A or BB HIS-8157B until approximately 20 gpm observed on BG FI-138A and BG FI-138B, EXCESS LTDN HX TO PRT, meters.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 5 RNO e. 4 DRAFT 6 of 9

Appendix C Page 7 of 9 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 11 f. Balance excess letdown and seal injection flows.

Standard: Candidate adjusted BG HIS-8357A until BG FI-215A/B read approximately 32 gpm.

Candidate verified excess letdown at approximately 20 gpm.

Candidate checked BB LR-459, PZR PROGRAM LEV RECORDER, for Pressurizer level trend stabilizing.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 5 RNO f.

Examiner NOTE: JPM may be terminated when RCP seal injection and excess letdown are in service.

Performance Step: 12 Step Complete Standard: Candidate recognized JPM was complete.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: OFN KA-019 Step 5 Terminating Cue: When alternate seal injection and excess letdown are in service, JPM is complete.

DRAFT 7 of 9

Appendix C Page 8 of 9 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: S5 Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 8 of 9

Appendix C Page 9 of 9 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: You are the Reactor Operator. The plant is at ~44% power and Xenon is approaching equilibrium. An air leak downstream of KA-V584, TURB BLDG INSTRUMENT AIR HDR TO AUX BLDG ISO, has caused valves in the Auxiliary and Containment buildings to fail. The CRS has entered OFN KA-019 LOSS OF INSTRUMENT AIR.

INITIATING CUE: The CRS directs you to perform step 5 of OFN KA-019, LOSS OF INSTRUMENT AIR.

DRAFT 9 of 9

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Startup the Containment Mini-Purge JPM No.: S6 System per SYS GT-120, CONTAINMENT MINI PURGE SYSTEM OPERATIONS K/A

Reference:

103 A1.01 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: x Classroom Simulator x Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: You are the Reactor Operator. The plant is at ~44% and Xenon is approaching equilibrium. Containment pressure is at 27 INWC.

A Containment entry is planned for later in the shift. Outside temperature is 70°F.

A Gaseous Release Permit (GRP) for a Containment Purge has been issued by Chemistry. Prerequisites of SYS GT-120, CONTAINMENT MINI PURGE SYSTEM OPERATIONS are complete.

Task Standard: Upon completion of the JPM, the candidate completed sections 6.1, Startup Of CTMT Mini Purge Exhaust and 6.2, Startup Of CTMT Mini Purge Supply.

Required Materials: Partially completed SYS GT-120, CONTAINMENT MINI PURGE SYSTEM OPERATIONS Simulator set-up: IC 314.

Depressurization may require time compression.

General

References:

SYS GT-120, CONTAINMENT MINI PURGE SYSTEM OPERATIONS Handouts: Partially completed SYS GT-120, CONTAINMENT MINI PURGE SYSTEM OPERATIONS, and GRP 2011-1234 for Containment Purge.

DRAFT 1 of 11

Appendix C Job Performance Measure Form ES-C-1 Worksheet Initiating Cue: The CRS directs you to perform SYS GT-120, CONTAINMENT MINI PURGE SYSTEM OPERATIONS sections 6.1 to depressurize the Containment and 6.2 to place Mini-Purge Supply into service.

Time Critical Task:

(Yes or No) No Alternate Success Path: (Yes or No) No Validation Time: 20 minutes DRAFT 2 of 11

Appendix C Page 3 of 11 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: 1 Candidate receives and reviews SYS GT-120, CONTAINMENT MINI PURGE OPERATIONS Standard: Candidate received and reviewed SYS GT-120, CONTAINMENT MINI PURGE OPERATIONS Cue:

Score: SAT or UNSAT SAT or UNSAT Comment:

Performance Step: 2 Candidate performs section 6.1 Standard: Candidate performed section 6.1 Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.1 Performance Step: 3 Record the time/date Purge must be initiated from the permit.

Standard: From the Special Instructions section of the GRP, the candidate recorded the INITIATE RELEASE PRIOR to Time and Date from the permit.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.1.1 DRAFT 3 of 11

Appendix C Page 4 of 11 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 4 Perform the following CTMT Purge Damper lineup:

1. Open CTMT PURGE DAMPER. (D012)

• GT HIS OPEN

2. Open CTMT PURGE EXH DAMPER. (D011)

• GT HIS OPEN

3. Open CTMT MINI PURGE EXH OUTER CTMT ISO.

• GT HIS OPEN

4. Record Time/Date Dampers Opened.

Standard: Candidate located controls on RL020 Panel.

Candidate performed the following actions:

1. Open CTMT PURGE DAMPER. (D012)

• GT HIS Depressed and held OPEN pushbutton until the Green light was EXTINGUISHED and the Red Light was LIT.

2. Open CTMT PURGE EXH DAMPER. (D011)

• GT HIS Depressed and held OPEN pushbutton until the Green light was EXTINGUISHED and the Red Light was LIT.

3. Open CTMT MINI PURGE EXH OUTER CTMT ISO.

• GT HIS Depressed and held OPEN pushbutton until the Green light was EXTINGUISHED and the Red Light was LIT.

4. Recorded time/date dampers opened.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.1.2 DRAFT 4 of 11

Appendix C Page 5 of 11 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 5 Start CTMT MINI PURGE EXH FAN & DAMPER and verify its discharge damper (D005) opens.

• GT HIS NORMAL AFTER RUN and

• GT HZ OPEN Standard: Candidate located controls on RL020 Panel.

Candidate started CTMT MINI PURGE EXH FAN and verified the discharge damper open

• GT HIS J-handle manipulated to the RIGHT (RUN position) and released. Green Light EXTINGUISHED and Red Light LIT.

• Candidate checked GT HZ Damper open: Green Light EXTINGUISHED and Red Light LIT.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: STEP 6.1.3 NOTE prior to step 6.1.3: Prior to CTMT pressure decreasing to less than -5.5 inches water (-0.2 psig), ensure the CTMT Mini Purge Exhaust Fan is stopped.

• Performance Step: 6 Open CTMT MINI PURGE EXH INNER CTMT ISO and record time/date opened.

• GT HIS OPEN

• Time/Date Opened Standard: Candidate located control on RL020 Panel.

• GT HIS Depressed and held OPEN pushbutton until the Green light was EXTINGUISHED and the Red Light was LIT.

• Candidate recorded time and date OPENED Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.1.4 DRAFT 5 of 11

Appendix C Page 6 of 11 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 7 Section 6.1, Startup Of CTMT Mini Purge Exhaust, complete.

Standard: Candidate initialed and dated Step 6.1.5, Section 6.1, Startup Of CTMT Mini Purge Exhaust, complete.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.1.5 Performance Step: 8 Candidate performs section 6.2 Standard: Candidate performed section 6.2 Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.2 Performance Step: 9 Section 6.1, Startup Of CTMT Mini Purge Exhaust has been completed.

Standard: Candidate completed section 6.1.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.2.1 EXAMINER NOTE for the next step: TIME COMPRESSION CUE: When time goes past 5 minutes: "GT PDI-40 indicates less than 2 inches of water. Deleted: 2 DRAFT 6 of 11

Appendix C Page 7 of 11 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 10 When CTMT pressure is less than two inches water, then perform the following:

1. Open CTMT MINI PURGE SPLY/EXH DAMPERS. (D016 and D015)

• GT HIS OPEN

2. Open CTMT PURGE SYS AIR SPLY DAMPER. (D009)

• GT HIS OPEN

3. Open CTMT PURGE SYS AIR SPLY DAMPER. (D010)

• GT HIS OPEN

4. Open CTMT MINI PURGE AIR SPLY CTMT ISO.

• GT HIS OPEN

5. Recorded Time/Date Opened Standard: Candidate located controls on RL020 Panel.

Candidate performed the following actions at less than 2 INWC:

1. OPENED CTMT MINI PURGE SPLY/EXH DAMPERS.

(D016 and D015)

• GT HIS Depressed and held OPEN pushbutton until the Green light was EXTINGUISHED and the Red Light was LIT.

1. OPENED CTMT PURGE SYS AIR SPLY DAMPER.

(D009)

• GT HIS Depressed and held OPEN pushbutton until the Green light was EXTINGUISHED and the Red Light was LIT.

2. OPENED CTMT PURGE SYS AIR SPLY DAMPER.

(D010)

• GT HIS Depressed and held OPEN pushbutton until the Green light was EXTINGUISHED and the Red Light was LIT.)

3. OPENED CTMT MINI PURGE AIR SPLY CTMT ISO.

• GT HIS Depressed and held OPEN pushbutton until the Green light was EXTINGUISHED and the Red Light was LIT.

4. Record Time/Date Opened Cue: TIME COMPRESSION CUE: When time goes past 5 minutes:

"GT PDI-40 indicates less than 2 inches of water. Deleted: 2 Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.2.2 DRAFT 7 of 11

Appendix C Page 8 of 11 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 11 Start CTMT MINI PURGE AIR SPLY UNIT.

• GT HIS NORMAL-AFTER-RUN Standard: Candidate located control on RL020 Panel.

Candidate started CTMT MINI PURGE AIR SPLY UNIT.

• GT HIS J-handle manipulated to the RIGHT (RUN position) and released. Green Light EXTINGUISHED and Red Light LIT.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.2.3

• Performance Step: 12 Open CTMT MINI PURGE AIR SPLY CTMT ISO damper and record time/date opened.

• GT HIS OPEN

• Time/Date Opened Standard: Candidate located control on RL020 Panel.

Candidate opened CTMT MINI PURGE AIR SPLY CTMT ISO damper and recorded time/date opened.

• GT HIS Depressed and held OPEN pushbutton until the Green light was EXTINGUISHED and the Red Light was LIT.

• Recorded time and date opened Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.2.4 Performance Step: 13 Section 6.2, Startup Of CTMT Mini Purge Supply, complete Standard: Candidate has completed section 6.2.

Cue: When candidate has completed sections 6.1, Startup pf CTMT Mini Purge Exhaust and 6.2, Startup Of CTMT Mini Purge Supply, the JPM is complete.

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6.2.5 DRAFT 8 of 11

Appendix C Page 9 of 11 Form ES-C-1 PERFORMANCE INFORMATION Terminating Cue: When candidate has completed sections 6.1, Startup pf CTMT Mini Purge Exhaust and 6.2, Startup Of CTMT Mini Purge Supply, the JPM is complete.

DRAFT 9 of 11

Appendix C Page 10 of 11 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: S6 Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 10 of 11

Appendix C Page 11 of 11 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: You are the Reactor Operator. The plant is at ~44% and Xenon is approaching equilibrium. Containment pressure is at 27 INWC.

A Containment entry is planned for later in the shift. Outside temperature is 70°F.

A Gaseous Release Permit (GRP) for a Containment Purge has been issued by Chemistry. Prerequisites of SYS GT-120, CONTAINMENT MINI PURGE SYSTEM OPERATIONS are complete.

INITIATING CUE: The CRS directs you to perform SYS GT-120, CONTAINMENT MINI PURGE SYSTEM OPERATIONS sections 6.1 to depressurize the Containment and 6.2 to place Mini-Purge Supply into service.

DRAFT 11 of 11

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Bypass a failed Power Range JPM No.: S7 nuclear instrumentation channel K/A

Reference:

015 A4.03 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: x Classroom Simulator x Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: You are the Balance of Plant Operator. The plant is at ~44% power, Xenon is approaching equilibrium and Rod Control is in MANUAL.

Power Range instrument NI-43 has failed high.

The crew is performing the steps of OFN SB-008, Attachment R.

Attachment R has been performed up through and including step R3.

Task Standard: Upon completion of this JPM, the Operator will have placed failed Power Range NI-43 channel in bypass.

Required Materials: OFN SB-008, INSTRUMENT MALFUNCTIONS, ATTACHMENT R, POWER RANGE NEUTRON FLUX CHANNEL MALFUNCTION Simulator setup: IC 316 - Run concurrent with JPM S5.

Ensure Rod Control is in MANUAL. Place a FUB on NI43.

Verify bistable PR HI FLUX NC43U/K is illuminated, and alarms 078A and 083C are illuminated.

Built into IC 316 is file:

Fail NI-43 high IMF mSE03C f

120 General

References:

OFN SB-008, INSTRUMENT MALFUNCTIONS, ATTACHMENT R, POWER RANGE NEUTRON FLUX CHANNEL MALFUNCTION DRAFT 1 of 7

Appendix C Job Performance Measure Form ES-C-1 Worksheet Handouts: OFN SB-008, INSTRUMENT MALFUNCTIONS, ATTACHMENT R, POWER RANGE NEUTRON FLUX CHANNEL MALFUNCTION, step R4 Initiating Cue: The Control Room Supervisor directs you to perform step R4 to bypass the failed power range flux channel.

Time Critical Task:

(Yes or No) No Alternate Success Path: (Yes or No) No Validation Time: 10 minute DRAFT 2 of 7

Appendix C Page 3 of 7 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: 1 Candidate receives and reviews OFN SB-008, INSTRUMENT MALFUNCTIONS, ATTACHMENT R, POWER RANGE NEUTRON FLUX CHANNEL MALFUNCTION, step R4 Standard: Candidate received and reviewed OFN SB-008, INSTRUMENT MALFUNCTIONS, ATTACHMENT R, POWER RANGE NEUTRON FLUX CHANNEL MALFUNCTION, step R4 Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step R4 Performance Step: 2 Bypass Failed Power Range Flux Channel:

Standard: Candidate performed step R4a and R4b Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step R4 DRAFT 3 of 7

Appendix C Page 4 of 7 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 3 a. At the Detector Current Comparator Drawer (N50), perform the following

1. Turn the Upper Section switch to the failed power range flux channel.

2. Turn the Lower Section switch to the failed power range flux channel.

3. Turn the Power Mismatch Bypass switch to the failed power range flux channel

4. Turn the Rod Stop Bypass switch to the failed power range flux channel.

Standard: Candidate located Detector Current Comparator Drawer (N50) in the back of the Control Room/Simulator.

Candidate performed the following:

1. Rotated Upper Section knob left to PRN 43. When Upper Section knob was rotated, the CHANNELS DEFEAT Light ILLUMINATED.

2. Rotated Lower Section knob left to PRN43. When Lower Section switch was rotated, the CHANNELS DEFEAT Light ILLUMINATED.

3. Rotated the right hand Power Mismatch Bypass knob left to PR N43.

4. Rotated right hand Rod Stop Bypass knob left to PR N43.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step R4a Note: When Rod Stop Bypass switch was rotated, N-43 BYP C-2 OVER-PWR ROD STOP (3 down 3 across) on Misc Bistable Panel SC066W, located on RL024 ILLUMINATED.

MCB alarms are affected when the last knob is turned.

DRAFT 4 of 7

Appendix C Page 5 of 7 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 4 b. At the Comparator and Rate Drawer (N37/N46), perform the following:

1. Turn the Comparator Channel Defeat switch to the failed power range channel.

Standard: Candidate located the Comparator and Rate Drawer (N37/N46) below the Detector Current Comparator Drawer (N50).

1. Candidate rotated Comparator Channel Defeat knob from NORMAL left to N43. When Comparator Channel Defeat switch was rotated, COMPARATOR DEFEAT light above knob ILLUMINATED.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step R4b Examiner NOTE: Main Control Board 078A, PR CHANNEL DEV, CLEARED.

Performance Step: 5 JPM complete.

Standard: Candidate informed Control Room Supervisor Power Range Channel N43 was bypassed. Step R4 was complete.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment:

Terminating Cue: The JPM is complete when the candidate is finished bypassing N43 at the Detector Current Comparator Drawer.

DRAFT 5 of 7

Appendix C Page 6 of 7 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: S7 Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 6 of 7

Appendix C Page 7 of 7 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: You are the Balance of Plant Operator. The plant is at ~44%

power, Xenon is approaching equilibrium and Rod Control is in MANUAL. Power Range instrument NI-43 has failed high.

The crew is performing the steps of OFN SB-008, Attachment R.

Attachment R has been performed up through and including step R3.

INITIATING CUE: The Control Room Supervisor directs you to perform step R4 to bypass the failed power range flux channel.

DRAFT 7 of 7

Appendix C Job Performance Measure Form ES-C-1 Worksheet Facility: Wolf Creek Task No.: N/A Task

Title:

Respond to a loss of a Component JPM No.: S8 Cooling Water pump using ALR 00-052A, CCW TO RCP FLOW LO K/A

Reference:

008 K3.03, A4.01, A2.01 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: x Classroom Simulator x Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: You are the Reactor Operator. The plant is in MODE 3 following a Safety Injection. The B CCW pump has tripped. D CCW pump is tagged out. Main Control Board alarm 052A, CCW TO RCP FLOW LO, has just annunciated.

Task Standard: Upon completion of this JPM, the candidate will have restored from a loss of CCW to the Service Loop.

Required Materials: ALR 00-052A , CCW TO RCP FLOW LO Simulator set up: IC 313. Run concurrent with JPM S4 Place CCW D pump in PTL and place a Test/Caution Tag on handswitch for CCW D.

Ensure EG HIS-58 is fully closed before going to FREEZE.

Ensure BB3 is on the NPIS display.

FREEZE, Go to Run upon Examiner cue.

NOTE: IC 313 includes:

ICM bkrDPEG01B t:1 ICR bkrDPEG01D t:2 Malfunction movEGHV0058 Fail Closed will require bypassing per RNO step 6.

General

References:

ALR 00-052A, CCW TO RCP FLOW LO DRAFT 1 of 13

Appendix C Job Performance Measure Form ES-C-1 Worksheet Handouts: ALR 00-052A, CCW TO RCP FLOW LO Initiating Cue: The Control Room Supervisor directs you to perform ALR 00-052A, CCW TO RCP FLOW LO.

Time Critical Task:

(Yes or No) No Alternate Success Path: (Yes or No) Yes Validation Time: 12 minutes DRAFT 2 of 13

Appendix C Page 3 of 13 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: 1 Candidate receives and reviews ALR 00-052A, CCW TO RCP FLOW LO.

Standard: Candidate received and reviewed ALR 00-052A, CCW TO RCP FLOW LO.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment:

Performance Step: 2 Check CCW To RCS Flow - LESS THAN 1.25 X106 LBM/HR

• EG FI-128

• EG FI-129 Standard: Candidate located EG FI-128 and EG FI-129 on RL020 Panel.

Candidate determined that flow is zero.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 1 Performance Step: 3 Check If CCW Flow To RCS Required:

RCS Temperature - GREATER THAN 200°F or Any Reactor Coolant Pump - RUNNING Standard: Candidate determined both conditions are met and that CCW flow is required.

RCS temperature: Candidate may use H/C LEGS WR TEMP meters on RL022 Panel or NPIS Display 1 on RL022 Panel Candidate checked indication located on RL021 Panel, RCPs RUNNING; Handswitch - Red Light LIT; amp meters; GREEN BAND and RL022 Panel flow indicators; 3 per loop Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 2 Candidate may use NPIS BB3 to monitor RCP parameters at this time. Temperatures will be increasing.

DRAFT 3 of 13

Appendix C Page 4 of 13 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 4 Check Containment Isolation Phase B - NOT ACTUATED Standard: Candidate checked Main Control Board alarm 059B, CISB, alarm NOT ILLUMINATED and/or ESFAS status panels SA066Y or SA066X, CTMT ISO SYS PHASE B sections, NOT ILLUMINATED, to check CISB not actuated.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 3 Candidate may verify CTMT pressure using meter on RL018 Panel (GN PR-934, CTMT ATMS PRESS)

Performance Step: 5 Monitor RCP Motor Temperatures Using NPIS Computer:

a. Check RCP Motor Bearing Temperatures - LESS THAN 195°F

• Turn On Code BB3

b. Check RCP Motor Stator Winding Temperatures - LESS THAN 299°F

• Turn On Code BB3 Standard: Candidate used NPIS computer to display Turn On Code BB3.

Candidate checked:

a. RCP Motor Bearing Temperatures - LESS THAN 195°F; NO, Perform RNO (see next page)

b. RCP Motor Stator Winding Temperatures - LESS THAN 299°F; Yes, and increasing Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 4 Examiner NOTE: BB3 will indicate RCP motor bearing temperatures greater than 195°F.

DRAFT 4 of 13

Appendix C Page 5 of 13 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 6 Candidate performs Step 4 RNOa

a. Perform the following:

1) If reactor is critical, then manually trip reactor and stabilize the plant using EMGs, while continuing with this procedure.

2) Stop all RCPs Standard: Candidate

a. Performed the following:

1) Determined reactor is not critical.

2) Stopped all RCPs:

• Manipulating J-handle on BB HIS-37, RCP A, to the left (STOP) and observed Red Light EXTINGUISH and Green Light LIT.

• Manipulating J-handle on BB HIS-38, RCP B, to the left (STOP) and observed Red Light EXTINGUISH and Green Light LIT.

• Manipulating J-handle on BB HIS-39, RCP C, to the left (STOP) and observed Red Light EXTINGUISH and Green Light LIT.

• Manipulating J-handle on BB HIS-40, RCP D, to the left (STOP) and observed Red Light EXTINGUISH and Green Light LIT.

Cue: Cue if CRS informed: Understand stopping RCPs.

Score: SAT or UNSAT SAT or UNSAT Comment: Step 4RNOa Examiner NOTE: Candidate should inform CRS of securing the RCPs. Candidate should make a plant announcement prior to securing the RCPs. Candidate should use diverse indications of decreasing AMPs, and decreasing LOOP FLOW to verify pump is stopped.

DRAFT 5 of 13

Appendix C Page 6 of 13 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 7 Check CCW Pumps In Train Supplying Service Loop - BOTH RUNNING Standard: Candidate located CCW Pumps on RL019 Panel.

Candidate checked CCW B tripped.

Candidate found CCW D in PTL and tagged out.

Candidate transitioned to RNO column: Perform the following:

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 5 Performance Step: 8 Step 5RNO: Perform the following:

a. Start standby CCW Pump in train supplying service loop.

Standard: Candidate determined CCW D Pump is unavailable.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 5RNOa DRAFT 6 of 13

Appendix C Page 7 of 13 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 9 IF a CCW Pump in train aligned to the service loop can NOT be started, THEN ensure alternate train CCW Pump is operating and shift service loop to alternate CCW train:

1. Open service loop CCW supply and return valves for train not supplying service loop.

EG ZL-15 AND EG ZL-53 For Train A

• EG HS-15 EG ZL-16 AND EG ZL-54 For Train B

• EG HS-16

2. Close service loop CCW supply and return valves for train previously supplying service loop.

EG ZL-15 AND EG ZL-53 For Train A

• EG HI-15 EG ZL-16 AND EG ZL-54 For Train B

• EG HS-16 Standard: Candidate located CCW Pump A (or C) on RL019 Panel.

Candidate checked one CCW pump running:

EG HIS-21 for CCW A pump - Red Light LIT; YES

- OR -

EG HIS-23 for CCW C pump - Red Light LIT Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 5RNOb Examiner NOTE: Separated out candidate actions. One pump is already running in the Red train (CCW A pump in RUNNING).

DRAFT 7 of 13

Appendix C Page 8 of 13 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 10 IF a CCW Pump in train aligned to the service loop can NOT be started, THEN ensure alternate train CCW Pump is operating and shift service loop to alternate CCW train:

1. Open service loop CCW supply and return valves for train not supplying service loop.

EG ZL-15 AND EG ZL-53 For Train A

• EG HS-15 EG ZL-16 AND EG ZL-54 For Train B

• EG HS-16

2. Close service loop CCW supply and return valves for train previously supplying service loop.

EG ZL-15 AND EG ZL-53 For Train A

• EG HI-15 EG ZL-16 AND EG ZL-54 For Train B

• EG HS-16 Standard: Candidate located EG HS-15 (pushbutton) on RL019 Panel.

1. Candidate depressed OPEN pushbutton: Green Lights LIT and Red Lights LIT then Green Lights EXTINGUISHED (EG ZL-15 AND EG ZL-53 Train A)

Candidate located EG HS-16 (pushbutton) on RL019 Panel.

2. Candidate depressed CLOSE pushbutton: Red Lights LIT and Green Lights LIT then Red Lights EXTINGUISHED. (EG ZL-16 AND EG ZL-54)

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Examiner NOTE: Annunciator 51F CCW SPLY RTN VLVS MISALIGN alarm is expected after EG HS-15 is pushed.

Examiner NOTE: Annunciator 51F CCW SPLY RTN VLVS MISALIGN alarm should clear when EG ZL16 and EG ZL-54 are GREEN Step 5RNOb continued DRAFT 8 of 13

Appendix C Page 9 of 13 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 11 Ensure CCW Containment Isolation Valves - OPEN

• CCW From RCS Outer Containment Isolation Valve -

OPEN

• EG HIS-59

• CCW From RCS Inner Containment Isolation Valve -

OPEN

• EG HIS-60

• CCW To RCS Outer Containment Isolation Valve -

OPEN

• EG HIS (discovered CLOSED)

• EG HIS-71 Standard: Candidate located valves on RL019 Panel.

Candidate performed the following:

• Checked EG HIS OPEN: Red Light LIT

• Checked EG HIS OPEN: Red Light LIT

• Checked EG HIS OPEN: NO Green Light LIT Candidate depressed OPEN pushbutton on EG HIS-58

• Checked EG HIS OPEN: Red Light LIT Candidate transitioned to Step 6 RNO Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6 Examiner NOTE: The OPEN pushbutton for EG HIS-58 will not work.

DRAFT 9 of 13

Appendix C Page 10 of 13 Form ES-C-1 PERFORMANCE INFORMATION

• Performance Step: 12 If any valve can NOT be opened, THEN perform the following:

a. Verify unaffected bypass valves are closed.

• EG HIS-127 For EG HIS-58

• EG HIS-131 For EG HIS-59

• EG HIS-130 For EG HIS-60

• EG HIS-126 For EG HIS-71

b. Open associated bypass valve.

• EG HIS-127 For EG HIS-58

• EG HIS-131 For EG HIS-59

• EG HIS-130 For EG HIS-60

• EG HIS-126 For EG HIS-71

c. Refer to Tech. Spec 3.6.3 Standard: Candidate located valves on RL020 Panel.

a. Candidate checked unaffected bypass valves were closed:

• EG HIS-131 - CLOSED: Green Light LIT

• EG HIS-130 - CLOSED: Green Light LIT

• EG HIS-126 - CLOSED: Green Light LIT

b. Candidate opened YELLOW TRAIN bypass valve:

• EG HIS-127A - Depressed NON-ISO, White Light LIT and button latched down

• EG HIS-127 - OPEN: Depressed the OPEN pushbutton. Red Light LIT and Green Light EXTINGUISHED Cue: If notified that dedicated Operator is required Acknowledge Request.

If notified about T.S. 3.6.3 entry: CRS will refer to Tech Specs.

Score: SAT or UNSAT SAT or UNSAT Comment: Step 6RNO Examiner NOTE: Candidate may depress the ISO pushbutton to release the Non-Iso latch after EG HV-127 is OPEN. This is action not required for this JPM.

DRAFT 10 of 13

Appendix C Page 11 of 13 Form ES-C-1 PERFORMANCE INFORMATION Performance Step: 13 Check CCW To RCS Flow - GREATER THAN 1.25 x 106 LBM/HR

• EG FI-128

• EG FI-129 Standard: Candidate located gauges on RL020 Panel. Candidate checked flow MET.

Cue: JPM complete when candidate verified flow requirement MET.

Score: SAT or UNSAT SAT or UNSAT Comment: Step 7 Performance Step: 14 Return to Procedure And Step in Effect Standard: Candidate recognized JPM completed.

Cue:

Score: SAT or UNSAT SAT or UNSAT Comment: Step 8 Terminating Cue: JPM complete when candidate verified CCW to RCS flow requirement met.

DRAFT 11 of 13

Appendix C Page 12 of 13 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: S8 Examinees Name:

Examiners Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

DRAFT 12 of 13

Appendix C Page 13 of 13 Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS: You are the Reactor Operator. The plant is in MODE 3 following a Safety Injection. The B CCW pump has tripped. D CCW pump is tagged out. Main Control Board alarm 052A, CCW TO RCP FLOW LO, has just annunciated.

INITIATING CUE: The Control Room Supervisor directs you to perform ALR 00-052A, CCW TO RCP FLOW LO.

DRAFT 13 of 13