Text

2012-10-FINAL OP Test
	ML13003A238
Person / Time
Site:	Waterford
Issue date:	10/01/2013
From:	Brian Larson; Operations Branch IV
To:	; Entergy Operations
	laura hurley
References
	Download: ML13003A238 (249)
	v • d • e

ES-301 Administrative Topics Outline Form ES-301-1 Facility: Waterford 3 Date of Examination: 10/01/2012 Examination Level: RO SRO Operating Test Number: 1 Administrative Topic Type Describe activity to be performed (see Note) Code*

A1 R,D,P 2.1.25, Ability to interpret reference materials, such as graphs, curves, tables, etc.

Conduct of Operations Complete a Shutdown Margin with an immoveable CEA in accordance with OP-903-090, Shutdown Margin, section K/A Importance: 3.9 7.3, Shutdown Margin Verification - Untrippable CEA.

A2 R,N 2.1.23, Ability to perform specific system and integrated plant procedures during all modes of plant operation.

Conduct of Operations Complete a calculation for determining the amount of pure water that may be added to the Refuel Cavity without K/A Importance: 4.3 dilution to below shutdown margin requirements in accordance with OP-010-006, Outage Operations, section 9.24, Refueling Cavity Boron Concentration.

A3 R,D 2.2.12, Knowledge of surveillance procedures.

Equipment Control Determine Acceptability of Containment Temperature In accordance With OP-903-001, Technical Specification Surveillance Logs, Attachments 11.1 and 11.20.

K/A Importance: 3.7 A4 R,D 2.3.11, Ability to control radiation releases.

Radiation Control Evaluate Meteorological conditions for gaseous release from the Gaseous Waste Management System in accordance with OP-007-003, Gaseous Waste K/A Importance: 3.8 Management Emergency Plan Not selected NOTE: All items (5 total are required for SROs. RO applicants require only 4 items unless they are retaking only the administrative topics, when 5 are required.

Type Codes & Criteria: (C)ontrol room, (S)imulator, or Class(R)oom (D)irect from bank ( 3 for ROs; 4 for SROs & RO retakes)

(N)ew or (M)odified from bank ( 1)

(P)revious 2 exams ( 1; randomly selected) 2012 NRC Revision 1

ES-301 Administrative Topics Outline Form ES-301-1 Facility: Waterford 3 Date of Examination: 10/01/2012 Examination Level: RO SRO Operating Test Number: 1 Administrative Topic Type Describe activity to be performed (see Note) Code*

A5 R,D,P 2.1.25, Ability to interpret reference materials, such as graphs, curves, tables, etc.

Conduct of Operations Review and approve a completed Shutdown Margin with an immovable CEA in accordance with OP-903-090, Shutdown K/A Importance: 4.2 Margin, section 7.3, Shutdown Margin Verification -

Untrippable CEA.

A6 R,N 2.1.23, Ability to perform specific system and integrated plant procedures during all modes of plant operation.

Conduct of Operations Review a completed calculation for determining the amount of pure water that may be added to the Refuel Cavity K/A Importance: 4.4 without dilution to below shutdown margin requirements in accordance with OP-010-006, Outage Operations, section 9.24, Refueling Cavity Boron Concentration.

A7 R,D 2.2.12, Knowledge of surveillance procedures Equipment Control Review a completed Containment Pressure calculation in accordance With OP-903-001, Technical Specification K/A Importance: 4.1 Surveillance Logs, Attachment 11.15, Containment Pressure Calculation.

A8 R,D 2.3.4, Knowledge of radiation exposure limits under normal or emergency conditions.

Radiation Control Authorize Emergency Exposure as the Emergency Director in accordance with EP-002-030, Emergency Radiation K/A Importance: 3.7 Exposure Guidelines and Controls.

A9 R,D 2.4.44, Knowledge of emergency plan protective action recommendations.

Emergency Plan Determine protective action recommendations in accordance with EP-002-052, Protective Action Guidelines.

K/A Importance: 4.4 NOTE: All items (5 total are required for SROs. RO applicants require only 4 items unless they are retaking only the administrative topics, when 5 are required.

Type Codes & Criteria: (C)ontrol room, (S)imulator, or Class(R)oom (D)irect from bank ( 3 for ROs; 4 for SROs & RO retakes)

(N)ew or (M)odified from bank ( 1)

(P)revious 2 exams ( 1; randomly selected) 2012 NRC Revision 0

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE A1 Calculate Shutdown Margin with a Stuck CEA Applicant:

Examiner:

JPM A1 JOB PERFORMANCE MEASURE DATA PAGE Task: Calculate Shutdown Margin with a stuck CEA.

Task Standard: Applicant calculated Shutdown Margin in accordance with OP-903-090, Shutdown Margin. The results conformed to the answer key and concluded that reactor power is greater than the Shutdown Margin allowed power level.

References:

OP-903-090, Shutdown Margin, revision 303 Plant Data Book, volume 1 COLR History: This JPM last used in the 2011 NRC RO exam.

Time Critical: No Validation Time: 15 mins.

K/A 2.1.25, Ability to interpret reference Importance Rating 3.9 materials, such as graphs, curves, RO tables, etc.

Applicant:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 7 2012 NRC Exam

JPM A1 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-903-090, Shutdown Margin, revision 303 Plant Data Book, volume 1 COLR

==

Description:==

The applicant will be required to calculate Shutdown Margin with 1 mechanically bound CEA. The results will indicate that Shutdown Margin is NOT met and Emergency Boration is required.

READ TO APPLICANT DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

INITIAL CONDITIONS:

Core burnup is 335 EFPD

TCOLD is 543.5 °F

Power is 35%

Power is being held due to a Chemistry hold

Regulating Group P CEAs are being used for ASI control as xenon builds in

CEA 24 failed to withdraw or insert on the last move

I&C has completed troubleshooting and there are no problems associated with CEDMCS

The Shift Manager has concluded that CEA 24 is mechanically bound INITIATING CUE:

The CRS directs you to perform OP-903-090, Shutdown Margin, section 7.3.

Revision 1 Page 3 of 7 2012 NRC Exam

JPM A1 7.3.1 If an Untrippable CEA Condition exists and the other CEAs are not inserted, then determine Shutdown Margin and record on Attachment 10.3 as follows:

TASK ELEMENT 1 STANDARD NOTE (1) Use 541°F when using PDB Figure 1.5.7.

(2) When using graphs and tables in the Plant Data Book (PDB), to Note reviewed.

obtain the necessary data, it may be necessary and is acceptable to interpolate (approximate between data points or curves). However, extrapolation (approximation outside of the bounds of the data or curves) should not be used.

Comment:

Use Figure 1.5.7.3 for MOC.

MOC can be determined by reviewing the Precautions and Limitations in SAT / UNSAT OP-903-090, Shutdown Margin.

TASK ELEMENT 2 STANDARD 7.3.1.1 Using current Cycle Burnup and 541 °F temperature, determine 5.3 - 5.4 Net Worth Worst Pair Stuck out (WPSO) from Figure 1.5.7.

Comment: Critical Refer to A1 Key.

Use Figure 1.5.7.3 for MOC. SAT / UNSAT TASK ELEMENT 3 STANDARD 7.3.1.2 Determine Shutdown Margin required by COLR. 5.15 Comment: Critical Refer to A1 Key. COLR 3.1.1.1 used to obtain required SDM.

SAT / UNSAT TASK ELEMENT 4 STANDARD 7.3.1.3 Subtract Step 7.3.1.2 from Step 7.3.1.1 to determine Shutdown 0.15 - 0.25 Margin Allowed Power Defect %K/K.

Comment: Critical Refer to A1 Key. Step 7.3.1.1 (5.351) - step 7.3.1.2 (5.15)

SAT / UNSAT Revision 1 Page 4 of 7 2012 NRC Exam

JPM A1 TASK ELEMENT 5 STANDARD 7.3.1.4 Record current Reactor Power on Attachment 10.3. 35% recorded.

Comment:

SAT / UNSAT TASK ELEMENT 6 STANDARD 7.3.1.5 Using result from step 7.3.1.3 and Power Defect vs. Power Level, 10% - 18%

Figure 1.2.1, Determine Shutdown Margin Allowed Power Level.

Comment: Critical Refer to A1 Key.

SAT / UNSAT TASK ELEMENT 7 STANDARD 7.3.1.6 Verify Shutdown Margin greater than or equal to that required by Shutdown Margin is not the COLR by verifying that current power level is less than or equal to the met.

Shutdown Margin Allowed Power Level.

Comment: Critical Refer to A1 Key.

SAT / UNSAT TASK ELEMENT 8 STANDARD 7.3.2 If Shutdown Margin does not meet the requirements of Technical Applicant identified that Specifications, then Commence Emergency Boration and go to OP-901- Emergency Boration is 103, Emergency Boration. required.

Comment:

SAT / UNSAT END OF TASK Revision 1 Page 5 of 7 2012 NRC Exam

JPM A1 SIMULATOR OPERATOR INSTRUCTIONS There is no Simulator setup for this JPM Revision 1 Page 6 of 7 2012 NRC Exam

JPM A1 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

Do not use Simulator data for this JPM INITIAL CONDITIONS:

Core burnup is 335 EFPD

TCOLD is 543.5 °F

Power is 35%

Power is being held due to a Chemistry hold

Regulating Group P CEAs are being used for ASI control as xenon builds in

CEA 24 failed to withdraw or insert on the last move

I&C has completed troubleshooting and there are no problems associated with CEDMCS

The Shift Manager has concluded that CEA 24 is mechanically bound INITIATING CUE:

The CRS directs you to perform OP-903-090, Shutdown Margin, section 7.3.

Revision 1 Page 7 of 7 2012 NRC Exam

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE A2 Calculation For Determining The Amount Of Pure Water That May Be Added To The Refuel Cavity Applicant:

Examiner:

JPM A2 JOB PERFORMANCE MEASURE DATA PAGE Task: Calculate pure water addition to the Refuel Cavity.

Task Standard: Applicant calculated the amount of pure water that can be added to the refuel cavity through step 9.24.3, in accordance with OP-010-006, Outage Operations. The result conformed to the answer key.

References:

OP-010-006, Outage Operations, revision 320 TS 3.9.1 COLR Time Critical: No Validation Time: 20 mins.

K/A 2.1.23 Ability to perform specific system Importance Rating 4.3 and integrated plant procedures during RO all modes of plant operation.

Applicant:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 7 2012 NRC Exam

JPM A2 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-010-006, Outage Operations, revision 320 COLR TS 3.9.1

==

Description:==

The applicant will be required to calculate the amount of pure water that can be added to the refuel cavity in accordance with OP-010-006, Outage Operations. To perform this calculation the applicant will need to determine what the Refueling Minimum Boron Concentration is from Tech Specs. The results will indicate that 1413 gallons of PMU may be added to the refuel cavity.

READ TO APPLICANT DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

INITIAL CONDITIONS:

Waterford 3 is in a refueling outage

Reactor Engineering has determined that a boron concentration of 1985 ppm is required to maintain the Refuel Cavity at a Keff of < .95

Refuel Cavity Water Level is 24 ft. and will be drained to 22 ft. MSL

Refuel Cavity boron concentration is 2090 ppm INITIATING CUES:

RP has requested that the refuel cavity walls be washed down with CMU as level in the refueling cavity is lowered to 22 ft The CRS directs you to determine refueling minimum boron concentration per TS 3.9.1 and perform OP-010-006, Attachment 9.24 Refueling Cavity Boron concentration Revision 1 Page 3 of 7 2012 NRC Exam

JPM A2 TASK ELEMENT 1 STANDARD Note:

(1) This attachment provides guidance for calculating the amount of pure water that may be added to the Refuel Cavity without dilution to below shutdown margin requirements. This is typically used while Radiation Protection is using CMU to wash down the Refuel Cavity walls to mitigate airborne radioactivity while Note reviewed.

performing Refuel Cavity drain down.

(2) This calculation is only valid for water additions while the Refuel Cavity Water Level is > 20 MSL.

(3) This calculation includes a 50% margin.

SAT / UNSAT 9.24.1 Record the following:

TASK ELEMENT 2 STANDARD Final Refuel Cavity Water Level (Lf): 22 ft. MSL Comment:

Refer to A2 Key.

SAT / UNSAT TASK ELEMENT 3 STANDARD Initial Refuel Cavity Boron Concentration (Ci) 2090 ppm Comment:

Refer to A2 Key.

SAT / UNSAT TASK ELEMENT 4 STANDARD Refueling Minimum Boron Concentration (Cf) 2050 ppm Comment: Critical Refer to A2 Key.

The applicant will determine that 2050 ppm is the most restrictive SAT / UNSAT requirement per TS 3.9.1 and COLR 3.9.1.

Revision 1 Page 4 of 7 2012 NRC Exam

JPM A2 TASK ELEMENT 5 STANDARD 9.24.2 Calculate the amount of pure water that may be added to the Refuel Cavity (Vw) using the following formula:

Vw = (6954 gal/ft x Lf - 79,161 gal) x (1- Cf/Ci) 1402 to 1476 gallons Vw = [( 6954x___ ft) - 79,161]x [1-(___ppm/___ppm)]

Vw=____gallons Comment: Critical 73827 x .019139 = 1413 gallons SAT / UNSAT TASK ELEMENT 6 STANDARD 9.24.3 Select the lower of Vw calculated in Step 9.24.2 or 1500 gallons: 1402 to 1476 gallons Comment: Critical Refer to A1 Key.

SAT / UNSAT END OF TASK Revision 1 Page 5 of 7 2012 NRC Exam

JPM A2 SIMULATOR OPERATOR INSTRUCTIONS There is no Simulator setup for this JPM Revision 1 Page 6 of 7 2012 NRC Exam

JPM A2 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

Do not use Simulator data for this JPM INITIAL CONDITIONS:

Waterford 3 is in a refueling outage

Reactor Engineering has determined that a boron concentration of 1985 ppm is required to maintain the Refuel Cavity at a Keff of < .95

Refuel Cavity Water Level is 24 ft. and will be drained to 22 ft. MSL

Refuel Cavity boron concentration is 2090 ppm INITIATING CUES:

RP has requested that the refuel cavity walls be washed down with PMU as level in the refueling cavity is lowered to 22 ft The CRS directs you to determine refueling minimum boron concentration per TS 3.9.1 and perform OP-010-006, Attachment 9.24 Refueling Cavity Boron concentration Revision 1 Page 7 of 7 2012 NRC Exam

Waterford 3 2012 RO NRC Exam JOB PERFORMANCE MEASURE A3 Determine Acceptability of Containment Temperature In Accordance With OP-903-001 Applicant:

Examiner:

JPM A3 JOB PERFORMANCE MEASURE DATA PAGE Task: Determine Acceptability of Containment Temperature In Accordance With OP-903-001 Task Standard: Determined Containment Average Temperature does not meet acceptance criteria with instrument error accounted for and Tech Spec 3.6.1.5 entry is required.

References:

OP-903-001, revision 49 TS 3.6.1.5 TS Bases 3/4.6 Validation Time: 20 minutes Time Critical: No K/A 2.2.12, Knowledge of surveillance Importance Rating 3.7 procedures. RO Applicant:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 6 2012 RO NRC Exam

JPM A3 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-903-001, Attachment 11.1 MODES 1-4 Technical Specification Surveillance Logs, revision 49

OP-903-001, Attachment 11.20 MODES 1-4 PMC Technical Specification Surveillance Logs (page 149), revision 49

Waterford 3 Technical Specifications

==

Description:==

This JPM requires the candidate to use Containment temperature readings from the PMC (provided on the cue sheet), calculate the average temperature using 3 of the 4 readings, and determine compliance with TS 3.6.1.5 and OP-903-001. Based on the readings of the 3 running CFC intake temperatures and tighter acceptance criteria of OP-903-001 (based on instrument error) TS 3.6.1.5 ACTION a must be complied with.

READ TO APPLICANT DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

Provide all answers on the material provided.

INITIAL CONDITIONS:

Reactor power is at 100%

I & C has just completed calibration of CFC Air Intake temperature loops

Containment Fan Coolers A, C, and D are operating

Primary Containment Average Air temperatures are as follows:

PID A51115, CFC A Air Inlet Temp reads 97°F PID A51119, CFC B Air Inlet Temp reads 100°F PID A51123, CFC C Air Inlet Temp reads 101°F PID A51127, CFC D Air Inlet Temp reads 98°F INITIATING CUES:

The CRS directs you to determine compliance of Containment Average Temperature per OP-903-001.

Document results and actions required, if any, on OP-903-001, Attachment 11.20.

Revision 1 Page 3 of 6 2012 RO NRC Exam

JPM A3 Evaluator Note The candidate will determine Containment Average Temperature using Containment Fan Cooler inlet temperatures from the PMC, Containment Fan Coolers running, and reactor power (all provided on the cue sheet)

TASK ELEMENT 1 STANDARD Determines Containment Average Temperature 98.3°F -99.7°F Comment: Critical

1. The applicant will use the provided CFC temperatures and average the 3 running CFC temperatures (A, C and D). The SAT / UNSAT average will be 98.7°F.

Note: Averaging the 3 running CFC temperatures is preferred but not required. Any 3 can be used. The range given covers the various combinations that can be averaged.

TASK ELEMENT 2 STANDARD Determined that Determines Average Containment Temperature does NOT meet acceptance criteria is not Acceptance Criteria. met and TS 3.6.1.5 entry is required.

Comment: Critical If the candidate just compares the temperature to the 3.6.1.5 LCO they will determine that no action is required and acceptance criteria is met. SAT / UNSAT However, Tech Spec 3.6.1.5 does not take into account instrument uncertainties. and notes 2.0 - 2.3 of OP-903-001, Attachment 11.1 should be reviewed to determine acceptability of Containment Temperature.

END OF TASK Revision 1 Page 4 of 6 2012 RO NRC Exam

JPM A3 SIMULATOR OPERATOR INSTRUCTIONS None.

Revision 1 Page 5 of 6 2012 RO NRC Exam

JPM A3 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

Reactor power is at 100%

I & C has just completed calibration of CFC Air Intake temperature loops

Containment Fan Coolers A, C, and D are operating

Primary Containment Average Air temperatures are as follows:

PID A51115, CFC A Air Inlet Temp reads 97°F PID A51119, CFC B Air Inlet Temp reads 100°F PID A51123, CFC C Air Inlet Temp reads 101°F PID A51127, CFC D Air Inlet Temp reads 98°F INITIATING CUES:

The CRS directs you to determine compliance of Containment Average Temperature per OP-903-001.

Document results and actions required, if any, on OP-903-001, Attachment 11.20.

Revision 1 Page 6 of 6 2012 RO NRC Exam

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE A4 Gaseous Release Evaluation Applicant:

Examiner:

JPM A4 JOB PERFORMANCE MEASURE DATA PAGE Task: Meteorological conditions are evaluated for gaseous release from the GWM System.

Task Standard: Applicant concluded that a release is permitted. The conclusion included the correct evaluation of wind speed, wind direction, and stability class.

References:

OP-007-003, Gaseous Waste Management, revision 302 Time Critical: No Validation Time: 10 mins.

K/A 2.3.11 Ability to control radiation releases Importance Rating 3.8 Applicant:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 5 2012 NRC Exam

JPM A4 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

Attachment 11.5 of OP-007-003, Gaseous Waste Management, revision 302 METDATA

==

Description:==

The setting will be in the classroom for this JPM. The applicant will be provided information from the PMC for the applicable meteorological conditions. The data will be used to evaluate the flow chart in OP-007-003, Attachment 11.5.

READ TO APPLICANT DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from this JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

INITIAL CONDITIONS:

The plant is in Mode 1

Chemistry has requested a release of all 3 Gas Decay Tanks for planned maintenance

Environmental conditions are as displayed on the METDATA handout INITIATING CUES:

The CRS directs you to complete an evaluation of meteorological conditions for the release in accordance with OP-007-003, Gaseous Waste Management

Document all information used and conclusions on OP-007-003, Attachment 11.5 Revision 1 Page 3 of 5 2012 NRC Exam

JPM A4 TASK ELEMENT 1 STANDARD Concluded wind speed is 2.68 (primary met tower)or Evaluate 10 meter (33 foot) wind speed.

2.75 (backup met tower) m/s.

Comment: Critical Note 2 on attachment 11.5 directs the use of 33 foot parameters.

Note 1 on attachment 11.5 directs all parameters to be obtained from 15 SAT / UNSAT minute average values.

The 199 foot reading (3.62 m/s) will conclude that there are no restrictions on the release without using the rest of the flowchart TASK ELEMENT 2 STANDARD Concluded wind direction is 331.1(or 330.7 from the Evaluate 10 meter (33 foot) wind direction. B/U met tower) deg and continued right through the flow chart.

Comment: Critical The 199 foot reading (314.5 deg) will also continue right through the flow chart. The procedure directs using the 33 foot parameters. SAT / UNSAT TASK ELEMENT 3 STANDARD Concluded T is -0.77 °C or -0.78 °C, stability class C, and that the release is Evaluate Pasquill Stability Class. permitted. If using the B/U met tower, T is -0.93 °C, stability class B, and that the release is permitted.

Comment: Critical Note 3 on attachment 11.5 directs the T/50m to be obtained from the primary or backup tower 199-33 Delta T reading. SAT / UNSAT END OF TASK Revision 1 Page 4 of 5 2012 NRC Exam

JPM A4 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The plant is in Mode 1

Chemistry has requested a release of all 3 Gas Decay Tanks for planned maintenance

Environmental conditions are as displayed on the METDATA handout INITIATING CUES:

The CRS directs you to complete an evaluation of meteorological conditions for the release in accordance with OP-007-003, Gaseous Waste Management

Document all information used and conclusions on OP-007-003, Attachment 11.5 Revision 1 Page 5 of 5 2012 NRC Exam

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE A5 Review and Approve a Shutdown Margin with a Stuck CEA Applicant:

Examiner:

JPM A5 JOB PERFORMANCE MEASURE DATA PAGE Task: Review and Approve a Shutdown Margin with a stuck CEA.

Task Standard: Applicant reviewed the completed Shutdown Margin and identified that the incorrect Shutdown Margin required value was used and corrected applicable data in the attachment in accordance with the key. The applicant identified that the plant is operating above the allowed power level of 14% and Emergency Boration is required.

References:

OP-903-090, Shutdown Margin, revision 303 Plant Data Book, volume 1 COLR Time Critical: No Validation Time: 20 mins.

K/A 2.1.25, Ability to interpret reference Importance Rating 4.2 materials, such as graphs, curves, SRO tables, etc.

Applicant:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 7 2012 NRC Exam

JPM A5 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-903-090, Shutdown Margin, revision 303 Plant Data Book, volume 1 COLR

==

Description:==

The applicant will be required to review a completed Shutdown Margin with 1 mechanically bound CEA. The review will indicate that Shutdown Margin is not met and Emergency Boration is required.

READ TO APPLICANT DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

INITIAL CONDITIONS:

Core burnup is 335 EFPD

TCOLD is 543.5 °F

Power is 35%

Power is being held due to a Chemistry hold

Regulating Group P CEAs are being withdrawn for ASI control as xenon builds in

CEA 24 failed to withdraw or insert on the last move

I&C has completed troubleshooting and there are no problems associated with CEDMCS

The Shift Manager has concluded that CEA 24 is mechanically bound INITIATING CUES:

The STA has provided you with a completed OP-903-090, Shutdown Margin, for review.

Review and approve the completed surveillance or correct any errors and document any actions required on the worksheet given.

Revision 1 Page 3 of 7 2012 NRC Exam

JPM A5 7.3.1 If an Untrippable CEA Condition exists and the other CEAs are not inserted, then determine Shutdown Margin and record on Attachment 10.3 as follows:

TASK ELEMENT 1 STANDARD CAUTION Caution reviewed.

The following section has the potential to affect core reactivity.

Comment:

SAT / UNSAT TASK ELEMENT 2 STANDARD NOTE (1) Use 541°F when using PDB Figure 1.5.7.

(2) When using graphs and tables in the Plant Data Book (PDB), to Note reviewed.

obtain the necessary data, it may be necessary and is acceptable to interpolate (approximate between data points or curves). However, extrapolation (approximation outside of the bounds of the data or curves) should not be used.

Comment:

Use Figure 1.5.7.3 due to MOC. The plant is at MOC based on EFPD.

The EFPD to MOC correlation is described in the precautions and SAT / UNSAT limitations section of OP-903-090, Shutdown Margin.

TASK ELEMENT 3 STANDARD 7.3.1.1 Using current Cycle Burnup and 541 °F temperature, determine Recorded correctly on Net Worth Worst Pair Stuck out (WPSO) from Figure 1.5.7. surveillance.

Comment:

Use Figure 1.5.7.3 due to MOC.

SAT / UNSAT TASK ELEMENT 4 STANDARD 7.3.1.2 Determine Shutdown Margin required by COLR. 5.15 Comment: Critical Surveillance lists 4.6, the COLR Shutdown Margin for > 500 F with CEAs inserted. SAT / UNSAT Revision 1 Page 4 of 7 2012 NRC Exam

JPM A5 TASK ELEMENT 5 STANDARD 7.3.1.3 Subtract Step 7.3.1.2 from Step 7.3.1.1 to determine Shutdown 0.15 - 0.25 Margin Allowed Power Defect %K/K.

Comment: Critical Surveillance lists .751 because of previous error.

SAT / UNSAT TASK ELEMENT 6 STANDARD 7.3.1.5 Using result from step 7.3.1.3 and Power Defect vs. Power Level, 10% - 18%

Figure 1.2.1, Determine Shutdown Margin Allowed Power Level.

Comment: Critical Surveillance lists 58%.

SAT / UNSAT TASK ELEMENT 7 STANDARD 7.3.1.6 Verify Shutdown Margin greater than or equal to that required by Shutdown Margin is not the COLR by verifying that current power level is less than or equal to the met.

Shutdown Margin Allowed Power Level.

Comment: Critical Surveillance lists 58% allowed, which is greater than the current power level. Applicant must recognize that the actual limit is 10% - 18% which SAT / UNSAT is below the current power level.

TASK ELEMENT 8 STANDARD 7.3.2 If Shutdown Margin does not meet the requirements of Technical Specifications, then Commence Emergency Boration and go to OP-901- Direct Emergency Boration.

103, Emergency Boration.

Comment: Critical If the candidate does not state Emergency Boration is required but states that Shutdown Margin is not met, then ask the candidate what actions SAT / UNSAT are required for this condition, prior to the candidate leaving the area.

END OF TASK Revision 1 Page 5 of 7 2012 NRC Exam

JPM A5 SIMULATOR OPERATOR INSTRUCTIONS There is no Simulator setup for this JPM Revision 1 Page 6 of 7 2012 NRC Exam

JPM A5 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

Do not use Simulator data for this JPM INITIAL CONDITIONS:

Core burnup is 335 EFPD

TCOLD is 543.5 °F

Power is 35%

Power is being held due to a Chemistry hold

Regulating Group P CEAs are being withdrawn for ASI control as xenon builds in

CEA 24 failed to withdraw or insert on the last move

I&C has completed troubleshooting and there are no problems associated with CEDMCS

The Shift Manager has concluded that CEA 24 is mechanically bound INITIATING CUES:

The STA has provided you with a completed OP-903-090, Shutdown Margin, for review.

Review and approve the completed surveillance or correct any errors and document any actions required on the worksheet given.

Revision 1 Page 7 of 7 2012 NRC Exam

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE A6 Review A Calculation For Determining The Amount Of Pure Water That May Be Added To The Refuel Cavity Applicant:

Examiner:

JPM A6 JOB PERFORMANCE MEASURE DATA PAGE Task: Reviewed a calculation for determining the amount of pure water that may be added to the Refuel Cavity Task Standard: Applicant reviewed a calculation for determining the amount of pure water that can be added to the refuel cavity in accordance with OP-010-006, Outage operations. The results conform to the answer key.

References:

OP-010-006, Outage Operations, revision 320 TS 3.9.1 COLR Time Critical: No Validation Time: 15 mins.

K/A 2.1.23 Ability to perform specific system Importance Rating 4.4 and integrated plant procedures during SRO all modes of plant operation.

Applicant:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 8 2012 NRC Exam

JPM A6 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-010-006, Outage Operations COLR

==

Description:==

The applicant will be required to review a calculation for the amount of pure water that can be added to the refuel cavity in accordance with OP-010-006, Outage Operations. To perform this calculation the applicant will determine what the Refueling Minimum Boron concentration is from Tech Specs. The results will indicate that 1413 gallons of PMU may be added to the refuel cavity instead of the 1500 gallons indicated on the reviewed attachment.

READ TO APPLICANT DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

INITIAL CONDITIONS:

Waterford 3 is in a refueling outage

Reactor engineering has determined that a boron concentration of 1985 ppm is required to maintain the refuel cavity at a Keff of < .95

Refueling Cavity Water Level is 24 ft. and will be drained to 22 ft.

Refueling Cavity boron concentration is 2090 ppm INITIATING CUES:

RP has requested that the refuel cavity walls be washed down with PMU as level in the refueling cavity is lowered to 22 ft. MSL.

The CRS is to review the calculation for determining refueling minimum boron concentration per TS 3.9.1 and the performance OP-010-006, Attachment 9.24 Refueling Cavity Boron Concentration. IF necessary, correct any problems found on .24.

Revision 1 Page 3 of 8 2012 NRC Exam

JPM A6 TASK ELEMENT 1 STANDARD Note:

(1) This attachment provides guidance for calculating the amount of pure water that may be added to the Refuel Cavity without dilution to below shutdown margin requirements. This is typically used while Radiation Protection is using CMU to wash down the Refuel Cavity walls to mitigate airborne radioactivity while Note reviewed.

performing Refuel Cavity drain down.

(2) This calculation is only valid for water additions while the Refuel Cavity Water Level is > 20 MSL.

(3) This calculation includes a 50% margin.

SAT / UNSAT 9.24.1 Record the following:

TASK ELEMENT 2 STANDARD Final Refuel Cavity Water Level (Lf): value input verified Comment:

Refer to A6 Key.

SAT / UNSAT TASK ELEMENT 3 STANDARD Initial Refuel Cavity Boron Concentration (Ci) value input verified Comment:

Refer to A6 Key.

SAT / UNSAT Revision 1 Page 4 of 8 2012 NRC Exam

JPM A6 TASK ELEMENT 4 STANDARD Refueling Minimum Boron Concentration (Cf) 2050 ppm Comment: Critical Refer to A6 Key.

The applicant will determine that 2050 ppm is the most restrictive SAT / UNSAT requirement per TS 3.9.1.

The attachment being reviewed has 1985 ppm entered as the refueling minimum boron concentration. 1985 ppm is the reactor engineering boron concentration to maintain Keff < .95. TS 3.9.1 requires the most restrictive of 2050 ppm or the boron concentration to maintain Keff < .95 as the refueling minimum boron concentration. In this case, the most restrictive boron concentration is 2050 ppm.

TASK ELEMENT 5 STANDARD 9.24.2 Calculate the amount of pure water that may be added to the Refuel Cavity (Vw) using the following formula:

Vw = (6954 gal/ft x Lf-79,161 gal) x (1- Cf/Ci) 1402 to 1476 gallons Vw = [( 6954x___ ft) - 79,161]x [1-(___ppm/___ppm)]

Vw=____gallons Comment: Critical The attachment being reviewed would have an error carried forward if 1985 ppm is used as the minimum required boron concentration. SAT / UNSAT TASK ELEMENT 6 STANDARD 9.24.3 Select the lower of Vw calculated in Step 9.24.2 or 1500 gallons: 1402 to 1476 gallons Comment: Critical Refer to A6 Key.

The attachment being reviewed would have an error carried forward if SAT / UNSAT 1985 ppm is used as the minimum required boron concentration.

Revision 1 Page 5 of 8 2012 NRC Exam

JPM A6 TASK ELEMENT 7 STANDARD 9.24.4 SM/CRS designate the allowable amount of pure water to add to the Refuel Cavity by specifying an amount that is < amount specified in Less than or equal to the Step 9.24.3. number calculated in step 9.24.2 SM/CRS designated allowable pure water limit to add to cavity:

Comment: Critical Refer to A1 Key.

Note:The CRS may desire to limit the amount specified in step 9.24.3. SAT / UNSAT The CRS may also defer this decision to the Shift Manager, if he does, the examiner will direct the applicant to designate the amount of pure water to add to the refuel cavity.

END OF TASK Revision 1 Page 6 of 8 2012 NRC Exam

JPM A6 SIMULATOR OPERATOR INSTRUCTIONS There is no Simulator setup for this JPM Revision 1 Page 7 of 8 2012 NRC Exam

JPM A6 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

Do not use Simulator data for this JPM INITIAL CONDITIONS:

Waterford 3 is in a refueling outage

Reactor engineering has determined that a boron concentration of 1985 ppm is required to maintain the refuel cavity at a Keff of < .95

Refueling Cavity Water Level is 24 ft. and will be drained to 22 ft.

Refueling Cavity boron concentration is 2090 ppm INITIATING CUES:

RP has requested that the refuel cavity walls be washed down with PMU as level in the refueling cavity is lowered to 22 ft. MSL.

The CRS is to review the calculation for determining refueling minimum boron concentration per TS 3.9.1 and the performance OP-010-006, Attachment 9.24 Refueling Cavity Boron Concentration. IF necessary, correct any problems found on .24.

Revision 1 Page 8 of 8 2012 NRC Exam

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE A7 Review of Containment Pressure Calculation Applicant:

Examiner:

JPM A7 JOB PERFORMANCE MEASURE DATA PAGE Task: Review of Containment pressure calculation Task Standard: Applicant reviewed a calculation for containment pressure in accordance with OP-903-001, Technical Specification Surveillance Logs. The results conformed to the answer key. The applicant identified that Tech Spec 3.6.1.4 entry is required and identified the applicable Tech Spec action.

References:

OP-903-001, Technical Specification Surveillance Logs, revision 49 Technical Specification 3.6.1.4 Time Critical: No Validation Time: 15 mins.

K/A 2.2.12 Knowledge of Surveillance Importance Rating 4.1 procedures SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 7 2012 NRC Exam

JPM A7 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

1. OP-903-001, Technical Specification Surveillance Logs, revision 49

2. Copy of Attachment 11.15, Containment Pressure Calculation (performed by the ATC)

3. Calculator

==

Description:==

Applicant verifies Containment pressure calculation performed by the ATC.

READ TO APPLICANT DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

INITIAL CONDITIONS:

The plant is at 100% power

Containment pressure reduction was secured during the previous shift

Containment Pressure is -5.4 INWC (PMC Point A51000)

Barometric Pressure is reading is 29.44 INHG as indicated on the (PMC Point C48516)

INITIATING CUE:

Verify the containment pressure calculation performed by the ATC using OP-903-001, Technical Specification Surveillance Logs and identify any TS actions required, if any.

Revision 1 Page 3 of 7 2012 NRC Exam

JPM A7 TASK ELEMENT 1 STANDARD 11.15.1 Barometric Pressure as measured by PMC (PID C48516). If local reading used, then add 0.05 INHG to obtain a value equivalent to Met Tower PMC point. BP=___________ INHG Verified 29.44 entered.

11.15.1.2 Record M&TE data on TS Logs Remarks and WR, if applicable Comment:

Applicant should not add .05 INHG because the PMC is operable. If he adds .05 INHG, the final value of this calculation will be greater than the SAT / UNSAT TS limit.

TASK ELEMENT 2 STANDARD 11.15.2 Containment to Ambient Differential Pressure Verified -5.4 entered (PMC PID-A51000) C/A=____________ INWC Comment:

Value is from initial conditions SAT / UNSAT TASK ELEMENT 3 STANDARD 11.15.3 Convert Barometric Pressure (BP) from INHG to PSIA by performing the following:

Verified BP (PSIA) in the BP(PSIA) = [BP(INHG) x 0.4912 PSIA/INHG]

range of 14.46 to 14.461.

BP(PSIA) = [______________ INHG x 0.4912 PSIA/INHG]

BP(PSIA) = _______________ PSIA Comment:

14.46 is rounded from 14.460928.

SAT / UNSAT TASK ELEMENT 4 STANDARD 11.15.4 Convert Containment to Ambient Differential pressure (C/A) from INWC to PSIA by performing the following:

Recognize the wrong C/A(PSIA) = [CA(INWC) x 0.0361 PSIA/INWC]

number inserted C/A(PSIA) = [______________ INWC x 0.0361 PSIA/INWC]

C/A(PSIA) = _______________ PSIA Comment: Critical

-.195 is rounded from -.19494.

The applicant should indentify that a positive number has been inserted SAT / UNSAT and calculated for this step. The number is correct but the value should be negative. If this error is not identified, the final value of this calculation will be greater than the TS limit.

Revision 1 Page 4 of 7 2012 NRC Exam

JPM A7 TASK ELEMENT 5 STANDARD 11.15.5 Calculate Absolute Containment Internal Pressure (CP) by Recognized the error performing the following: carried forward from the CP(PSIA) = BP(PSIA) + C/A(PSIA) previous step. Corrected CP(PSIA) = ______________ PSIA + _______________ PSIA value should be 14.265 (14.26-14.27)

CP(PSIA) = _______________ PSIA Comment: Critical CP(PSIA) should be 14.265 when corrected. This number is less than TS. SAT / UNSAT TASK ELEMENT 6 STANDARD Identified corrected value is The applicant should identify the corrected value is less than the less than 14.275 PSIA.

Technical Specification 3.6.14 limit for containment pressure (14.275 Identified TS 3.6.1.4 entry PSIA) and the actions for Technical Specification 3.6.1.4 are required. and the correct action required.

Comment: Critical The action for TS 3.6.1.4 is to restore the internal pressure to within the limits within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in at least HOT STANDBY withing the next 6 SAT / UNSAT hours and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

Note: If applicant does not provide the action for TS 3.6.1.4, ask what the action is.

END OF TASK Revision 1 Page 5 of 7 2012 NRC Exam

JPM A7 SIMULATOR OPERATOR INSTRUCTIONS None Revision 1 Page 6 of 7 2012 NRC Exam

JPM A7 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The plant is at 100% power

Containment pressure reduction was secured during the previous shift

Containment Pressure is -5.4 INWC (PMC Point A51000)

Barometric Pressure is reading is 29.44 INHG as indicated on the (PMC Point C48516)

INITIATING CUE:

Verify the containment pressure calculation performed by the ATC using OP-903-001, Technical Specification Surveillance Logs and identify any TS actions required, if any.

Revision 1 Page 7 of 7 2012 NRC Exam

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE A8 Authorize Emergency Exposure as the Emergency Coordinator Candidate:

Examiner:

JPM A8 JOB PERFORMANCE MEASURE DATA PAGE Task: Authorize Emergency Exposure as the Emergency Director Task Standard: Correctly determined that authorization is not appropriate

References:

EP-002-030, Emergency Radiation Exposure Guidelines and Controls, revision 10 Validation Time: 15 minutes Time Critical: No K/A 2.3.4, Knowledge of radiation exposure limits Importance Rating 3.7 under normal or emergency conditions. SRO Candidate:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 5 NRC Exam 2012

JPM A8 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

EP-002-030, Emergency Radiation Exposure Guidelines and Controls, revision 10.

DIRECTION TO CANDIDATE:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

INITIAL CONDITONS:

You are the Emergency Coordinator. The following conditions exist:

A stuck valve must be operated in a high radiation area with dose rates of 45 REM/Hour.

The job will take 15 minutes.

The only available person to do this task is Joe Tallard, SSN # 111-22-3333, Badge # 0101, with Operations.

Radiation Protection has reported that they can take no action to reduce the dose rate.

INITIATING CUE:

Evaluate authorizing Emergency Exposure as Emergency Director.

Document all work and results on this sheet.

Revision 1 Page 3 of 5 NRC Exam 2012

JPM A8 TASK ELEMENT STANDARD Candidate determines that emergency exposure limit of 10 REM TEDE would be Emergency Director reviews EP-002-030, Emergency Exposure exceeded (actual Guidelines & Controls, and authorizes emergency exposure if criteria is calculation would be 11.25 met. REM TEDE) and does not authorize emergency exposure.

Comment: Critical Candidate may state that he could authorize Emergency Exposure if the SAT / UNSAT job could be split between two personnel.

END OF TASK Revision 1 Page 4 of 5 NRC Exam 2012

JPM A8 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)

INITIAL CONDITONS:

You are the Emergency Coordinator. The following conditions exist:

A stuck valve must be operated in a high radiation area with dose rates of 45 REM/Hour.

The job will take 15 minutes.

The only available person to do this task is Joe Tallard, SSN # 111-22-3333, Badge # 0101, with Operations.

Radiation Protection has reported that they can take no action to reduce the dose rate.

INITIATING CUE:

Evaluate authorizing Emergency Exposure as Emergency Director.

Document all work and results on this sheet.

Revision 1 Page 5 of 5 NRC Exam 2012

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE A9 Determine Protective Action Recommendations Candidate:

Examiner:

JPM A9 JOB PERFORMANCE MEASURE DATA PAGE Task: Determine protective action recommendations Task Standard: Satisfactorily uses Attachment 7.2, Protective Action Guidelines Worksheet, Release Occurring, to determine Protective Action Recommendations for the given conditions.

References:

EP-002-052, Protective Action Guidelines, revision 23 Validation Time: 15 minutes Time Critical: No K/A 2.4.44, Knowledge of emergency plan Importance Rating 4.4 protective action recommendations. SRO Candidate:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 5 NRC Exam 2012

JPM A9 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

EP-002-052, Protective Action Guidelines, revision 23 DIRECTION TO CANDIDATE:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

INITIAL CONDITIONS:

You are the Emergency Director

A release is in progress following a LOCA with a failed containment penetration

You declared a General Emergency The following data is available for protective action recommendations:

Duration of release is unknown

Wind Direction from 75°

The Field Teams have reported the following:

o EAB TEDE = 890 mr/hr o EAB CDE Thyroid = 4800 mr/hr o 2 Mile TEDE = 501 mr/hr o 2 Mile CEDE Thyroid = 2485 mr/hr o 5 Mile TEDE = 98 mr/hr o 5 Mile CEDE Thyroid = 1410 mr/hr INITIATING CUE:

Determine Protective Action Recommendations based on available data in accordance with EP-002-052, Protective Action Guidelines.

Revision 1 Page 3 of 5 NRC Exam 2012

JPM A9 TASK ELEMENT STANDARD Candidate determined that an evacuation of areas A1, B1, C1, D1, and C2 is Determine Protective Action Recommendations based on available data required in accordance with EP-002-052, Protective Action Guidelines. Candidate determines that sheltering all other protective response areas is required.

Comment: Critical Candidate should multiply dose rate by 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months (requirement for releases of unknown duration) and determine areas to evacuate. All other areas SAT / UNSAT should be sheltered.

A key for the evaluator (EP-002-052 Attachment 7.2) is available. The applicant may provide the answer verbally and not fill out the attachment.

END OF TASK Revision 1 Page 4 of 5 NRC Exam 2012

JPM A9 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)

Provide all answers on the sheets provided.

INITIAL CONDITIONS:

You are the Emergency Director

A release is in progress following a LOCA with a failed containment penetration

You declared a General Emergency The following data is available for protective action recommendations:

Duration of release is unknown

Wind Direction from 75°

The Field Teams have reported the following:

o EAB TEDE = 890 mr/hr o EAB CDE Thyroid = 4800 mr/hr o 2 Mile TEDE = 501 mr/hr o 2 Mile CEDE Thyroid = 2485 mr/hr o 5 Mile TEDE = 98 mr/hr o 5 Mile CEDE Thyroid = 1410 mr/hr INITIATING CUE:

Determine Protective Action Recommendations based on available data in accordance with EP-002-052, Protective Action Guidelines.

Revision 1 Page 5 of 5 NRC Exam 2012

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Facility: Waterford 3 Date of Examination: 10/01/2012 Exam Level RO SRO-I SRO-U Operating Test No.: 1 Control Room Systems (8 for RO); (7 for SRO-I); (2 or 3 for SRO-U, including 1 ESF)

Type Code* Safety System / JPM Title Function S1 004 Chemical and Volume Control System L,N,S 1 Secure Emergency Boration in accordance with OP-901-103, Emergency Boration.

A4.07, Boration/Dilution RO - 3.9, SRO - 3.7 S2 006 Emergency Core Cooling System, Establish simultaneous hot and D,L,P,S 2 cold leg injection in accordance with OP-902-002, Loss of Coolant Accident Recovery.

A4.07, ECCS pumps and valves RO - 4.4, SRO - 4.4 S3 010 Pressurizer Pressure Control System; Restore Pressurizer Heater L,N,S 3 Control in accordance with OP-902-009, Appendix 25.

A4.02, PZR Heaters RO - 3.6, SRO - 3.4 S4 005 Shutdown Cooling System; Place Shutdown Cooling Train A in A,D,L,S 4P Service Fault: After LPSI Pump A is running, SI-405A will fail closed, requiring the operator to take immediate operator actions IAW OP-901-131, Shutdown Cooling Malfunction, to secure LPSI Pump A.

A4.01 Controls and indication for RHR pumps RO - 3.6, SRO - 3.4 S5 039 Main and Reheat Steam System; BOP operator immediate A,M,S 4S operator actions on evacuation of the Control Room in accordance with OP-901-502, Control Room Evacuation Fault: Turbine fails to trip.

A4.01 Main steam supply. Valves RO - 2.9, SRO - 2.8 S6 022 Containment Cooling System; Perform OP-903-037, Containment D,S 5 Cooling Fans Operability Verification A4.01 CCS Fans RO - 3.6, SRO - 3.6 S7 062 AC Electrical Distribution System; Energize 4.16 KV Safety Bus L,M,S 6 from Offsite Power following a Station Blackout in accordance with OP-902-009, Attachment 12A, 6.9 KV and 4.16 KV Non-Safety Bus Restoration and Attachment 12B, Energize 4.16 KV Safety Bus from Offsite Power. (SITE PRIORITY - PRA)

A4.01 All breakers (including available switchyard) RO - 3.3, SRO -3.1 S8 012 Reactor Protection System (RPS); Reset EFAS in accordance D,EN,S 7 with OP-902-009 Attachment 5-C: EFAS Reset Procedure A4.04 Bistable, trips, reset and test switches RO - 3.3, SRO - 3.3 1 2012 NRC Revision 1

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 In-Plant Systems (3 for RO; 3 for SRO-I; 3 or 2 for SRO-U)

P1 041 Steam Dump System and Turbine Bypass Control A,D,E,L 4S Operate Atmospheric Dump Valve A locally in accordance with OP-901-502, Control Room Evacuation.

Fault: The local pneumatic control station will not function, requiring use of the local handwheel.

A4.06 Atmospheric relief valve controllers RO - 2.9, SRO - 3.1 P2 005 Residual Heat Removal System (Shutdown Cooling System) D,L,R 4P Placing Shutdown Cooling Purification in Service in accordance with OP-009-005 Section 6.6.

K1.04 CVCS RO-2.9, SRO 3.1 G2.1.30 RO-4.4, SRO 4.0 P3 062 A.C. Electrical Distribution A,D,P 6 Transfer SUPS 014AB from Alternate to Normal AC Power in accordance with OP-006-005, Inverters and Distribution.

Fault: After alignment, voltage will not be indicated on SUPS 014 AB inverter.

A3.04 Operation of inverter RO - 2.7, SRO - 2.9

@ All RO and SRO-I control room (and in-plant) systems must be different and serve different safety functions; all 5 SRO-U systems must serve different safety functions; in-plant systems and functions may overlap those tested in the control room.

Type Codes Criteria for RO / SRO-I / SRO-U (A)lternate path 4-6 / 4-6 / 2-3 4 (C)ontrol room 0 (D)irect from bank 9/8/4 7 (E)mergency or abnormal in-plant 1/1/1 1 (EN)gineered safety feature - / - / 1 (control room system) 1 (L)ow-Power / Shutdown 1/1/1 7 (N)ew or (M)odified from bank including 1(A) 2/2/1 4 (P)revious 2 exams 3 / 3 / 2 (randomly selected) 2 (R)CA 1/1/1 1 (S)imulator 8 2 2012 NRC Revision 1

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Facility: Waterford 3 Date of Examination: 10/01/2012 Exam Level: RO SRO-I SRO-U Operating Test No.: 1 Control Room Systems (8 for RO); (7 for SRO-I); (2 or 3 for SRO-U, including 1 ESF)

Type Code* Safety System / JPM Title Function S1 004 Chemical and Volume Control System L,N,S 1 Secure Emergency Boration in accordance with OP-901-103, Emergency Boration.

A4.07, Boration/Dilution RO - 3.9, SRO - 3.7 S2 006 Emergency Core Cooling System, Establish simultaneous hot and D,L,P,S 2 cold leg injection in accordance with OP-902-002, Loss of Coolant Accident Recovery.

A4.07, ECCS pumps and valves RO - 4.4, SRO - 4.4 S3 010 Pressurizer Pressure Control System; Restore Pressurizer Heater L,N,S 3 Control in accordance with OP-902-009 Appendix 25.

A4.02, PZR Heaters RO - 3.6, SRO - 3.4 S4 005 Shutdown Cooling System; Place Shutdown Cooling Train A in A,D,L,S 4P Service Fault: After LPSI Pump A is running, SI-405A will fail closed, requiring the operator to take immediate operator actions IAW OP-901-131, Shutdown Cooling Malfunction, to secure LPSI Pump A.

A4.01 Controls and indication for RHR pumps RO - 3.6, SRO - 3.4 S5 039 Main and Reheat Steam System; BOP operator immediate A,M,S 4S operator actions on evacuation of the Control Room in accordance with OP-901-502, Control Room Evacuation Fault: Turbine fails to trip.

A4.01 Main steam supply. Valves RO - 2.9, SRO - 2.8 S6 022 Containment Cooling System; Perform OP-903-037, Containment D,S 5 Cooling Fans Operability Verification A4.01 CCS Fans RO - 3.6, SRO - 3.6 S7 062 AC Electrical Distribution System; Energize 4.16 KV Safety Bus L,M,S 6 from Offsite Power following a Station Blackout in accordance with OP-902-009, Attachment 12-A: 6.9 KV and 4.16 KV Nonsafety Bus Restoration and Attachment 12-B: Energize 4.16 KV Safety Bus from Offsite Power. (SITE PRIORITY - PRA)

A4.01 All breakers (including available switchyard) RO - 3.3, SRO -3.1 S8.

3 2012 NRC Revision 1

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 In-Plant Systems (3 for RO; 3 for SRO-I; 3 or 2 for SRO-U)

P1 041 Steam Dump System and Turbine Bypass Control A,D,E,L 4S Operate Atmospheric Dump Valve A locally in accordance with OP-005-004, Main Steam.

Fault: The local pneumatic control station will not function, requiring use of the local handwheel.

A4.06 Atmospheric relief valve controllers RO - 2.9, SRO - 3.1 P2 005 Residual Heat Removal System (Shutdown Cooling System) D,L,R 4P Placing Shutdown Cooling Purification in Service in accordance with OP-009-005 Section 6.6.

K1.04 CVCS RO-2.9, SRO 3.1 G2.1.30 RO-4.4, SRO 4.0 P3 062 A.C. Electrical Distribution A,D,P 6 Transfer SUPS 014AB from Alternate to Normal AC Power in accordance with OP-006-005, Inverters and Distribution.

Fault: After alignment, voltage will not be indicated on SUPS 014 AB inverter.

A3.04 Operation of inverter RO - 2.7, SRO - 2.9

@ All RO and SRO-I control room (and in-plant) systems must be different and serve different safety functions; all 5 SRO-U systems must serve different safety functions; in-plant systems and functions may overlap those tested in the control room.

Type Codes Criteria for RO / SRO-I / SRO-U (A)lternate path 4-6 / 4-6 / 2-3 4 (C)ontrol room 0 (D)irect from bank 9/8/4 6 (E)mergency or abnormal in-plant 1/1/1 1 (EN)gineered safety feature - / - / 1 (control room system) -

(L)ow-Power / Shutdown 1/1/1 7 (N)ew or (M)odified from bank including 1(A) 2/2/1 4 (P)revious 2 exams 3 / 3 / 2 (randomly selected) 2 (R)CA 1/1/1 1 (S)imulator 7 4 2012 NRC Revision 1

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Facility: Waterford 3 Date of Examination: 10/01/2012 Exam Level RO SRO-I SRO-U Operating Test No.: 1 Control Room Systems (8 for RO); (7 for SRO-I); (2 or 3 for SRO-U, including 1 ESF)

Type Safety System / JPM Title Code* Function S1 004 Chemical and Volume Control System L,N,S 1 Secure Emergency Boration in accordance with OP-901-103, Emergency Boration.

A4.07, Boration/Dilution RO - 3.9, SRO - 3.7 S2 S3 S4 S5 S6 S7.

S8. 012 Reactor Protection System (RPS); Reset EFAS in accordance with D,EN,S 7 OP-902-009 Attachment 5-C: EFAS Reset Procedure A4.04 Bistable, trips, reset and test switches RO - 3.3, SRO - 3.3 5 2012 NRC Revision 1

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 In-Plant Systems (3 for RO; 3 for SRO-I; 3 or 2 for SRO-U)

P1 041 Steam Dump System and Turbine Bypass Control A,D,E,L 4S Operate Atmospheric Dump Valve B locally in accordance with OP-901-502, Control Room Evacuation.

Fault: The local pneumatic control station will not function, requiring use of the local handwheel.

A4.06 Atmospheric relief valve controllers RO - 2.9, SRO - 3.1 P2 005 Residual Heat Removal System (Shutdown Cooling System) D,L,R 4P Placing Shutdown Cooling Purification in Service in accordance with OP-009-005 Section 6.6.

K1.04 CVCS RO-2.9, SRO 3.1 G2.1.30 RO-4.4, SRO 4.0 P3 062 A.C. Electrical Distribution A,D,P 6 Transfer SUPS 014AB from Alternate to Normal AC Power in accordance with OP-006-005, Inverters and Distribution.

Fault: After alignment, voltage will not be indicated on SUPS 014 AB inverter.

A3.04 Operation of inverter RO - 2.7, SRO - 2.9

@ All RO and SRO-I control room (and in-plant) systems must be different and serve different safety functions; all 5 SRO-U systems must serve different safety functions; in-plant systems and functions may overlap those tested in the control room.

Type Codes Criteria for RO / SRO-I / SRO-U (A)lternate path 4-6 / 4-6 / 2-3 2 (C)ontrol room 0 (D)irect from bank 9/8/4 4 (E)mergency or abnormal in-plant 1/1/1 1 (EN)gineered safety feature - / - / 1 (control room system) 1 (L)ow-Power / Shutdown 1/1/1 3 (N)ew or (M)odified from bank including 1(A) 2/2/1 1 (P)revious 2 exams 3 / 3 / 2 (randomly selected) 1 (R)CA 1/1/1 1 (S)imulator 2 6 2012 NRC Revision 1

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE S1 Securing Emergency Boration Applicant:

Examiner:

JPM S1 JOB PERFORMANCE MEASURE DATA PAGE Task: Secure Emergency Boration in accordance with step 7 of OP-901-103, Emergency Boration.

Task Standard: Applicant secured Emergency Boration and performed a flush of one standby charging pump per step 7 of OP-901-103 without tripping the running Charging Pump.

References:

OP-901-103, Emergency Boration, revision 2 Alternate Path: No Time Critical: No Validation Time: 10 mins.

K/A 004 A4.07 Boration/Dilution Importance Rating 3.9/3.7 RO/SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 12 2012 NRC Exam

JPM S1 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-901-103, Emergency Boration

==

Description:==

The applicant will perform step 7 of OP-901-103, securing Emergency Boration.

This task secures Emergency Boration and aligns the suction source of the Charging Pumps to the Volume Control Tank. All manipulations occur at CP-4. If an applicant does not follow the procedure sequence properly and trips the running Charging Pump, then that applicant would fail this task.

The plant will be emergency borating using the Boric Acid Make-up Pumps.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

INITIAL CONDITIONS:

The plant is in Mode 3 The plant has been shutdown for 3 days

The plant is Emergency Borating due to an uncontrolled positive reactivity addition

The uncontrolled positive reactivity addition has been terminated and Emergency Boration termination criteria are met

The Standby Charging Pump Seal Packages have been running for 30 minutes and an AO is standing by INITIATING CUE:

The CRS directs you to secure Emergency Boration in accordance with OP-901-103, Emergency Boration, step 7 Revision 1 Page 3 of 12 2012 NRC Exam

JPM S1 Evaluator Note Cue the Simulator Operator to place the Simulator in RUN.

TASK ELEMENT 1 STANDARD

7. When Emergency Boration termination criteria (Step 6) are met, then Applicant continues on with secure Emergency Boration by performing the following: the procedure.

Comment:

Termination criteria is met as given in the initial conditions SAT / UNSAT TASK ELEMENT 2 STANDARD 7.1 Place VCT Disch Valve, CVC-183, control switch to AUTO and verify CVC-183 is open.

valve opens Comment: Critical SAT / UNSAT TASK ELEMENT 3 STANDARD Boric Acid Pumps are 7.2 Stop both Boric Acid Pumps.

stopped.

Comment: Critical BAM Pump B is the critical element. SAT / UNSAT TASK ELEMENT 4 STANDARD 7.3 Verify the following valves closed:

CVC-507 RWSP to Charging Pumps All valves in step are BAM-133 Emergency Boration Valve closed.

BAM-113A Boric Acid Makeup Gravity Feed Valve A BAM-113B Boric Acid Makeup Gravity Feed Valve B Comment: Critical BAM-133 will need to be closed. Other valves are not critical. because they are already in the correct position SAT / UNSAT Revision 1 Page 4 of 12 2012 NRC Exam

JPM S1 TASK ELEMENT 5 STANDARD 7.4 Open the following valves:

BAM-126A Boric Acid Makeup Pump A Recirc Valve BAM-126A and B are open.

BAM-126B Boric Acid Makeup Pump B Recirc Valve Comment: Critical BAM-126B is the Critical Task because it is the only one that is closed. SAT / UNSAT Evaluator Note Inform the candidate that the CRS directs him to start Charging Pump AB first to flush boric acid out of the pump.

TASK ELEMENT 6 STANDARD At least one standby 7.5 Operate each Charging Pump for at least 5 minutes to flush Charging Pump is concentrated boric acid out of pump.

operated.

Comment: The candidate may use OP-002-005 to swap charging pumps. Critical Task elements 7 through 20 are the steps in OP-002-005, Charging and Letdown System, for swapping charging pumps. SAT / UNSAT Time compression used for operation of each charging pump.

EVALUATOR CUE: After the applicant starts Charging Pump AB, cue the candidate that 5 minutes has elapsed.

TASK ELEMENT 7 STANDARD Procdure Note The Charging Pump Seal System should be operated for at least 30 Reviewed the Note minutes prior to starting the Charging Pump.

Comment:

The seal package has been running for 30 minutes as indicated in the initial conditions. SAT / UNSAT EVALUATOR CUE: If the candidate calls the RCA watch to verify the seal package running for 30 minutes, then inform him that all seal water pumps have been running for at least 30 minutes.

Revision 1 Page 5 of 12 2012 NRC Exam

JPM S1 TASK ELEMENT 8 STANDARD 6.2.1 At SM/CRS discretion, verify readiness for operation of each Charging Pump to be started as follows:

Verify crankcase oil level 1/2 in bulls eye.

Verify gear reducer oil level between low and high marks on dipstick.

Flush debris and fines from packing seal water system as follows:

A. Place Seal Water Pump A(B)(AB) control switch to ON.

B. Open Charging Pump A(B, AB) Packing Cooling Sump Drain, CVC-704A(B, AB). Candidate communicates with the RCA to verify C. If packing cooling tank level continues to lower Charging Pump AB ready after makeup begins, then prior to tank level for a start.

lowering below the bottom of the sight glass, Throttle Closed Charging Pump A(B, AB)

Packing Cooling Sump Drain, CVC-704A(B, AB), as necessary to maintain packing cooling tank level visible but 1/2 in sightglass.

D. After flushing the packing cooling tank for at least three minutes, then Close Charging Pump A(B, AB) Packing Cooling Sump Drain, CVC-704A(B, AB).

E. Verify packing cooling tank water level 1/2 in sightglass.

Comment:

EVALUATOR CUE: When the candidate calls the RCA watch to perform step 6.1, inform the candidate that step 6.1 is complete and SAT / UNSAT Charging Pump AB is ready for a start.

Revision 1 Page 6 of 12 2012 NRC Exam

JPM S1 TASK ELEMENT 9 STANDARD Procedure Note The purpose of securing the Pressurizer Backup Heater Bank is to minimize the impact of the Charging Pump start on Pressurizer pressure. Note reviewed If the first pump is secured shortly (within approximately one minute) after starting the second pump or PZR boron equalization is in progress, then this step is not necessary when swapping Charging pumps.

Comment:

SAT / UNSAT TASK ELEMENT 10 STANDARD 6.2.2 At SM/CRS discretion, if a Pressurizer Backup Heater Bank is operating, then secure the Pressurizer Backup Heater Bank by Step communicated with placing control switch in AUTO. the CRS.

Comment:

EVALUATOR CUE: If asked, Inform the candidate that securing a pressurizer backup heater is not desired. SAT / UNSAT TASK ELEMENT 11 STANDARD Procedure Caution (1) TO MINIMIZE THERMAL SHOCK OF CHARGING NOZZLES, ONLY ONE CHARGING PUMP SHOULD BE STARTED AT A TIME. Caution reviewed (2) EXTREME CAUTION SHALL BE USED WHEN STARTING ADDITIONAL CHARGING PUMPS WITH THE PRESSURIZER SOLID. EXCESSIVE RCS PRESSURIZATION COULD RESULT.

Comment:

SAT / UNSAT Revision 1 Page 7 of 12 2012 NRC Exam

JPM S1 TASK ELEMENT 12 STANDARD 6.2.3 Start desired Charging Pump A(B)(AB) by placing control Charging Pump AB control switch(es) to ON. switch in ON.

Comment: Critical SAT / UNSAT TASK ELEMENT 13 STANDARD 6.2.4 Verify Seal Water Pump operating for the Charging Pump Seal Water Pump AB A(B)(AB) started and Place Seal Water Pump A(B)(AB) control control switch has been switch in AUTO returned to auto.

Comment:

EVALUATOR CUE: If asked, inform the candidate that the seal water SAT / UNSAT pump for Charging Pump AB is running.

When the candidate directs the RCA watch to place the Seal Water Pump for Charging Pump AB to auto, inform him that the Seal Water Pump for Charging Pump AB is in auto.

TASK ELEMENT 14 STANDARD 6.2.5 If Charging Pump A(B)(AB) started will remain in service as Step reviewed Standby Charging Pump(s), then go to Step 6.2.9.

Comment:: Charging Pump AB will remain in service and Charging Pump B will be secured. Therefore, the applicant will continue to Step 6.2.6.

SAT / UNSAT EVALUATOR CUE: If asked, inform the candidate that Charging Pump AB will be the lead pump.

TASK ELEMENT 15 STANDARD 6.2.6 Secure desired Charging Pump A(B)(AB) by placing control Charging Pumps A and B switch(es) to OFF. control switches are taken to OFF.

Comment:

SAT / UNSAT Revision 1 Page 8 of 12 2012 NRC Exam

JPM S1 TASK ELEMENT 16 STANDARD Procedure Note If there is an Inoperable Charging Pump, then at SM/CRS discretion the Standby Charging Pumps selector switch may be aligned so that Note reviewed the Operable Backup Charging Pump will be the first one selected for auto starting capability.

Comment:

SAT / UNSAT TASK ELEMENT 17 STANDARD 6.2.8 Verify Standby Charging Pumps selector switch in the appropriate Position for the Charging Pump started (Pump in Lead) per Table 6.2.8.

TABLE 6.2.8 Selector switch should be selected to the AB as lead PUMP IN LEAD POSITION pump (A-B position)

B AB - A A B - AB AB A-B Comment: Critical SAT / UNSAT TASK ELEMENT 18 STANDARD 6.2.9 Place control switch(es) for Standby Charging Pump Charging Pumps A and B A(B)(AB) to AUTO. control switches are returned to auto.

Comment: Critical SAT / UNSAT Revision 1 Page 9 of 12 2012 NRC Exam

JPM S1 TASK ELEMENT 19 STANDARD 6.2.10 Place Pump AB Assignment switch to the appropriate Position for the Charging Pump A(B)(AB) to be Assigned to Trip on SIAS, per Table 6.2.10.

TABLE 6.2.10 ASSIGNED TO TRIP ON SIAS POSITION Step reviewed A A AB NORM B B Comment:: The switch does not require manipulation since no Charging Pumps are out of service.

SAT / UNSAT TASK ELEMENT 20 STANDARD 6.2.11 If a Pressurizer Backup Heater Bank was secured in step 6.2.2, then restore a Pressurizer Backup Heater Bank to operation by placing control switch to ON. Step reviewed.

Comment:: No action required for this step since none of the heaters were taken to auto for task element 10.

SAT / UNSAT END OF TASK Revision 1 Page 10 of 12 2012 NRC Exam

JPM S1 SIMULATOR OPERATOR INSTRUCTIONS

1. Reset to IC-199

2. Verify Emergency Boration aligned per OP-901-103 using Boric Acid Pumps

3. There are no malfunctions or overrides for this JPM.

Revision 1 Page 11 of 12 2012 NRC Exam

JPM S1 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The plant is in Mode 3 The plant has been shutdown for 3 days

The plant is Emergency Borating due to an uncontrolled positive reactivity addition

The uncontrolled positive reactivity addition has been terminated and Emergency Boration termination criteria are met

The Standby Charging Pump Seal Packages have been running for 30 minutes and an AO is standing by INITIATING CUE:

The CRS directs you to secure Emergency Boration in accordance with OP-901-103, Emergency Boration, step 7 Revision 1 Page 12 of 12 2012 NRC Exam

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE S2 Hot and Cold Leg Safety Injection Applicant:

Examiner:

JPM S2 JOB PERFORMANCE MEASURE DATA PAGE Task: Hot and Cold Leg Safety Injection aligned for Trains A and B per OP-902-009, Appendix 15.

Task Standard: Applicant aligned Hot and Cold Leg Safety Injection in accordance with OP-902-009, Standard Appendices, Appendix 15.

References:

OP-902-002, Loss of Coolant Accident Recovery, revision 14 OP-902-009, Standard Appendices, revision 307 Alternate Path: No Time Critical: No Validation Time: 15 mins.

K/A 006 A4.07, ECCS pumps and valves Importance Rating 4.4/4.4 RO/SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 8 2012 NRC Exam

JPM S2 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-902-009, Standard Appendices, Appendix 15, Hot and Cold Leg Injection.

==

Description:==

This JPM occurs during a Loss of Coolant Accident. The applicant will receive direction to align simultaneous Hot and Cold Leg Safety Injection. All manipulations will occur at CP-8.

Applicant must obtain keys for the valves manipulated in this JPM at the NPO Desk.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

INITIAL CONDITIONS:

A Loss of Coolant Accident occurred 2.5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months ago

The crew has entered OP-902-002, Loss of Coolant Accident Recovery

The conditions exist that require alignment of hot and cold leg injection per step 47, Hot and Cold Leg Injection

You are the BOP operator INITIATING CUE:

The Control Room Supervisor directs you to establish Hot and Cold Leg Injection in accordance with OP-902-009, Standard Appendices, Appendix 15 Revision 1 Page 3 of 8 2012 NRC Exam

JPM S2 1.1 Establish simultaneous Hot and Cold leg injection for Train A by performing the following:

TASK ELEMENT 1 STANDARD 1.1.a Close SI-219A, HPSI HEADER ORIFICE BYPASS valve. SI-219A is closed.

Comment: Critical SAT / UNSAT TASK ELEMENT 2 STANDARD 1.1.b Open SI-502A, HOT LEG 1 INJECTION ISOLATION valve. SI-502A is open.

Comment: Critical SAT / UNSAT TASK ELEMENT 3 STANDARD 1.1.c Open SI-506A, HOT LEG 1 INJECTION FLOW CONTROL valve. SI-506A is open.

Comment: Critical SAT / UNSAT Revision 1 Page 4 of 8 2012 NRC Exam

JPM S2 1.2 Establish simultaneous Hot and Cold leg injection for Train B by performing the following:

TASK ELEMENT 4 STANDARD 1.2.a Close SI-219B, HPSI HEADER ORIFICE BYPASS valve. SI-219B is closed.

Comment: Critical SAT / UNSAT TASK ELEMENT 5 STANDARD 1.2.b Open SI-502B, HOT LEG 2 INJECTION ISOLATION valve. SI-502B is open.

Comment: Critical SAT / UNSAT TASK ELEMENT 6 STANDARD 1.2.c Open SI-506B, HOT LEG 2 INJECTION FLOW CONTROL valve. SI-506B is open.

Comment: Critical SAT / UNSAT Revision 1 Page 5 of 8 2012 NRC Exam

JPM S2 TASK ELEMENT 7 STANDARD The sum of all cold leg 1.3 WHEN hot and cold leg injection has been established, THEN adjust flows is approximately SI-506 A and SI-506 B to obtain the sum of ALL cold leg flows equal to equal to the sum of the hot the sum of the hot leg flows.

leg flows.

Comment:

Applicant can obtain Hot and Cold Leg flows from either the PMC, the meters on CP-8, or QSPDS. SAT / UNSAT Due to the flow balance that is performed on these valves each outage flow balance between Hot and Cold Leg injection will be close. The candidate may not adjust flow. They should however, verify the flows.

END OF TASK Revision 1 Page 6 of 8 2012 NRC Exam

JPM S2 SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-198 Place the Simulator in Run on the lead examiners cue.

Revision 1 Page 7 of 8 2012 NRC Exam

JPM S2 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

A Loss of Coolant Accident occurred 2.5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months ago

The crew has entered OP-902-002, Loss of Coolant Accident Recovery

The conditions exist that require alignment of hot and cold leg injection per step 47, Hot and Cold Leg Injection

You are the BOP operator INITIATING CUE:

The Control Room Supervisor directs you to establish Hot and Cold Leg Injection in accordance with OP-902-009, Standard Appendices, Appendix 15 Revision 1 Page 8 of 8 2012 NRC Exam

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE S3 OP-902-009, Restore Pressurizer Heater Control Applicant:

Examiner:

JPM S3 JOB PERFORMANCE MEASURE DATA PAGE Task: Perform OP-902-009 Appendix 25, Restore Pressurizer Heater Control.

Task Standard: Applicant completed OP-902-009 Appendix 25 and restored Pressurizer backup and proportional heaters to service.

References:

OP-902-009 Appendix 25, revision 307 Alternate Path: No Time Critical: No Validation Time: 10 mins.

K/A 010 A4.02 Pzr Heaters Importance Rating 3.6, 3.4 RO/SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 7 2012 NRC Exam

JPM S3 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-902-009 Appendix 25, Restore Pressurizer Heater Control, revision 307

==

Description:==

The applicant will perform OP-902-009 Appendix 25, Restore Pressurizer Heater Control. This task restores Pressurizer Heaters to service following a SIAS. All manipulations occur at CP-1 and CP-2. If an applicant does not restore all Pressurizer heaters to service, then that applicant would fail this task.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

INITIAL CONDITION:

The plant is shutdown following an Inadvertent Safety Injection Actuation Signal.

INITIATING CUE:

The CRS directs you to perform OP-902-009, Appendix 25, Restore Pressurizer Heater Control.

Revision 1 Page 3 of 7 2012 NRC Exam

JPM S3 Evaluator Note Cue the Simulator Operator to place the Simulator in RUN.

TASK ELEMENT 1 STANDARD Procedure Note Pressurizer heaters can NOT be restored with a LOOP concurrent with a Note reviewed.

SIAS.

Comment:

Only a SIAS will be initiated.

SAT / UNSAT TASK ELEMENT 2 STANDARD 1.1 Verify pressurizer level is greater than 33%. Level verified.

Comment:

SAT / UNSAT TASK ELEMENT 3 STANDARD 1.2 Monitor EDG loading to ensure EDG does not exceed 4 MW. Step reviewed Comment: CP-1 The EDGs will be running but not connected to the safety busses. No LOOP has occurred. SAT / UNSAT TASK ELEMENT 4 STANDARD Verifies 200 Second Block 1.3 Check SEQUENCER has timed out for each energized safety bus. illuminated for both Sequencers Comment: CP-1 SAT / UNSAT Revision 1 Page 4 of 7 2012 NRC Exam

JPM S3 TASK ELEMENT 5 STANDARD A32 FEEDER breaker 1.4 Close SST A32 FEEDER breaker.

closed.

Comment: CP-1 Critical SAT / UNSAT TASK ELEMENT 6 STANDARD B32 FEEDER breaker 1.5 Close SST B32 FEEDER breaker.

closed.

Comment: CP-1 Critical SAT / UNSAT TASK ELEMENT 7 STANDARD Both Proportional Heater Bank control switches 1.6 Place PROPORTIONAL HEATER BANKS control switches to ON taken to ON and Proportional Heaters are energized.

Comment: CP-2 Critical SAT / UNSAT TASK ELEMENT 8 STANDARD All Backup Heater Bank 1.7 Momentarily place each BACKUP HEATER BANKS control switches control switches taken to to OFF and then to AUTO. OFF and then to AUTO or ON.

Comment: CP-2 Critical SAT / UNSAT END OF TASK Revision 1 Page 5 of 7 2012 NRC Exam

JPM S3 SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-197 Verify SIAS is initiated and both Sequencers are timed out.

There are no malfunctions or overrides for this JPM.

Revision 1 Page 6 of 7 2012 NRC Exam

JPM S3 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITION:

The plant is shutdown following an Inadvertent Safety Injection Actuation Signal.

INITIATING CUE:

The CRS directs you to perform OP-902-009, Appendix 25, Restore Pressurizer Heater Control.

Revision 1 Page 7 of 7 2012 NRC Exam

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE S4 Place Shutdown Cooling Train A in Service Applicant:

Examiner:

JPM S4 JOB PERFORMANCE MEASURE DATA PAGE Task: Place Shutdown Cooling Train A in Service Task Standard: Applicant correctly performed the identified critical steps for placing Shutdown Cooling Train A in service in accordance with OP-009-005 and secured Low Pressure Safety Injection Pump A after SI-405A fails closed.

References:

OP-009-005, Shutdown Cooling, revision 31 OP-901-131, Shutdown Cooling Malfunction, revision 302 Alternate Path: Yes Time Critical: No Validation Time: 20 mins.

K/A 005 A4.01, Controls and indication for RHR Importance Rating 3.6 / 3.4 pumps RO / SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision1 Page 2 of 12 2012 NRC Exam

JPM S4 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-009-005, Shutdown Cooling OP-901-131, Shutdown Cooling Malfunction, revision 302

==

Description:==

This task is performed at CP-8. The applicant must place Shutdown Cooling Train A in service. The fault in this task is that SI-405A, RC Loop 2 SDC Suction Inside Containment Isol, will fail closed, requiring the applicant to secure Low Pressure Safety Injection Pump A. The task can be stopped after LPSI Pump A is secured.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

INITIAL CONDITIONS:

The plant is in Mode 4

Protected Train is A

RCS temperature is 280 °F

RCS pressure is 340 PSIA

RCS boron concentration is 2027 ppm

SDC Train A suction penetration piping has been manually vented

Shutdown Cooling Train A has been placed in Standby in accordance with OP-009-005, Shutdown Cooling, section 5.3 INITIATING CUE:

The CRS directs you to place Shutdown Cooling Train A in service in accordance with OP-009-005, Shutdown Cooling, Section 6.1 Revision1 Page 3 of 12 2012 NRC Exam

JPM S4 TASK ELEMENT 1 STANDARD Procedure Caution:

THE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT Caution reviewed.

CORE REACTIVITY Comment:

SAT / UNSAT TASK ELEMENT 2 STANDARD Procedure Note: The Shutdown Cooling Train placed in service Note reviewed.

should be on the Protected Train.

Comment:

Protected Train is A as given in initial conditions.

SAT / UNSAT TASK ELEMENT 3 STANDARD Procedure Caution:

FOLLOWING A DESIGN BASIS TORNADO EVENT, DELAYING THE INITIATION OF SHUTDOWN COOLING (SDC) FOR UP TO 7 DAYS WILL BE REQUIRED TO ENSURE THE COMPONENT COOLING WATER SYSTEM IS CAPABLE OF REMOVING Caution reviewed.

REACTOR COOLANT SYSTEM DECAY HEAT. THE ACTUAL DELAY TIME WILL DEPEND ON UHS DAMAGE AND AMBIENT TEMPERATURE AND WILL BE DETERMINED BY ENGINEERING.

EMERGENCY FEEDWATER SUPPORTS DECAY HEAT REMOVAL UNTIL SDC CAN BE INITIATED.

Comment:

SAT / UNSAT TASK ELEMENT 4 STANDARD 6.1.1: Verify Shutdown Cooling Train A has been aligned to Standby Notes Section 5.3 is complete condition in accordance with Section 5.3, Alignment of and continues in procedure.

Shutdown Cooling Train A to Standby Condition.

Comment:

Cue sheet lists this as complete.

SAT / UNSAT Revision1 Page 4 of 12 2012 NRC Exam

JPM S4 TASK ELEMENT 5 STANDARD 6.1.2: Verify sufficient number of Dry Cooling Tower Fans running to Continues in procedure after accept increased heat load on CCW System. cue.

Comment:

EVALUATOR CUE: If asked, inform the candidate to leave the Dry SAT / UNSAT Cooling Tower Fans in automatic and allow Auxiliary Component Cooling Water to pick up the heat load.

TASK ELEMENT 6 STANDARD Procedure Caution:

CC-963A IS REQUIRED TO BE MAINTAINED OPEN WHILE IN MODE 4 TO PRESERVE THE DESIGN TEMPERATURE BASIS OF PIPING AND ASSOCIATED COMPONENTS AT THE CCW OUTLET Caution reviewed.

OF SHUTDOWN COOLING HEAT EXCHANGER A. WITH CC-963A OPEN, FLOW THROUGH SHUTDOWN COOLING HEAT EXCHANGER A WILL BE MAINTAINED ABOVE 2305 GPM.

Comment:

SAT / UNSAT TASK ELEMENT 7 STANDARD 6.1.3: Place Shutdown HX A CCW Flow Control, CC-963A, control CC-963 A is open.

switch to Open.

Comment: Critical SAT / UNSAT Revision1 Page 5 of 12 2012 NRC Exam

JPM S4 TASK ELEMENT 8 STANDARD Procedure Caution:

(1) The following Reactor Coolant System limits shall be met for Shutdown Cooling Entry:

RCS temperature limit: < 350 °F

RCS pressure limit: < 392 psia

If Containment harsh environment conditions (>200°F) have Caution reviewed.

been exceeded then RCS pressure limit: <358 Psia (2) If Containment Spray Header A Isolation, CS-125 A, is open while Shutdown Cooling Train A is operating, then Containment Spray A riser may fill and possibly spray water into Containment, due to leakage past Containment Spray Pump A discharge stop check, CS-117A.

Comment:

SAT / UNSAT TASK ELEMENT 9 STANDARD Procedure Caution: To minimize the effect of air introduction to a LPSI pump, the piping between SI-405A AND SI-407A should be placed in- Caution reviewed.

service with one of the following conditions:

Comment:

SAT / UNSAT TASK ELEMENT 10 STANDARD 6.1.4: Verify RC Loop 2 SDC suction piping meets one of the following conditions:

The SDC Train is placed in-service with RCS pressure > 100 PSIA by PMC indication (PIDs A12203, A12204, A12222) or >

110 PSIA by board indication (RC-IPI0103,-0104,-0105,- One of the conditions is 0106). verified. Cue sheet lists SDC or Train A suction penetration The SDC Trains suction penetration has been manually has been manually vented.

vented.

or The SDC Train was previously in-service since the unit has been shutdown.

Comment:

SAT / UNSAT Revision1 Page 6 of 12 2012 NRC Exam

JPM S4 TASK ELEMENT 11 STANDARD 6.1.5: Unlock and Open RC Loop 2 SDC Suction Outside SI-407 A is open.

Containment Isol, SI-407A.

Comment: Critical Key 133 required.

SAT / UNSAT TASK ELEMENT 12 STANDARD 6.1.6: Notify Radiation Protection Department that Shutdown Cooling Call is made.

Train A is being placed in service.

Comment:

SAT / UNSAT TASK ELEMENT 13 STANDARD 6.1.7: Start LPSI Pump A. LPSI Pump A is started.

Comment: Critical Annunciator LPSI Pump A Flow Lost (Cabinet M, F-3) is expected. It will clear when the applicant raises flow > 2900 gpm. SAT / UNSAT TASK ELEMENT 14 STANDARD 6.1.8: Raise Shutdown Cooling flow by Manually adjusting LPSI Header Flow controller 2A/2B, SI-IFIC-0307, output until Shutdown Cooling Header A Flow indicates 4100 GPM, as Flow is raised to ~ 4100 GPM.

indicated by RC Loop 2 Shdn Line Flow Indicator, SI-IFI-1307-A1.

Comment: Critical SAT / UNSAT TASK ELEMENT 15 STANDARD 6.1.9: Adjust LPSI Header Flow Controller 2A/2B, SI-IFIC-0307, Setpoint potentiometer is ~

setpoint potentiometer to 73%, and place controller to AUTO. 73%, and controller is in AUTO Comment: Critical SAT / UNSAT Revision1 Page 7 of 12 2012 NRC Exam

JPM S4 TASK ELEMENT 16 STANDARD 6.1.10: Verify LPSI Header Flow Controller 2A/2B, SI-IFIC-0307, is maintaining 4100 GPM Shutdown Cooling Header A flow, as Flow is verified.

indicated by RC Loop 2 Shdn Line Flow Indicator, SI-IFI-1307-A1.

Comment:

SAT / UNSAT TASK ELEMENT 17 STANDARD Procedure note: If a sample was drawn prior to shutdown and no interim shutdown has occurred where SDC was placed in service and Note reviewed.

boron concentration could have been reduced, then sampling is not required.

Comment:

SAT / UNSAT TASK ELEMENT 18 STANDARD 6.1.11: At SM/CRS discretion, direct Chemistry Department to sample Shutdown Cooling Train A for boron concentration.

Determines that boron 6.1.11.1 When Chemical Analysis results indicate that concentration meets the Shutdown Cooling Train A boron concentration is greater than requirement.

Reactor Coolant boron concentration or >2050 ppm (required for Mode 6), then proceed to next step.

Comment:

EVALUATOR CUE: When requested, inform the applicant that SAT / UNSAT Shutdown Cooling Train A boron concentration is 2060 ppm. RCS boron concentration is in the initial conditions and is 2027 ppm.

TASK ELEMENT 19 STANDARD Procedure Note: Shutdown Cooling Train A requires one operable Low Pressure Safety Injection Flow Control Valve for the train to be Note reviewed.

operable.

Comment:

SAT / UNSAT Revision1 Page 8 of 12 2012 NRC Exam

JPM S4 TASK ELEMENT 20 STANDARD Procedure Caution: The Reactor Coolant System shall not exceed the Caution reviewed.

100 °F per hour cooldown rate of Technical Specification 3.4.8.1.

Comment:

EVALUATOR CUE: If asked, inform the applicant that the CRS will SAT / UNSAT evaluate Tech Specs.

6.1.12 Raise Shutdown Cooling Train A temperature to within 100 °F of Reactor Coolant Hot temperature as follows:

TASK ELEMENT 21 STANDARD 6.1.12.1: Open the following valves:

SI-139 A and SI-138 A are

SI-139A LPSI Header to RC Loop 2A Flow Control open.

SI-138A LPSI Header to RC Loop 2B Flow Control Comment: Critical SAT / UNSAT TASK ELEMENT 22 STANDARD 6.1.12.2: Throttle Closed RC Loop 2 Shdn Cooling Warmup, SI-135A, until one of the following is within 100°F of Shutdown Cooling Train A temperature, as indicated by LPSI Pump A Discharge Header Temperature Indicator, SI-ITI-0351X:

Hot Leg 2 temperature, as indicated by RC Loop 2 Temperature is within 100 °F Hot Leg Temperature Indicator, RC-ITI-0122-HA or Hot Leg 1 temperature, as indicated by RC Loop 1 Hot Leg Temperature Indicator, RC-ITI-0122-HB Comment: Critical SI-135 A is a large gate valve with a very long stroke. SAT / UNSAT TASK ELEMENT 23 STANDARD 6.1.12.3: Close RC Loop 2 Shdn Cooling Warmup, SI-135 A. SI-135 A is closed Comment: Critical SAT / UNSAT Revision1 Page 9 of 12 2012 NRC Exam

JPM S4 Evaluator Note Coordinate with the simulator operator to initiate trigger 1 to close SI-405 A five seconds after SI-135A closes.

Evaluator Note The following step represents the alternate path portion of the JPM.

TASK ELEMENT 24 STANDARD Secure LPSI Pump A LPSI Pump A is off.

Comment: Critical This is an immediate operator action in accordance with OP-901-131, SAT / UNSAT Shutdown Cooling Malfunction, section D.1.

END OF TASK Revision1 Page 10 of 12 2012 NRC Exam

JPM S4 SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-195 Verify the following Malfunctions:

SI23A for SI-405A on Trigger 1 Coordinate with the examiner so that when SI-135 A is fully closed at step 6.1.11.3 for 5 seconds, initiate event Trigger 1 to close SI-405A. (Use Extreme View to monitor SI-135A position)

Revision1 Page 11 of 12 2012 NRC Exam

JPM S4 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The plant is in Mode 4

Protected Train is A

RCS temperature is 280 °F

RCS pressure is 340 PSIA

RCS boron concentration is 2027 ppm

SDC Train A suction penetration piping has been manually vented

Shutdown Cooling Train A has been placed in Standby in accordance with OP-009-005, Shutdown Cooling, section 5.3 INITIATING CUE:

The CRS directs you to place Shutdown Cooling Train A in service in accordance with OP-009-005, Shutdown Cooling, Section 6.1 Revision1 Page 12 of 12 2012 NRC Exam

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE S5 Balance of Plant Operator Immediate Operator Actions on Control Room Evacuation Applicant:

Examiner:

JPM S5 JOB PERFORMANCE MEASURE DATA PAGE Task: Perform balance of plant operators immediate operator action on Control Room evacuation with fire conditions.

Task Standard: Applicant performed immediate operator actions for BOP position for a fire in the Control Room in accordance with OP-901-502, Evacuation of Control Room and Subsequent Plant Shutdown.

Applicant manually tripped the turbine due the turbine failing to trip on a Reactor trip. Applicant placed Atmospheric Dump Valve 2 in manual and lowered output to zero due to Atmospheric Dump Valve 2 spuriously opening.

References:

OP-901-502, Evacuation of Control Room and Subsequent Plant Shutdown, Revision 22 Alternate Path: Yes Time Critical: No Validation Time: 5 mins.

K/A 039 A4.01 Main Steam Supply Valves Importance Rating 2.9 / 2.8 RO / SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 7 2012 NRC Exam

JPM S5 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

None

==

Description:==

The applicant will be cued that there is a fire in CP-33. The CRS will direct him to carry out his immediate operator actions as BOP operator. The main turbine will not trip when the reactor is tripped. The applicant will be required to manually trip the main turbine using the turbine trip buttons. Atmospheric Dump Valve 2 will spuriously open requiring Atmospheric Dump Valve 2 controller to be placed in manual and output lowered to zero. The task will end when the applicant obtains a key ring and communicates his intention to proceed to the RAB +35 Relay room.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

INITIAL CONDITIONS:

The plant is at 100% power

A fire has started in CP-33

The CRS has entered OP-901-502, Evacuation of Control Room and Subsequent Plant Shutdown

The At-The-Controls Operator will perform his immediate operator actions

You are the Balance of Plant Operator INITIATING CUE:

The CRS directs you to perform the BOP immediate operator actions for OP-901-502, Evacuation of Control Room and Subsequent Plant Shutdown.

Revision 1 Page 3 of 7 2012 NRC Exam

JPM S5 Evaluator Note Cue the Simulator Operator to place the Simulator in RUN and initiate Trigger 1.

Evaluator Note The Alternate Path becomes applicable when the applicant addresses the turbine not tripping on a Reactor Trip.

TASK ELEMENT 1 STANDARD 2.1 Verify Turbine trip:

Governor valves Closed Turbine tripped.

Throttle valves Closed Comment: Critical The applicant will trip the turbine using the trip buttons at CP-1 SAT / UNSAT TASK ELEMENT 2 STANDARD 2.2 Verify Generator trip:

Exciter Field Breaker Tripped Verification complete.

Generator Breaker A Tripped

Generator Breaker B Tripped Comment:

SAT / UNSAT TASK ELEMENT 3 STANDARD RESET pushbutton depressed and 2.3 RESET Moisture Separator Reheater controls.

Temperature Control Valves are closed.

Comment: Critical SAT / UNSAT Revision 1 Page 4 of 7 2012 NRC Exam

JPM S5 2.4 IF evacuating the Control Room due to fire, THEN perform the following:

Evaluator Note The second Alternate Path becomes applicable when the applicant addresses MS-116A SG 1 Atmospheric Dump spuriously opening.

TASK ELEMENT 4 STANDARD 2.4.1 IF EITHER of the following valves has spuriously Opened, THEN MS-116A verified operating place the applicable controller(s) in MANUAL AND lower the output properly.

to zero:

MS-116B controller in MS-116A SG 1 Atmospheric Dump Manual and output lowered MS-116B SG 2 Atmospheric Dump (critical path) to zero.

Comment: Critical SAT / UNSAT TASK ELEMENT 5 STANDARD 2.4.2 Close the following valves:

MS-124A & MS-124B are MS-124A Main Steam Isol Valve #1 closed.

MS-124B Main Steam Isol Valve #2 Comment: Critical SAT / UNSAT TASK ELEMENT 6 STANDARD 2.5 Obtain Operations Security Key Ring AND proceed to RAB +35 Relay Keys obtained.

Room.

Comment:

The examinee should obtain a Key Locker key from the Key locker on left side of the Control Room Desk and simulate getting key from the locker SAT / UNSAT in the Shift Managers Office represented by the photo posted in the SM office.

END OF TASK Revision 1 Page 5 of 7 2012 NRC Exam

JPM S5 SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-196

1. Set Trigger 1 to actuate on Rx Tripped

2. Verify the following Malfunctions:

RP03 - ACTIVE

MS23B - 0 PSIG with a 10 Second Ramp on Trigger 1 Revision 1 Page 6 of 7 2012 NRC Exam

JPM S5 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The plant is at 100% power

A fire has started in CP-33

The CRS has entered OP-901-502, Evacuation of Control Room and Subsequent Plant Shutdown

The At-The-Controls Operator will perform his immediate operator actions

You are the Balance of Plant Operator INITIATING CUE:

The CRS directs you to perform the BOP immediate operator actions for OP-901-502, Evacuation of Control Room and Subsequent Plant Shutdown.

Revision 1 Page 7 of 7 2012 NRC Exam

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE S6 Perform OP-903-037, Containment Cooling Fans Operability Check Candidate:

Examiner:

JPM S6 JOB PERFORMANCE MEASURE DATA PAGE Task: Perform OP-903-037, Containment Cooling Fans Operability Check Task Standard: Candidate correctly completed the identified critical tasks of OP-903-037, Containment Cooling Fans Operability Check.

References:

OP-903-037, Containment Cooling Fans Operability Check, revision 5 OP-008-003, Containment Cooling System, revision 301 Alternate Path: No Time Critical: No Validation Time: 15 mins.

K/A 022 A4.01 CCS Fans Importance Rating 3.6/3.6 RO/SRO Candidate:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 10 NRC Exam 2012

JPM S6 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-903-037, Containment Cooling Fans Operability Check, revision 5 OP-008-003, Containment Cooling System, revision 301

==

Description:==

This task is performed at CP-18. The candidate must perform surveillance OP-903-037, which will require logging differential pressure for the 3 running fans. The candidate will then have to secure a running Containment Cooling Fan and start Containment Cooling Fan D, at which time the data for CCS Fan D can be recorded.

The candidate should then leave the CCS Fans in an alignment with A, B, and D running, as specified in OP-903-037.

READ TO CANDIDATE DIRECTION TO CANDIDATE:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

INITIAL CONDITIONS:

Plant is in Mode 3 INITIATING CUES:

The CRS directs you to perform OP-903-037, Containment Cooling Fans Operability Check.

Align the final Containment Fan Cooler configuration for the month of October.

Revision 1 Page 3 of 10 NRC Exam 2012

JPM S6 TASK ELEMENT 1 STANDARD 7.1 Record differential pressure (DP) and CCW flow rate for operating Values are recorded on Att. 1.

CFC units on Attachment 10.1, CFC Data Sheet.

Comment: Critical SAT / UNSAT TASK ELEMENT 2 STANDARD Procedure Note: Attachment 10.2, Run Time Equalization Schedule Determine correct alignment Sheet, should be referenced in determining which CFC operating for the month of October.

unit(s) is secured.

Comment:

SAT / UNSAT TASK ELEMENT 3 STANDARD Procedure Caution: To prevent vibration alarms, and damage to containment cooling unit duct work, limit configuration to only three (3) Caution reviewed of four (4) units operating at a time.

Comment:

SAT / UNSAT TASK ELEMENT 4 STANDARD 7.2 Adjust CFC operating unit configuration to operate idle CFC CCS Fan C is off and CCS unit(s). Fan D is running.

Comment:

Evaluator: This is written for the candidate to secure CCS Fan C, which is the most reasonable fan for him to stop. It is acceptable for SAT / UNSAT the candidate to secure CCS Fan A or B at this point. This would require the candidate to maneuver fans later in the task to leave fans A, B, and D running.

The applicant will use OP-008-003 to first secure a CCS fan and then to start a CCS fan. Task elements 5-6 are for securing a CCS fan.

Task elements 7-14 are for starting a CCS fan.

Revision 1 Page 4 of 10 NRC Exam 2012

JPM S6 7.1 Securing Containment Fan Coolers TASK ELEMENT 5 STANDARD 7.1 1 Stop desired Containment Fan Coolers (CFC), from CP-18, by placing Fan Cooler A(B)(C)(D) control switch CCS-0003 One CCS fan is secured A(B)(C)(D) to Stop.

Critical SAT / UNSAT TASK ELEMENT 6 STANDARD 7.1 2 Verify at CP-18, that Component Cooling Water Inlet and Outlet Valves for all secured Containment Fan Coolers are Closed.

CFC VALVES A Inlet CC-808A Outlet CC-822A Inlet and Outlet valves closed B Inlet CC-807B Outlet CC-823B C Inlet CC-807A Outlet CC-823A D Inlet CC-808B Outlet CC-822B SAT / UNSAT 6.1 Starting Containment Fan Coolers TASK ELEMENT 7 STANDARD Procedure Note Note reviewed Normal Containment Cooling System Configuration in modes 1-4 is three (3) Containment Fan Coolers operating and one (1) in standby.

SAT / UNSAT Revision 1 Page 5 of 10 NRC Exam 2012

JPM S6 TASK ELEMENT 8 STANDARD Procedure Caution TO PREVENT VIBRATION ALARMS AND DAMAGE TO CONTAINMENT COOLING UNIT DUCT WORK, LIMIT Caution reviewed.

CONFIGURATION TO ONLY THREE (3) OF FOUR (4)

CONTAINMENT FAN COOLERS OPERATING AT ONE TIME WHEN IN FAST SPEED.

SAT / UNSAT TASK ELEMENT 9 STANDARD 6.1.1 Start desired Containment Fan Coolers (CFC), from CP-18, by placing Fan Cooler A(B)(C)(D) control switch CCS-0003 A(B)(C)(D) to CCS fan started.

Start/ Fast.

Critical SAT / UNSAT TASK ELEMENT 10 STANDARD 6.1.2 Verify at CP-18 that the Component Cooling Water Inlet and Outlet Valves Open for the in-service coolers:

CFC VALVES A Inlet CC-808A Outlet CC-822A B Inlet CC-807B Inlet And Outlet Valves open.

Outlet CC-823B C Inlet CC-807A Outlet CC-823A D Inlet CC-808B Outlet CC-822B SAT / UNSAT Revision 1 Page 6 of 10 NRC Exam 2012

JPM S6 TASK ELEMENT 11 STANDARD Procedure Note If Containment Fan Coolers are being started with slow speed Note reviewed.

jumpers installed for Containment cooling with Temporary Chilled Water, then steps 6.1.3 and 6.1.4 are not applicable.

SAT / UNSAT TASK ELEMENT 12 STANDARD 6.1.3 Check in-service Containment Fan Coolers A (B, C, D)

Verified proper differential differential pressures within expected range of 5.0 INWC to 8.0 pressure.

INWC, as indicated on CCS-IDPR-5154A(B).

SAT / UNSAT TASK ELEMENT 13 STANDARD 6.1.4 Check Component Cooling Water flow is > 625 gpm as Verified proper flow.

indicated on CC-IFI-7570A(B).

SAT / UNSAT TASK ELEMENT 14 STANDARD 7.4 When CFC unit(s) have operated for > 15 minutes, then record Attachment 10.1 data updated CFC unit(s) differential pressure for unit(s) started in Step 2, on for differential pressure.

Attachment 10.1, CFC Data Sheet.

Perform Time Compression and state that the fan has been running Critical for > 15 minutes.

SAT / UNSAT TASK ELEMENT 15 STANDARD 7.5 Verify all four CFC units were operated and data recorded on Attachment 10.1 data updated Attachment 10.1, CFC Data Sheet. for all CCS Fans.

Critical Note: Only 2 fans will be operated. One will be secured and the non-running fan will be started. SAT / UNSAT Revision 1 Page 7 of 10 NRC Exam 2012

JPM S6 TASK ELEMENT 16 STANDARD 7.6 Verify each CFC Unit CCW flow rate is > 625 GPM Satisfactory flow rates verified.

SAT / UNSAT TASK ELEMENT 17 STANDARD 7.7 Refer to Attachment 10.2, Run Time Equalization Schedule Sheet, Determine that CFC A, B and to obtain CFC unit alignment for the upcoming month. D to be left running.

SAT / UNSAT TASK ELEMENT 18 STANDARD 7.8 Verify that CFC units are aligned as required on Attachment 10.1, CFC A, B and D running.

CFC Data Sheet.

SAT / UNSAT TASK ELEMENT 19 STANDARD Steps 10.1.1 and 10.1.2 0.1 of OP-903-037: completed and initialed.

Steps 10.1.1 and 10.1.2 completed and initialed.

The performed by line The performed by line signed.

signed.

SAT / UNSAT END OF TASK Revision 1 Page 8 of 10 NRC Exam 2012

JPM S6 SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-199 Verify CFC A, B, and C are running initially There are no malfunctions or overrides for this JPM.

Revision 1 Page 9 of 10 NRC Exam 2012

JPM S6 CANDIDATE CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)

INITIAL CONDITION:

Plant is in Mode 3 INITIATING CUES:

The CRS directs you to perform OP-903-037, Containment Cooling Fans Operability Check.

Align the final Containment Fan Cooler configuration for the month of October.

Revision 1 Page 10 of 10 NRC Exam 2012

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE S7 Energize 4.16 KV Safety Bus from Offsite Power following a Station Blackout Applicant:

Examiner:

JPM S7 JOB PERFORMANCE MEASURE DATA PAGE Task: Energize 4.16 KV Safety Bus from Offsite Power following a Station Blackout.

Task Standard: The candidate restored power to the 1A and 2A busses from offsite power and then energized the 4.16 KV Safety Bus (3A bus) from offsite power

References:

OP-902-009, Standard Appendices, Attachment 12-A: 6.9 KV and 4.16 KV Nonsafety Bus Restoration, revision 307 OP-902-009 Standard Appendices, Attachment 12-B: Energize 4.16 KV Safety Bus from Offsite Power, revision 307 Alternate Path: No Time Critical: No Validation Time: 15 mins.

K/A 062 A4.01, All breakers (including available Importance Rating 3.3 / 3.1 switchyard) RO / SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 8 2012 NRC Exam

JPM S7 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-902-009, Standard Appendices, Attachment 12-A: 6.9 KV and 4.16 KV Nonsafety Bus Restoration, revision 307 OP-902-009 Standard Appendices, Attachment 12-B: Energize 4.16 KV Safety Bus from Offsite Power, revision 307

==

Description:==

The JPM begins with the plant in a station blackout. The applicant will restore power to the 3A Safety Bus from offsite using OP-902-009, Standard Appendices, Attachments 12-A and 12-B. Actions for this task take place at CP-1 and CP-8. (This JPM is a site specific priority as an operator action for preventing core damage)

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

INITIAL CONDITIONS:

The plant is performing actions in OP-902-005, Station Blackout.

Power to the Offsite Grid has been restored.

Lockout relay 86STA handswitch on 7KV-ESWGR-1A-3 has been reset.

The station blackout has been occurring for 30 minutes. All time critical actions required by OP-902-005, Station Blackout, have been completed.

INITIATING CUE:

The CRS directs you to energize the A1 and A2 busses from offsite power and then energize the 3A bus in accordance with OP-902-009, Standard Appendices, Attachments 12A and 12B.

Revision 1 Page 3 of 8 2012 NRC Exam

JPM S7 Evaluator Note When Applicant is ready, cue the simulator operator to place the simulator in RUN.

Task element 1-4 are applicable to OP-902-009 Appendix 12-A, 6.9 KV and 4.16 KV Nonsafety Bus Restoration 1.1 IF offsite power is available AND 6.9 KV and 4.16 KV nonsafety buses A1 and A2 are deenergized, THEN energize the 6.9 KV and 4.16 KV nonsafety buses as follows:

TASK ELEMENT 1 STANDARD

a. Locally reset lockout relay 86STA handswitch on 7KV-ESWGR-1A-3. local relay reset Comment: The 86STA Lockout Relay has been RESET as indicated in the initial conditions.

SAT / UNSAT EVALUATOR CUE: If asked, inform the candidate that the 86STA Lockout Relay has been RESET.

TASK ELEMENT 2 STANDARD

b. Verify SUT A DISCONNECT closed. disconnect closed Comment: Critical Indication is in the control room on CP-1.

SAT / UNSAT TASK ELEMENT 3 STANDARD

c. Verify loads have stripped from SWGR A1 and SWGR A2.

loads verified stripped Comment:

Verified in the field.

EVALUATOR CUE: After the examinee requests verification from the SAT / UNSAT Auxiliary Operator, cue the examinee that all loads have stripped from Busses A1 and A2.

TASK ELEMENT 4 STANDARD

d. Place BUS A TRANSFER switch to SUT. Switch taken to SUT.

Comment: Critical Switch on CP-1 SAT / UNSAT Revision 1 Page 4 of 8 2012 NRC Exam

JPM S7 TASK ELEMENT 5 STANDARD

e. Locally reset lockout relays:

86A1/HR on 7KV-ESWGR-1A-2 relays reset 86A2/HR on 4KV-ESWGR-2A-2 Comment:

Relays are reset in the field.

EVALUATOR CUE: After the examinee requests the Auxiliary Operator SAT / UNSAT reset the relays, cue the examinee that the 86A1/HR and 86A2/HR relays are reset.

Evaluator Note The following steps are applicable to OP-902-009, Appendix 12B, Energize 4.16KV Safety Bus from Offsite Power.

TASK ELEMENT 6 STANDARD 1.1 IF containment pressure is less than 17.7 PSIA, THEN verify BOTH Both CS Pump control CS pump control switches are in OFF. switches are in OFF Comment: Critical Control switches are on CP-8.

SAT / UNSAT TASK ELEMENT 7 STANDARD 1.2 IF CCW flow to the RCP seals has been interrupted for greater than 10 minutes, THEN close the following valves:

CC 641, COMPONENT COOLING WATER RCP INLET OUTSIDE ISOL Required valves closed CC 710, COMPONENT COOLING WATER RCP OUTLET INSIDE ISOL CC 713, COMPONENT COOLING WATER RCP OUTLET OUTSIDE ISOL Comment: Critical Control switches on CP-8.

SAT / UNSAT Revision 1 Page 5 of 8 2012 NRC Exam

JPM S7 TASK ELEMENT 8 STANDARD 1.3 IF DC Loads have been stripped per Appendix 7 THEN Open the following breakers prior to AC power restoration to 4.16 KV Safety 3 buses: Both breakers are open.

EGF-EBKR-312A-3F, EG A Fuel Oil Transfer Pump EGF-EBKR-312B-3F, EG B Fuel Oil Transfer Pump Comment:

Performed in the field.

EVALUATOR CUE: After the examinee communicates the task to the SAT / UNSAT Auxiliary Operator, cue the examinee that both breakers are open.

1.4 IF 4.16KV nonsafety bus A2 energized AND the 4.16 KV safety bus A3 is deenergized, THEN perform the following:

TASK ELEMENT 9 STANDARD Verifies BUS A2 TO A3S

a. Verify BUS A3S TO A2 TIE BKR Open TIE BKR is open.

Comment:

Breaker switch and indication are on CP-1.

SAT / UNSAT TASK ELEMENT 10 STANDARD BUS A2 TO A3S TIE BKR

b. Close BUS A2 TO A3S TIE BKR is closed.

Comment: Critical Breaker switch is on CP-1.

SAT / UNSAT TASK ELEMENT 11 STANDARD BUS A3S TO A2 TIE BKR

c. Close BUS A3S TO A2 TIE BKR is closed.

Comment: Critical Breaker switches are on CP-1.

EVALUATOR CUE: After the BUS A3S TO A2 TIE BKR is closed, cue SAT / UNSAT the examinee that the task is complete.

END OF TASK Revision 1 Page 6 of 8 2012 NRC Exam

JPM S7 SIMULATOR OPERATOR INSTRUCTIONS

1. Reset to IC-200.

2. Place Simulator in RUN and allow PMC initiation.

3. After PMC has completed initialization acknowledge all annunciators and place the Simulator in FREEZE.

4. Place the Simulator in RUN on the lead examiners cue.

Initial IC Setup

1. Reset to a MODE 3 IC.

2. Insert Malfunctions ED01A-D to ACTIVE.

3. Insert Malfunctions EG10A and EG10B to ACTIVE.

4. Insert Malfunction ED02C to ACTIVE.

5. Place Simulator in RUN.

6. Verify all Malfunctions are ACTIVE and the Simulator indicates Station Blackout conditions with SUT A isolated.

7. Remove Malfunctions ED01A-D and ED02C.

8. Set Remotes EDR01, EDR02, EDR50, and EDR51 to CLOSE.

9. Set Remotes EDR59A SWGR on Trigger 1.

10. Set Remote EDR59B to SWGR on Trigger 2.

11. Acknowledge Annunciators.

12. Place Simulator in Freeze.

13. Snap to the desired IC using current exam passwords for read and write protection.

Revision 1 Page 7 of 8 2012 NRC Exam

JPM S7 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The plant is performing actions in OP-902-005, Station Blackout.

Power to the Offsite Grid has been restored.

Lockout relay 86STA handswitch on 7KV-ESWGR-1A-3 has been reset.

The station blackout has been occurring for 30 minutes. All time critical actions required by OP-902-005, Station Blackout, have been completed.

INITIATING CUE:

The CRS directs you to energize the A1 and A2 busses from offsite power and then energize the 3A bus in accordance with OP-902-009, Standard Appendices, Attachments 12A and 12B.

Revision 1 Page 8 of 8 2012 NRC Exam

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE S8 Reset Emergency Feedwater Actuation Applicant:

Examiner:

JPM S8 JOB PERFORMANCE MEASURE DATA PAGE Task: Reset Emergency Feedwater Actuation Task Standard: The candidate reset the EFAS actuation in accordance with OP-902-009, Standard Appendices, Attachment 5-C.

References:

OP-902-009, Standard Appendices, Attachment 5-C, EFAS Reset Procedure, Revision 307 OP-902-001, Reactor Trip Recovery, Revision 12 Alternate Path: No Time Critical: No Validation Time: 10 mins.

012 A4.04, Bistable, trips, reset and test K/A Importance Rating 3.3 / 3.3 switches RO / SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 9 2012 NRC Exam

JPM S8 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-902-009, Standard Appendices, Attachment 5-C, EFAS Reset Procedure, revision 307

==

Description:==

The JPM begins after a Reactor trip on an Inadvertent Safety Injection. EFAS-1 and EFAS-2 are actuated. Steam Generator Levels are being controlled by Main Feedwater. The applicant will be directed to reset EFAS 1 and 2. Actions for this task take place at CP-7, CP-8 and CP-33.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

INITIAL CONDITIONS:

A reactor trip has occurred due to an inadvertent Safety Injection Actuation Signal

The crew is implementing OP-902-001, Reactor Trip Recovery

Emergency Feedwater is not required to maintain Steam Generator levels

EFAS-1 has been manually initiated

EFAS-2 has automatically initiated INITIATING CUE:

The CRS directs you, to perform OP-902-009, Standard Appendices, Attachment 5-C, EFAS Reset Procedure, and reset EFAS 1 and 2.

Revision 1 Page 3 of 9 2012 NRC Exam

JPM S8 Evaluator Note When Applicant is ready, cue the simulator operator to place the simulator in RUN.

TASK ELEMENT 1 STANDARD 1.1 Verify steam generator level is being maintained or restored to 50%

Levels verified.

to 70% NR using MFW.

Comment:

SAT / UNSAT TASK ELEMENT 2 STANDARD 1.2. Verify EFAS-1 manual actuation switches in NORM position. (CP-Switches returned to 7 and CP-8)

NORM.

Comment: EFAS-1 has been manually initiated. The EFAS-1 switches Critical must be restored to NORM.

SAT / UNSAT TASK ELEMENT 3 STANDARD 1.3 Verify EFAS-2 manual actuation switches in NORM position. (CP-7 Verify switches.

and CP-8)

Comment:

SAT / UNSAT Revision 1 Page 4 of 9 2012 NRC Exam

JPM S8 TASK ELEMENT 4 STANDARD 1.4 Press BOTH EFAS-1 reset pushbuttons. (CP-33) Pushbuttons depressed.

Comment: Critical SAT / UNSAT TASK ELEMENT 5 STANDARD 1.5 Press BOTH EFAS-2 reset pushbuttons. (CP-33) Pushbuttons depressed.

Comment: Critical SAT / UNSAT TASK ELEMENT 6 STANDARD 1.6 Verify EFW Pump A is secured and place the control switch to EFW Pump A secured and normal. (mid position) switch in mid position.

Comment: Critical SAT / UNSAT TASK ELEMENT 7 STANDARD 1.7 Verify EFW Pump B is secured and place the control switch to EFW Pump B secured and normal (mid position) switch in mid position.

Comment: Critical SAT / UNSAT Revision 1 Page 5 of 9 2012 NRC Exam

JPM S8 TASK ELEMENT 8 STANDARD 1.8 Verify MS-401A, EFW PUMP AB TURB STM SUPPLY SG 1 is MS-401A is closed.

closed.

Comment: Critical Control switch must be taken to CLOSE and then to the mid position.

SAT / UNSAT TASK ELEMENT 9 STANDARD 1.9 Verify MS-401B, EFW PUMP AB TURB STM SUPPLY SG 2 is MS-401B is closed.

closed .

Comment: Critical Control switch must be taken to CLOSE and then to the mid position.

SAT / UNSAT TASK ELEMENT 10 STANDARD 1.10 Verify EMERGENCY FEEDWATER FLOW control valves closed:

EFW 223A, SG1 BACKUP EFW 224A, SG1 PRIMARY Valves are closed.

EFW 223B, SG2 BACKUP EFW 224B, SG2 PRIMARY Comment: The applicant should use both controller output position and PMC indication to verify valves closed.

SAT / UNSAT TASK ELEMENT 11 STANDARD 1.11 Place EMERGENCY FEEDWATER FLOW control valves in AUTO.

EFW 223A, SG1 BACKUP (critical)

EFW 224A, SG1 PRIMARY (critical) Valves in AUTO.

EFW 223B, SG2 BACKUP EFW 224B, SG2 PRIMARY Comment: Critical SAT / UNSAT Revision 1 Page 6 of 9 2012 NRC Exam

JPM S8 TASK ELEMENT 11 STANDARD 1.12 Close EMERGENCY FEEDWATER ISOLATION valves.

EFW 229A, SG1 BACKUP EFW 228A, SG1 PRIMARY Valves closed.

EFW 229B, SG2 BACKUP EFW 228B, SG2 PRIMARY Comment: Critical SAT / UNSAT END OF TASK Revision 1 Page 7 of 9 2012 NRC Exam

JPM S8 SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-197 Verify SIAS, EFAS1, and EFAS2 are initiated Place the Simulator in Run on the lead examiners cue.

Revision 1 Page 8 of 9 2012 NRC Exam

JPM S8 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

A reactor trip has occurred due to an inadvertent Safety Injection Actuation Signal

The crew is implementing OP-902-001, Reactor Trip Recovery

Emergency Feedwater is not required to maintain Steam Generator levels

EFAS-1 has been manually initiated

EFAS-2 has automatically initiated INITIATING CUE:

The CRS directs you, to perform OP-902-009, Standard Appendices, Appendix 5-C, EFAS Reset Procedure, and reset EFAS 1 and 2.

Revision 1 Page 9 of 9 2012 NRC Exam

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE P1 Atmospheric Dump Valve Local Operation Applicant:

Examiner:

JPM P1 JOB PERFORMANCE MEASURE DATA PAGE Task: Locally Operate Atmospheric Dump Valve A Task Standard: Opened Atmospheric Dump Valve A to 25% in accordance with OP-005-004, Main Steam. Local pneumatic control failed during the evolution, requiring local handwheel control.

References:

OP-005-004, Main Steam, revision 22 Alternate Path: Yes Time Critical: No Validation Time: 15 mins.

041 Steam Dump System and Turbine K/A Importance Rating 2.9 / 3.1 Bypass Control A4.06 Atmospheric relief valve controllers RO / SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 9 2012 NRC Exam

JPM P1 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-005-004, Main Steam, revision 22

==

Description:==

Applicant will be directed to open Atmospheric Dump Valve A to 25% open.

During the task, local pneumatic control will not function requiring local handwheel operation. Task will occur in Main Steam Isolation Valve A room and does require climbing ladders to access the platform. Gloves are required.

When performing JPM validation, actions are necessary to ensure exam security is maintained.

Prior to commencing in plant JPM validation, contact Health Physics and direct them to disable all cameras in the RCA in a manner that prevents anyone from viewing any of the RCA cameras.

After all in plant JPMs are complete, contact Health Physics to restore the disabled cameras.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All steps for this JPM will be simulated; do not manipulate any plant components. Make all necessary communications to me. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

INITIAL CONDITIONS:

The plant is in Mode 3

RCS temperature is being controlled by Atmospheric Dump Valve A and B

The CP-8 controller for Atmospheric Dump Valve A is not responding INITIATING CUE:

The CRS directs you to locally open MS-116A, Atmospheric Dump Valve A, to 25% open using OP-005-004, Main Steam, section 8.7 Revision 1 Page 3 of 9 2012 NRC Exam

JPM P1 TASK ELEMENT 1 STANDARD Procedure Note Note reviewed.

Refer to T.S. 3.7.1.7 prior to performing this section.

Comment:

EVALUATOR CUE: The Control Room staff is addressing all Tech Specs. SAT / UNSAT TASK ELEMENT 2 STANDARD Procedure Caution OPENING ADV MAY CAUSE AN RCS COOLDOWN, RESULTING IN A Caution reviewed.

CHANGE IN REACTIVITY AND STEAM GENERATOR LEVELS.

Comment:

SAT / UNSAT TASK ELEMENT 3 STANDARD 8.7.1 Establish communications with the Control Room. Control Room contacted.

Comment:

EVALUATOR CUE: The Control Room is standing by for local operation of MS-116A, ADV 1. SAT / UNSAT TASK ELEMENT 4 STANDARD 8.7.2 If desired to operate MS-116A locally using pneumatic operation, then perform the following : Pressure recorded.

8.7.2.1 Record the pressure at the outlet of the transducer:

Comment:

EVALUATOR CUE: Pressure reads as it is displayed (~ 3 psig).

SAT / UNSAT Revision 1 Page 4 of 9 2012 NRC Exam

JPM P1 TASK ELEMENT 5 STANDARD Pressure adjusted to 8.7.2.2 Adjust the pressure at Air Regulator outlet on the front of the pressure from preceding panel to the pressure noted in step 8.7.2.1.

step.

Comment:

Turning the regulator operator counter clockwise will lower pressure.

EVALUATOR CUE: When handle is turned in the correct direction, cue SAT / UNSAT that pressure lowers to required pressure.

TASK ELEMENT 6 STANDARD 8.7.2.3 Turn the Pneumatic Permissive Valve above the Transducer to Pneumatic Permissive Manual. Valve is in manual.

Comment: Critical EVALUATOR CUE: Valve handle is rotated from Auto to Manual.

SAT / UNSAT TASK ELEMENT 7 STANDARD 8.7.2.4 Turn the Pneumatic Permissive Valve above the Air Regulator to Pneumatic Permissive Manual. Valve is in manual.

Comment: Critical EVALUATOR CUE: Valve handle is rotated from Auto to Manual.

SAT / UNSAT Revision 1 Page 5 of 9 2012 NRC Exam

JPM P1 TASK ELEMENT 8 STANDARD Procedure Note The ADV will be closed when pressure at outlet of Air Regulator is < 4.5 Note reviewed.

PSIG and full open when pressure at outlet of Air Regulator is > 15 PSIG.

Comment:

SAT / UNSAT Evaluator Note The next step introduces the fault. When the air regulator is adjusted, provide the cue that there is no change in pressure and that MS-116A, ADV 1 is not moving.

Evaluator Note If the applicant reports to the Control Room that local pneumatic control is not functioning without a recommendation, ask the applicant if there is an alternate method to operate the ADV. If local handwheel operation is identified, then direct the applicant to open ADV A to 25% open using the handwheel.

TASK ELEMENT 9 STANDARD 8.7.2.5 Adjust the Air Regulator pressure to obtain desired valve position by performing any of the following:

Open MS-116A by turning air regulator adjusting screw in the Applicant attempts to adjust clockwise direction to raise air pressure. pressure.

Close MS-116A by turning the air regulator adjusting screw in the counterclockwise direction to lower air pressure.

Comment: Applicant attempts to open the ADV by rotating the regulator in the clockwise position.

EVALUATOR CUE: Air regulator pressure and ADV position are not SAT / UNSAT changing.

Applicant should go to step 8.7.4.

TASK ELEMENT 10 STANDARD Applicant proceeds with 8.7.4 If desired to operate MS-116A(B) using local handwheel, then local handwheel operation perform the following:

of MS-116A.

Comment: Critical EVALUATOR CUE:

SAT / UNSAT Revision 1 Page 6 of 9 2012 NRC Exam

JPM P1 TASK ELEMENT 11 STANDARD 8.7.4.1 Close Local NG/IA Isolation to the positioner for applicable MS-116A(B) SG 1(2) MS Atm Dump Valve:

NG-8271C, NG/IA Isolation to MS-116A NG-8271 C is closed or NG-8281D, NG/IA Isolation to MS-116B Comment: Critical EVALUATOR CUE: Valve closes when operated.

SAT / UNSAT TASK ELEMENT 12 STANDARD 8.7.4.2 Open Filter Petcock Drain and bleed off Air/N2 pressure by Filter Petcock Drain is opening Filter Petcock Drain. open.

Comment: Critical EVALUATOR CUE: Air is heard coming from the drain when opened.

Pressure lowers to zero and air flow stops and the sound of the air goes SAT / UNSAT away.

TASK ELEMENT 13 STANDARD 8.7.4.3 Open MS-116A(B) SG 1(2) MS Atm Dump Valve Local Valve Positioner Equalizing Valve Positioner Equalizing Valve. is open.

Comment: Critical EVALUATOR CUE: Valve open when operated.

SAT / UNSAT TASK ELEMENT 14 STANDARD 8.7.4.4 Engage local handwheel and Open MS-116A(B) SG 1(2) MS Atm Dump Valve to desired position by performing the following: Clevis removed.

8.7.4.4.1 Unscrew clevis from top of the Manual Override Shaft.

Comment: Critical EVALUATOR CUE: Clevis unscrews when operated counter clockwise.

SAT / UNSAT Revision 1 Page 7 of 9 2012 NRC Exam

JPM P1 TASK ELEMENT 15 STANDARD 8.7.4.4.2 Turn handwheel to expose actuator shaft above manual Actuator shaft exposed.

override shaft.

Comment: Critical EVALUATOR CUE: As handwheel is turned counter-clockwise, actuator shaft is exposed. When shaft is fully exposed, notch at the bottom of the SAT / UNSAT shaft is visible.

TASK ELEMENT 16 STANDARD 8.7.4.4.3 Slide clevis onto actuator shaft. Clevis installed.

Comment: Critical EVALUATOR CUE: Clevis fits into notch.

SAT / UNSAT TASK ELEMENT 17 STANDARD MS-116A, ADV 1 is 25%

8.7.4.4.4 Turn handwheel to open MS-116A(B) to desired position.

open.

Comment: Critical EVALUATOR CUE: As handwheel is turned clockwise, MS-116 A, ADV 1 opens. Steam issues from ADV 1 exhaust pipe. Applicant will observe SAT / UNSAT a loud noise and some heat.

END OF TASK Revision 1 Page 8 of 9 2012 NRC Exam

JPM P1 APPLICANT CUE SHEET Do Not Manipulate Any Plant Components (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The plant is in Mode 3

RCS temperature is being controlled by Atmospheric Dump Valve A and B

The CP-8 controller for Atmospheric Dump Valve A is not responding INITIATING CUE:

The CRS directs you to locally open MS-116A, Atmospheric Dump Valve A, to 25% open using OP-005-004, Main Steam, section 8.7 Revision 1 Page 9 of 9 2012 NRC Exam

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE P2 Placing Shutdown Cooling Purification in Service Applicant:

Examiner:

JPM P2 JOB PERFORMANCE MEASURE DATA PAGE Task: Placing Shutdown Cooling Purification in service Task Standard: Applicant performed all identified critical action steps correctly per OP-009-005, Shutdown Cooling. Shutdown Cooling Purification is in service and Shutdown Cooling Purification is aligned to Shutdown Cooling Train A.

References:

OP-009-005, Shutdown Cooling, revision 31 Alternate Path: No Time Critical: No Validation Time: 20 mins.

K/A 005 K1.04 CVCS Importance Rating 2.9/3.1 G2.1.30 RO/SRO 4.4/4.0 Applicant:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 10 2012 NRC Exam

JPM P2 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-009-005, Shutdown Cooling, revision 31

==

Description:==

This task is performed on the -4 and -15 levels of the RCA.

When performing JPM validation, actions are necessary to ensure exam security is maintained.

Prior to commencing in plant JPM validation, contact Radiation Protection and direct them to disable all cameras in the RCA in a manner that prevents anyone from viewing any of the RCA cameras.

After all in plant JPMs are complete, contact Radiation Protection to restore the disabled cameras.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All steps for this JPM will be simulated, do not manipulate any plant components. Make all necessary communications to me. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

INITIAL CONDITIONS:

Shutdown Cooling Train A is in service

Shutdown Cooling Purification Ion Exchanger A is aligned for service

RCS Hot Leg Temperature is 105°F INITIATING CUES:

The following conditions exist:

-Reactor Coolant System is at atmospheric pressure

-Normal Letdown and Charging is secured

-Sufficient room is available in the Boron Management System to flush Chemical and Volume Control System Purification Ion Exchanger(s)

The CRS directs you to place Shutdown Cooling Purification in service using Purification Ion Exchanger A in accordance with OP-009-005, Shutdown Cooling Purification, Section 6.6.

Revision 1 Page 3 of 10 2012 NRC Exam

JPM P2 TASK ELEMENT 1 STANDARD Procedure Caution THE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT Caution reviewed CORE REACTIVITY.

Comment:

EVALUATOR CUE:

SAT / UNSAT TASK ELEMENT 2 STANDARD Procedure Note The following are prerequisites for placing Shutdown Cooling Purification System in service:

(1) Reactor Coolant System is at atmospheric pressure.

(2) Normal Letdown and Charging is secured. Note reviewed (3) One Shutdown Cooling train in service.

(4) Sufficient room in Boron Management System to flush Chemical and Volume Control System Purification Ion Exchanger(s).

Comment:

EVALUATOR CUE: All perquisites are met for placing Shutdown Cooling Purification in service. The prerequisites are identified in the SAT / UNSAT initiating cue and initial conditions.

TASK ELEMENT 3 STANDARD Procedure Caution PLACING SHUTDOWN COOLING PURIFICATION IN SERVICE WITH EITHER HYDROGEN PEROXIDE OR HYDRAZINE PRESENT IN Caution reviewed REACTOR COOLANT WILL DAMAGE CHEMICAL AND VOLUME CONTROL SYSTEM PURIFICATION ION EXCHANGER(S).

Comment:

EVALUATOR CUE: If asked, there is no hydrogen peroxide or hydrazine present in the reactor coolant system. SAT / UNSAT TASK ELEMENT 4 STANDARD 6.6.1 Verify Letdown Stop Valve, CVC-101, Closed. Contacts Control Room Comment:

EVALUATOR CUE: Letdown Stop Valve, CVC-101, is Closed.

SAT / UNSAT Revision 1 Page 4 of 10 2012 NRC Exam

JPM P2 TASK ELEMENT 5 STANDARD Procedure Note Both of the following valves must be open to meet the Open permissive interlock for Letdown HX Temperature Control, CC-636. Note Reviewed CVC-103 Letdown Inside Containment Isolation CVC-109 Letdown Outside Containment Isolation Comment:

SAT / UNSAT TASK ELEMENT 6 STANDARD 6.6.2 If RCS Hot Leg temperature is > 120°F, then perform the following:

6.6.2.1 Verify the following valves Open:

CVC-103 Letdown Inside Containment Isolation Contacts Control Room to CVC-109 Letdown Outside Containment Isolation determine RCS Hot Leg 6.6.2.2 Verify Regen HX Outlet Header to Letdown HX Temperature temperature.

Indicator Controller, CVC-ITIC-0223, in Auto, and set potentiometer to maintain < 120°F.

Comment:

EVALUATOR CUE: RCS Hot leg temperature is 105°F.

SAT / UNSAT TASK ELEMENT 7 STANDARD Valve is unlocked and 6.6.3 Unlock and Open Letdown to LPSI Pumps Suction Isol, CVC-164.

open.

Comment: Critical EVALUATOR CUE: Provide cue to the applicant of valve position moving from closed to open. SAT / UNSAT TASK ELEMENT 8 STANDARD Valve is unlocked and 6.6.4 Unlock and Open Shdn Cooling Purification Supply Isol, SI-423.

open.

Comment: Critical EVALUATOR CUE: Provide cue to the applicant of valve position moving from closed to open. SAT / UNSAT Revision 1 Page 5 of 10 2012 NRC Exam

JPM P2 TASK ELEMENT 9 STANDARD 6.6.5 Place Letdown Backpressure Controller, CVC-IPIC-0201, to Contacts Control Room Manual, and adjust output to Zero.

Comment:

EVALUATOR CUE: The control room reports that the Letdown Backpressure Controller, CVC-IPIC-0201, is in Manual, and output is SAT / UNSAT adjusted to Zero.

TASK ELEMENT 10 STANDARD 6.6.6 Unlock and slowly open RC Loop 2(1) Shdn Cooling Purification Valve is open.

Supply Isol, SI-418A(B).

Comment: Critical EVALUATOR CUE: RC Loop 2, Shdn Cooling Purification Supply Isol, SI-418A is open. SAT / UNSAT Note: The placard on the valve informs the applicant to verify the same valve on the opposite train valve closed. The applicant should identify SI-418B closed.

TASK ELEMENT 11 STANDARD 6.6.7 Verify Letdown HX Outlet temperature < 120°F, as indicated by Contacts Control Room Letdown HX Tube Outlet Temperature indicator, CVC-ITI-0224.

Comment:

EVALUATOR CUE: The control room reports that Letdown HX Outlet temperature is 105°F, as indicated by Letdown HX Tube Outlet SAT / UNSAT Temperature indicator, CVC-ITI-0224.

TASK ELEMENT 12 STANDARD 6.6.8 Verify Purification Ion Exchanger(s) is in service, in accordance Recognizes Purification Ion with appropriate section of this procedure. Exchanger A is in service.

Comment:

EVALUATOR CUE: Purification Ion Exchanger A is in service per the initial conditions. SAT / UNSAT TASK ELEMENT 13 STANDARD 6.6.9 Verify Letdown to Ion Exchangers Inlet/Bypass, CVC-140, control Contacts Control Room switch in AUTO.

Comment:

EVALUATOR CUE: The control room reports that Letdown to Ion Exchangers Inlet/Bypass, CVC-140, control switch is in AUTO. SAT / UNSAT Revision 1 Page 6 of 10 2012 NRC Exam

JPM P2 TASK ELEMENT 14 STANDARD Contacts control room and applicant recognizes that 6.6.10 At SM/CRS discretion, direct Chemistry Department to sample steps 6.6.10.1 through CVC Ion Exchanger effluent for boron, chlorides, and fluorides as 6.6.10.6.3 are not required follows: since sampling is completed with SAT results.

Comment:

EVALUATOR CUE: The control room reports that Chemistry has completed their sample for CVC Ion Exchanger effluent and samples SAT / UNSAT indicate that fluorides and chlorides are within limits and boron concentration is greater than Reactor coolant boron concentration.

Evaluator Note The next step directs the applicant to Unlock and Close Purification Ion Exchs Outlet Header Isolation, CVC-1661. CVC-1661 is in the VCT room which is a High Radiation Room. The room is not accessible but the applicant should have knowledge that CVC-1661 is in the VCT room.

TASK ELEMENT 15 STANDARD Applicant identifies that CVC-1661 is in the VCT 6.6.11 Unlock and Close Purification Ion Exchs Outlet Header Isolation, room and indicates that he CVC-1661.

would unlock and close CVC-1661.

Comment: Critical EVALUATOR CUE: Purification Ion Exchs Outlet Header Isolation, CVC-1661 is unlocked and closed. After the applicant identifies that SAT / UNSAT CVC-1661 is in the VCT room, tell him that CVC-1661 is unlocked and closed.

TASK ELEMENT 16 STANDARD 6.6.12 Unlock and Open Letdown to LPSI Pump A (B) Suction Isol, CVC-Valve is open.

1654A(B).

Comment: Critical EVALUATOR CUE: Letdown to LPSI Pump A (B) Suction Isol, CVC-1654A(B) is unlocked and open. SAT / UNSAT Note: The placard on the valve informs the applicant to verify the same valve on the opposite train valve closed. The applicant should identify CVC-1654B closed.

Revision 1 Page 7 of 10 2012 NRC Exam

JPM P2 TASK ELEMENT 17 STANDARD 6.6.13 Verify Letdown HX Outlet temperature < 120°F, as indicated by Contacts Control Room Letdown HX Tube Outlet Temperature indicator, CVC-ITI-0224.

Comment:

EVALUATOR CUE: The control room reports that Letdown HX Outlet temperature is 105°F, as indicated by Letdown HX Tube Outlet SAT / UNSAT Temperature indicator, CVC-ITI-0224.

TASK ELEMENT 18 STANDARD Procedure Caution FLOW RATE THROUGH CVC ION EXCHANGER(S) SHOULD NOT Caution reviewed EXCEED 126 GPM.

Comment:

EVALUATOR CUE:

SAT / UNSAT TASK ELEMENT 19 STANDARD 6.6.14 Adjust Letdown Backpressure Controller, CVC-IPIC-0201, to Contacts Control Room obtain flow as required by SM/CRS.

Comment:

EVALUATOR CUE: The control room reports that the Letdown Backpressure Controller, CVC-IPIC-0201, has been adjusted to 80 gpm. SAT / UNSAT TASK ELEMENT 20 STANDARD 6.6.15 Verify Purification Ion Exchanger A(B)(C) differential pressure, as Satisfactory D/P is verified indicated on CVC-IDPI-0207(0205)(0203) is <20 PSID.

Comment:

EVALUATOR CUE: Purification Ion Exchanger A differential pressure, as indicated on CVC-IDPI-0207 is reading 5 PSID. SAT / UNSAT Revision 1 Page 8 of 10 2012 NRC Exam

JPM P2 TASK ELEMENT 21 STANDARD 6.6.16 If Alternate Shutdown Cooling Purification is required, then Contacts Control Room perform Section 6.14, Alternate Shutdown Cooling Purification.

Comment:

EVALUATOR CUE: The control room reports that Alternate Shutdown Cooling Purification is not desired. SAT / UNSAT END OF TASK Revision 1 Page 9 of 10 2012 NRC Exam

JPM P2 APPLICANT CUE SHEET Do Not Manipulate Any Plant Components (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

Shutdown Cooling Train A is in service

Shutdown Cooling Purification Ion Exchanger A is aligned for service

RCS Hot Leg Temperature is 105°F INITIATING CUES:

The following conditions exist:

-Reactor Coolant System is at atmospheric pressure

-Normal Letdown and Charging is secured

-Sufficient room is available in the Boron Management System to flush Chemical and Volume Control System Purification Ion Exchanger(s)

The CRS directs you to place Shutdown Cooling Purification in service using Purification Ion Exchanger A in accordance with OP-009-005, Shutdown Cooling Purification, Section 6.6.

Revision 1 Page 10 of 10 2012 NRC Exam

Waterford 3 2012 NRC Exam JOB PERFORMANCE MEASURE P3 SUPS 014 AB Operation Applicant:

Examiner:

JPM P3 JOB PERFORMANCE MEASURE DATA PAGE Task: Transfer SUPS 014 AB from Alternate to Normal AC power Task Standard: All identified critical steps for aligning SUPS 014 AB from the Alternate to Normal AC alignment in accordance with OP-006-005, Inverters and Distribution has been performed correctly.

References:

OP-006-005, Inverters and Distribution. revision 306 Alternate Path: Yes Time Critical: No Validation Time: 20 mins.

K/A 062 A3.04, Operation of inverter Importance Rating 2.7 / 2.9 RO / SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 13 2012 NRC Exam

JPM P3 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-006-005, Inverters and Distribution, revision 306

==

Description:==

SUPS 014 AB will be simulated in the Alternate AC power alignment. Applicant will transfer SUPS 014 AB to the Normal AC alignment. All steps will be simulated in Switchgear Room A. No special PPE will be required for this task.

The first figure in this JPM package is a figure of the SUPS, depicting meters and the initial position of SUPS breakers. The second figure is a line diagram representation of the SUPS AB, including breakers and meter locations.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All steps for this JPM will be simulated; do not manipulate any plant components. Make all necessary communications to me. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

INITIAL CONDITIONS:

SUPS 014 AB is in the Alternate AC alignment

The inverter was isolated in accordance with OP-006-005, Inverters and Distribution, Step 6.5.2.7 INITIATING CUE:

The CRS directs you to place SUPS 014 AB in the Normal AC alignment in accordance with OP-006-005, Inverters and Distribution, Section 6.5.3 Revision 1 Page 3 of 13 2012 NRC Exam

JPM P3 M1 M2 M3 M4 INVERTER INPUT INVERTER INPUT BATTERY BATTERY VOLTAGE CURRENT CURRENT RECHARGE TIMER INVERTER HIGH-LOW INVERTER PHASE DC OUTPUT M5 M6 M7 LOCKED VOLTAGE OVERLOAD STATIC STATIC OVER SWITCH SWITCH ON TEMP AC VOLTAGE FREQUENCY UPS OUTPUT INHIBITED RESERVE CURRENT PHASE VOLTAGE AC VOLTAGE UPS OUTPUT INVERTER INVERTER BATTERY SELECT SELECT CURRENT OPERATE STANDBY RECHARGE UPS OUTPUT A BC CN INVERTER RESERVE C B AB AN CA BN LAMP STATIC SWITCH TRANSFER TEST TEST/RESET STATIC SWITCH RETRANSFER AUTO INHIBIT ID-EBKR9335-3 ID-EBKR9335-4 ID-EBKR9335-5 ID-EBKR9335-1 ID-EBKR9335-2 ALTERNATE OUTPUT BYPASS NORMAL EMERGENCY FEEDER TO PDP FEEDER FEEDER (OFF/OPEN) (OFF/OPEN) (ON/CLOSED) (OFF/OPEN) (OFF/OPEN)

Revision 1 Page 4 of 13 2012 NRC Exam

JPM P3 MCC- 311AB MCC- 312A 480 VAC 480 VAC 30 30 NORMAL FEEDER ID-EBKR9335-1 480-208/120 VAC STEPDOWN XFORMER RECTIFIER CHARGER M3 Amps EMGY FEEDER M1 Volts ID- LINE VOLTAGE EBKR9335-2 M2 Amps REGULATING SUPS XFORMER 014AB INVERTER BATTERY M2 Hz BYPASS TRANSF.

NEUTRAL M6 M5 ID-EBKR9335-3 STATIC TRANSFER Hz Volts SWITCH ALT FEEDER M7 Amps ID-OUTPUT EBKR9335- ID-4 TO PDP EBKR9335-5 BYPASS SUPS 014AB 208/120VAC 30 / PDP014AB Revision 1 Page 5 of 13 2012 NRC Exam

JPM P3 Indications METERS Item Designation Comment M1 Inverter Input Voltage Voltage reads zero until AC power is (0-150 VDC) applied to the rectifier at step 6.5.3.1.1.

M2 Inverter Input Current Current reads zero until AC power is (0-400 DC Amps) applied to the rectifier at step 6.5.3.1.1.

Current increases momentarily and then goes back to zero.

M3 Battery Current (400 amps Reads as displayed throughout evolution.

discharge to 400 amps charge)

M4 Battery Recharge Timer Reads as displayed throughout evolution.

(0-30 Hours)

M5 AC Voltage (0-250 VAC) In the Inverter position, Voltage reads zero until step 6.5.3.9 is complete.

In the UPS position, voltage reads zero until step 6.5.3.4.

M6 Frequency (57-63 Hz) Frequency reads 57 until step 6.5.3.9. Will read 60 when step 6.5.3.9 is completed M7 UPS Output Current System load current reads zero until step (0-150 Amps AC) 6.5.3.6.

INDICATOR LIGHTS Item Designation Indication I-1 Inverter Phase Locked Illuminates at step 6.5.3.9.

I-2 High-Low DC Voltage Illuminated at the start of the JPM, clears at step 6.5.3.1.

I-3 Inverter Output Overload Remains OFF during JPM.

I-4 Over temperature Remains OFF during JPM.

I-5 Static Switch Inhibited Illuminated at the start of the JPM, clears at step 6.5.3.3.

I-6 Static Switch On Reserve Clear at the start of the JPM, illuminates at step 6.5.3.4.

Revision 1 Page 6 of 13 2012 NRC Exam

JPM P3 6.5.3 Transfer SUPS 014AB from Alternate to Normal AC Power as follows:

TASK ELEMENT 1 STANDARD 6.5.3.1. If SUPS 014AB inverter has been isolated in accordance with Step referred to.

step 6.5.2.7, then perform the following:

Comment: The initial conditions state that SUPS 014AB has been isolated in accordance with step 6.5.2.7.

SAT / UNSAT TASK ELEMENT 2 STANDARD 6.5.3.1.1 Place Normal Feeder breaker, ID-EBKR9335-1 to ON. Breaker is ON.

Comment: Critical EVALUATOR CUE: Breaker will be OFF on arrival, provide cue of breaker being moved from OFF to ON. SAT / UNSAT Inverter input voltage (M1) reads as is after this step is performed.

Inverter input current (M2) reads zero.

TASK ELEMENT 3 STANDARD 6.5.3.1.2 Verify Inverter Input Voltage > 121 VDC, then place Emergency Breaker is ON.

Feeder breaker, ID-EBKR9335-2 to ON.

Comment: Critical EVALUATOR CUE: When meter checked Inverter Voltage reads as you see it. SAT / UNSAT EVALUATOR CUE: Breaker will be OFF on arrival, provide cue of breaker being moved from OFF to ON.

TASK ELEMENT 4 STANDARD Pushbutton is pressed and 6.5.3.1.3 Depress and release Inverter Operate pushbutton.

released.

Comment: Critical EVALUATOR CUE: Pushbutton moved in when depressed and popped out when released. SAT / UNSAT Revision 1 Page 7 of 13 2012 NRC Exam

JPM P3 TASK ELEMENT 5 STANDARD 6.5.3.2 Verify SUPS 014AB Static Switch Retransfer toggle switch in Verification complete.

INHIBIT.

Comment:

EVALUATOR CUE: The Static Switch Retransfer toggle switch is in INHIBIT. SAT / UNSAT TASK ELEMENT 6 STANDARD 6.5.3.3 Place SUPS 014AB Alternate Feeder breaker, ID-EBKR9335-3 Breaker is ON.

to ON.

Comment: Critical EVALUATOR CUE: Breaker will be OFF on arrival, provide cue of breaker being moved from OFF to ON. SAT / UNSAT The Static Switch Inhibited light goes OFF when this is performed.

TASK ELEMENT 7 STANDARD 6.5.3.4 Depress and release SUPS 014AB Static Switch Transfer Test Test pushbutton depressed pushbutton. and released.

Comment: Critical EVALUATOR CUE: Pushbutton moved in when depressed and popped out when released. SAT / UNSAT The Static Switch On Reserve light illuminates when this is performed.

TASK ELEMENT 8 STANDARD 6.5.3.4.1 Verify Static Switch On Reserve light Illuminates. Verification complete.

Comment:

EVALUATOR CUE: The Static Switch On Reserve light is illuminated.

SAT / UNSAT Revision 1 Page 8 of 13 2012 NRC Exam

JPM P3 TASK ELEMENT 9 STANDARD Pushbutton depressed and 6.5.3.5 Depress and release SUPS 014AB Lamp Test/Reset pushbutton.

released.

Comment: Critical EVALUATOR CUE: Pushbutton moved in when depressed and popped out when released. SAT / UNSAT TASK ELEMENT 10 STANDARD 6.5.3.5.1 Verify Static Switch On Reserve light remains Illuminated. Verification complete.

Comment:

EVALUATOR CUE: The Static Switch On Reserve light is illuminated.

SAT / UNSAT TASK ELEMENT 11 STANDARD 6.5.3.6 Place SUPS 014AB Output To PDP014AB, ID-EBKR9335-4 Breaker is ON.

breaker to ON.

Comment: Critical EVALUATOR CUE: Breaker will be OFF on arrival, provide cue of breaker being moved from OFF to ON. SAT / UNSAT TASK ELEMENT 12 STANDARD 6.5.3.7 Place SUPS 014AB Bypass breaker, ID-EBKR9335-5 to OFF. Breaker is OFF.

Comment: Critical EVALUATOR CUE: Breaker will be ON on arrival, provide cue of breaker being moved from ON to OFF. SAT / UNSAT Revision 1 Page 9 of 13 2012 NRC Exam

JPM P3 TASK ELEMENT 13 STANDARD Select Switch is verified in 6.5.3.8 Place SUPS 014AB AC Voltage Select Switch to INVERTER.

INVERTER.

Comment:

EVALUATOR CUE: AC Voltage Select Switch is in INVERTER SAT / UNSAT The AC Voltage Select Switch could be in what ever position the last watch stander left it in.

Revision 1 Page 10 of 13 2012 NRC Exam

JPM P3 Evaluator Note When applicant observes the SUPS Output Voltage meter, provide indication of zero volts.

If the applicant presses the Operate pushbutton, provide the indications provided in Task Element 14.

If the applicant does not press the Operate pushbutton, then provide the indication that the Static Switch On Reserve light is still illuminated at Task Element 16.

TASK ELEMENT 14 STANDARD 6.5.3.9 If no voltage is indicated, then depress and release SUPS 014AB Inverter Operate pushbutton, and verify the following:

Inverter Phase Locked light Illuminated Depresses the Inverter

Inverter Output voltage CN ~120 VAC (118.8 to 121.2 VAC) Operate pushbutton and

Inverter Output voltage AN ~120 VAC (118.8 to 121.2 VAC) verifies proper voltage.

Inverter Output voltage BN ~120 VAC (118.8 to 121.2 VAC)

Inverter Output frequency ~60 Hz (59.97 to 60.03 Hz)

Comment: Critical The applicant must use the multi-selector switch and move through these positions. SAT / UNSAT EVALUATOR CUE: When the applicant initially checks voltage there is no voltage indicated in any Inverter position. Once the Inverter Operate pushbutton is depressed and released the voltages indicate the values given in the step.

EVALUATOR CUE: If the applicant observes any UPS position, voltage will be as indicated.

EVALUATOR CUE: Pushbutton moved in when depressed and popped out when released.

TASK ELEMENT 15 STANDARD 6.5.3.10 Place SUPS 014AB Static Switch Retransfer toggle switch to Toggle Switch is in Auto.

AUTO.

Comment: Critical EVALUATOR CUE: Static Switch Retransfer toggle switch will be in INHIBIT at this point, cue that the switch is moved from INHIBIT to SAT / UNSAT AUTO.

Revision 1 Page 11 of 13 2012 NRC Exam

JPM P3 TASK ELEMENT 16 STANDARD 6.5.3.11 After approximately 30 seconds, depress and release SUPS Pushbutton pressed and 014AB Lamp Test/Reset pushbutton. released.

Comment: Critical EVALUATOR CUE: 30 seconds have elapsed. After this pushbutton is depressed, the Static Switch On Reserve light will extinguish. SAT / UNSAT TASK ELEMENT 17 STANDARD 6.5.3.11.1 Verify Static Switch On Reserve light Extinguished. Verification complete.

Comment:

EVALUATOR CUE: The Static Switch On Reserve light is extinguished.

SAT / UNSAT END OF TASK Revision 1 Page 12 of 13 2012 NRC Exam

JPM P3 APPLICANT CUE SHEET Do Not Manipulate Any Plant Components (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

SUPS 014 AB is in the Alternate AC alignment

The inverter was isolated in accordance with OP-006-005, Inverters and Distribution, Step 6.5.2.7 INITIATING CUE:

The CRS directs you to place SUPS 014 AB in the Normal AC alignment in accordance with OP-006-005, Inverters and Distribution, Section 6.5.3 Revision 1 Page 13 of 13 2012 NRC Exam

Appendix D Scenario Outline Form ES-D-1 Facility: Waterford 3 Scenario No.: 2 Op Test No.: 1 Examiners: Operators:

Initial Conditions: Reactor power is 60%, MOC Turnover:

Protected Train is B, AB Bus is aligned to Train B, HPSI Pump A is OOS Event Malf. Event Event No. No. Type* Description R - ATC N - BOP Lower power to 50% in accordance with OP-010-005, 1 N/A N - SRO Plant Shutdown.

Letdown Flow Control Valve, CVC-113A, fails closed C - ATC requiring entry into OP-901-112, Charging or Letdown 2 CV30A2 C - SRO Malfunction.

C - BOP Component Cooling Water Pump A trips requiring C - SRO entry into OP-901-510, Component Cooling Water 3 CC01A TS - SRO System Malfunction.

I - BOP I - SRO Channel D Excore Nuclear Instrument Safety 4 NI01H TS - SRO Channel, ENI-IJI-0001D, middle detector fails low.

Main Steam line break outside Containment, SG 1, OP-902-004, Excess Steam Demand Recovery.

5 MS13A M - All (Critical Task 1 and 2)

C-BOP Main Feedwater Isolation Valve Steam Generator 1, 6 RP08G C-SRO FW-184A fails to AUTO close on MSIS.

Component Cooling Water Surge Tank Level Switch, CC-ILS-7013A, fails low, isolating Component Cooling Water to the Reactor Coolant Pumps, requiring the I-ATC ATC to secure all running Reactor Coolant Pumps.

7 CC12E2 I-SRO (Critical Task 3)

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 2012 NRC Exam Scenario 2 D-1 Rev. 2

Scenario Event Description NRC Scenario 2 The crew assumes the shift at ~ 60% power with instructions to lower power to ~ 50% in accordance with OP-010-005, Plant Shutdown, and remove Main Feedwater Pump B from service. The plant is at 60%

due to rising vibration on Main Feedwater Pump B at > 80% power. The System Engineer reports pump vibration monitoring indicates a possible impeller imbalance. High Pressure Safety Injection Pump A is out of service and danger tagged, due to high pump bearing vibration during its quarterly IST. Since it occurred just prior to shift turnover and the AB bus is aligned to Train B, High Pressure Safety Injection Pump AB has not yet been aligned for service. The Work Management Center is working in that direction.

After the reactivity manipulation is satisfied, the in-service letdown flow control valve, CVC-113A, fails closed. The SRO should enter OP-901-112, Charging or Letdown Malfunction and implement Section E2, Letdown Malfunction, and place the backup flow control valve, CVC-113B, in-service.

After the backup letdown flow control valve has been placed in service, Component Cooling Water Pump A trips on overcurrent. The SRO should enter OP-901-510, Component Cooling Water System Malfunction, and direct the start of Component Cooling Water Pump AB to replace Component Cooling Water Pump A. The SRO should enter Technical Specification 3.7.3, TRM 3.7.3, and cascading Technical Specifications per OP-100-014, Technical Specification and Technical Requirements Compliance.

After Component Cooling Water Pump AB is running and the SRO has reviewed Technical Specifications (or at examiner discretion), Channel D Safety Excore Nuclear Instrument Middle Detector fails low resulting in DNBR and LPD Trips on Plant Protection System Channel D and Startup Channel 1 energizes. The SRO should direct Startup Channel 1 be de-energized by placing the High Volts Selector switch in the Startup Channel 1 drawer to PRIMARY. The SRO should review Technical Specification 3.3.1 and Table 3.3-1 and determine that Action 2 should be entered for Functional Units of Linear Power, DNBR - Low, Local Power Density - High, and the Core Protection Calculator. The SRO should direct that at a minimum Linear Power, DNBR - Low, and Local Power Density - High trip bistables be bypassed in Channel D. Additionally the Logarithmic Power - High channel is also inoperable but the Technical Specification does not apply in MODE 1. However, the SRO may elect to place the Logarithmic Power - High Bistable in bypass as a conservative measure because this action would be applicable within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months following a reactor trip or shutdown. The SRO should review OP-903-013, Monthly Channel Checks and Technical Specifications 3.3.3.5 and 3.3.3.6 and determine that Technical Specification 3.3.3.6, action 29 should be entered.

After the trip bistables in Plant Protection System Channel D are bypassed, a Main Steam line break outside Containment occurs on Main Steam Line 1, resulting in a reactor trip, Safety Injection Actuation Signal (SIAS), Containment Isolation Actuation Signal (CIAS) and Main Steam Isolation Signal (MSIS).

FW-184A, Feedwater Isolation Valve A fails to close automatically on the MSIS requiring the BOP to manually close the valve. The SRO should diagnose to OP-902-004, Excess Steam Demand Recovery Procedure. The crew should take action to stabilize Reactor Coolant System temperature (CRITICAL TASK 1) and pressure (CRITICAL TASK 2) when Reactor Coolant System pressure AND Core Exit Thermocouple temperatures start to rise.

During the implementation of OP-902-004, CC-ILS-7013A, Component Cooling Water Surge Tank Level Switch fails low isolating Component Cooling Water to the Reactor Coolant Pumps. The ATC should secure all running Reactor Coolant Pumps within 3 minutes (CRITICAL TASK 3). The SRO may refer to OP-901-510, Component Cooling Water System Malfunction, Attachment 1, CCW Surge Tank Level Switch Failures to verify the failed instrument.

The scenario can be terminated after the crew secures all running Reactor Coolant Pumps or at the lead examiners discretion.

2012 NRC Exam Scenario 2 D-1 Rev. 2

NRC Scenario 2 CRITICAL TASKS

1. ESTABLISH REACTOR COOLANT SYSTEM TEMPERATURE CONTROL This task is satisfied by taking action to stabilize Reactor Coolant System temperature within the limits of the Reactor Coolant System Pressure/Temperature Limits curve using Atmospheric Dump Valve 2 and establishing EFW flow to Steam Generator 2. Action to address this task should prevent lifting a Pressurizer safety (2500 psia) or Steam Generator safety (1070 psig).

2. ESTABLISH REACTOR COOLANT SYSTEM PRESSURE CONTROL This task is satisfied by taking action to stabilize RCS pressure within the limits of the Reactor Coolant System P/T curve and additionally maintain Reactor Coolant System pressure within 1500-1600 psid of the faulted steam generator. Action to address this task shall prevent lowering Subcooled Margin to <

28°F.

3. TRIP ANY REACTOR COOLANT PUMP NOT SATISFYING REACTOR COOLANT PUMP OPERATING LIMITS This task is satisfied by securing all running Reactor Coolant Pumps within 3 minutes of loss of Component Cooling Water flow. This task becomes applicable after CC-ILS-7013A fails. The time requirement of 3 minutes is based on the Reactor Coolant Pump operating limit of 3 minutes without Component Cooling Water cooling.

Scenario Quantitative Attributes

1. Total malfunctions (5-8) 6

2. Malfunctions after EOP entry (1-2) 2

3. Abnormal events (2-4) 2

4. Major transients (1-2) 1

5. EOPs entered/requiring substantive actions (1-2) 1

6. EOP contingencies requiring substantive actions (0-2) 0

7. Critical tasks (2-3) 3 2012 NRC Exam Scenario 2 D-1 Rev. 2

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

Description:

Lower Power to 50% using OP-010-005 Time Position Applicants Actions or Behavior OP-010-005,Attachment 9.1 Steps 9.1.1 - 9.1.6 NOTE Power may be stabilized at SM/CRS discretion at any point during performance of this section. The Senior Line Manager for Plant Shutdown shall be the Operations Manager or designee, or a qualified Duty Plant Manager. Performance of an Infrequently Performed Test or Evolution (IPTE) Brief shall not preclude full compliance with any Technical Specification or procedurally required Plant Shutdown.

CAUTION THE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITY.

N/A 9.1.1 If performing a planned Plant Shutdown involving power reduction of

>30%, then the Operations Manager (OM) shall evaluate the use of IPTE controls in accordance with EN-OP-116, Infrequently Performed Tests or Evolutions. At the direction of the OM the following Infrequently Performed Test or Evolutions (IPTE) controls should be complied with:

CREW 9.1.2 Prior to commencing power reduction, notify Load Dispatcher.

CREW 9.1.3 Announce to Station Personnel that a power reduction is in progress over the Plant Paging System.

CREW 9.1.4 Maintain Reactor Coolant System Tcold 536°F to 549°F during the downpower.

N/A 9.1.5 Perform Boron Equalization in accordance with Attachment 9.13, Boron Equalization.

NOTE Boron Equalization is already in progress from down power to 60%.

Revision 1

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

Description:

Lower Power to 50% using OP-010-005 Time Position Applicants Actions or Behavior NOTE (1) BSCAL is not a good indication of instantaneous power during power maneuvers.

Additionally, once the smoothing factor is applied at approximately 98% MSBSRAW (PMC PID C24631), BSCAL becomes a time weighted average of power recorded over approximately 20 minutes. The following tables list COLSS calculated powers available during power maneuvering to monitor instantaneous power:

(2) During power ascension PMC PID C24649 COLSS ASCENDING PWR TRACK (DUMOUT

18) will automatically select and display the correct power indication. During power reduction PMC PID C24650 COLSS DESCENDING PWR TRACK (DUMOUT19) will automatically select and display the correct power indication.

UFM not in service Reactor Power 95% MSBSRAW PMC PID C24631 Reactor Power <95% and 35% FWBSRAW PMC PID C24630 Reactor Power <35% BDELT PMC PID C24104 UFM in service Reactor Power 95% MSBSRAW PMC PID C24631 Reactor Power <95% and 40% USBSRAW PMC PID C24629 Reactor Power <40% and 35% FWBSRAW PMC PID C24630 Reactor Power <35% BDELT PMC PID C24104 ATC 9.1.6 Begin Reactor Coolant System boration in accordance with OP-002-005, Chemical and Volume Control to reduce Reactor power.

OP-002-005, Chemical and Volume Control System, Section 6.7, Direct Boration CAUTION (1) THIS SECTION AFFECTS REACTIVITY. THIS EVOLUTION SHOULD BE CROSS-CHECKED AND COMPLETED PRIOR TO LEAVING CP-4.

(2) AT LEAST ONE REACTOR COOLANT PUMP IN EACH LOOP SHOULD BE OPERATING PRIOR TO PERFORMING DIRECT BORATION OPERATIONS TO ENSURE PROPER CHEMICAL MIXING.

Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 1 Page 3 of 21 Event

Description:

Lower Power to 50% using OP-010-005 Time Position Applicants Actions or Behavior ATC 6.7.1 Inform SM/CRS that this Section is being performed.

NOTE When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change.

1.2.1.1 Power Defect Vs Power Level

1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD)

1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD)

1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD)

1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC (340 EFPD)

ATC 6.7.2 At SM/CRS discretion, calculate volume of Boric Acid to be added on Attachment 11.6, Calculation of Boric Acid Volume for Direct Boration or VCT Borate Makeup Mode.

ATC 6.7.3 Set Boric Acid Makeup Batch Counter to volume of Boric Acid desired.

ATC 6.7.4 Verify Boric Acid Makeup Pumps selector switch aligned to desired Boric Acid Makeup Pump A(B).

ATC 6.7.5 Place Direct Boration Valve, BAM-143, control switch to AUTO.

ATC 6.7.6 Place Makeup Mode selector switch to BORATE.

ATC 6.7.7 Verify selected Boric Acid Makeup Pump A(B) Starts.

ATC 6.7.8 Verify Direct Boration Valve, BAM-143, Opens.

Revision 1

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

Description:

Lower Power to 50% using OP-010-005 Time Position Applicants Actions or Behavior NOTE The Boric Acid Flow Totalizer will not register below 3 GPM. The Boric Acid Flow Totalizer is most accurate in the range of 10 - 25 GPM.

ATC 6.7.9 If manual control of Boric Acid flow is desired, then perform the following:

6.7.9.1 Verify Boric Acid Flow controller, BAM-IFIC-0210Y, in Manual.

6.7.9.2 Adjust Boric Acid Flow controller, BAM-IFIC-0210Y, output to

>3 GPM flow rate.

N/A 6.7.10 If automatic control of Boric Acid flow is desired, then perform the following:

6.7.10.1 Place Boric Acid Flow controller, BAM-IFIC-0210Y, in Auto.

6.7.10.2 Adjust Boric Acid Flow controller, BAM-IFIC-0210Y, setpoint potentiometer to >3 GPM flow rate.

ATC 6.7.11 Verify Boric Acid Makeup Control Valve, BAM-141, Intermediate or Open.

ATC 6.7.12 Observe Boric Acid flow rate for proper indication.

ATC 6.7.13 When Boric Acid Makeup Batch Counter has counted down to desired value, then verify Boric Acid Makeup Control Valve, BAM-141, Closed.

Examiner Note The step below is only applicable if the ATC adds acid in small batches.

NOTE Step 6.7.14 may be repeated as necessary to achieve desired total boron addition for plant conditions.

ATC 6.7.14 If additional boric acid addition is required and with SM/CRS permission, then perform the following:

6.7.14.1 Reset Boric Acid Makeup Batch Counter.

6.7.14.2 Verify Boric Acid Makeup Control Valve, BAM-141, Intermediate or Open.

6.7.14.3 Observe Boric Acid flow rate for proper indication.

6.7.14.4 When Boric Acid Makeup Batch Counter has counted down to desired value, then verify Boric Acid Makeup Control Valve, BAM-141, Closed.

Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 1 Page 5 of 21 Event

Description:

Lower Power to 50% using OP-010-005 Time Position Applicants Actions or Behavior ATC 6.7.15 Verify Boric Acid Flow controller, BAM-IFIC-0210Y, in Manual.

ATC 6.7.16 Verify both Boric Acid Flow controller, BAM-IFIC-0210Y, output and setpoint potentiometer set to zero.

ATC 6.7.17 Place Makeup Mode selector switch to MANUAL.

ATC 6.7.18 Verify Selected Boric Acid Makeup Pump A(B) Stops.

ATC 6.7.19 Verify Direct Boration Valve, BAM-143, Closed.

ATC 6.7.20 Place Direct Boration Valve, BAM-143, control switch to CLOSE.

OP-010-005, Attachment 9.1 Step 9.1.7 -9.1.8 CAUTION CONTROL RODS SHOULD NEVER BE WITHDRAWN OR MANUALLY INSERTED EXCEPT IN A DELIBERATE CAREFULLY CONTROLLED MANNER WHILE CLOSELY MONITORING THE REACTORS RESPONSE.

ATC 9.1.7 Maintain ASI using CEA Reg. Group 5, 6 or Group P Control Element Assemblies in accordance with Attachment 9.9, Axial Shape Control Guidelines. (Refer to T.S. 3.1.3.6).

BOP 9.1.8 When Average Reactor Coolant Temperature (Tavg) begins to drop, then reduce Generator load to match Tavg and Reference Temperature (Tref) in accordance with OP-005-007, Main Turbine and Generator.

OP-005-007, Main Turbine and Generator, Section 6.2 BOP 6.2.1 To change Load/Rate perform the following:

6.2.1.1 Depress LOAD/RATE MW/MIN pushbutton.

BOP 6.2.1.2 Depress appropriate numerical pushbuttons for desired load rate.

BOP 6.1.2.3 Depress ENTER pushbutton.

Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 1 Page 6 of 21 Event

Description:

Lower Power to 50% using OP-010-005 Time Position Applicants Actions or Behavior NOTE Prior to changing Reference Demand, Main Turbine load must not be changing.

BOP 6.2.2 To change Main Turbine load, perform the following:

6.2.2.1 Depress REF pushbutton.

BOP 6.2.2.2 Depress appropriate numerical pushbuttons for desired MW load.

BOP 6.2.2.3 Depress ENTER pushbutton.

BOP 6.2.2.4 Depress GO pushbutton.

BOP 6.2.2.5 Verify Turbine load change stops at the desired MW load.

OP-010-005,Attachment 9.1 Steps 9.1.16 - 9.1.17 SRO 9.1.16 Remove Polishers from service to maintain system pressure in accordance with OP-003-031, Condensate Polisher/Backwash Treatment.

BOP 9.1.17 When Reactor power is approximately 55%, then remove one Main Feedwater Pump from service in accordance with OP-003-033, Main Feedwater.

Examiner Note This event is complete when the Reactivity Manipulation is met.

OR As directed by the Lead Evaluator.

Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 2 Page 7 of 21 Event

Description:

Letdown Flow Control Valve, CVC-113A, fails closed Time Position Applicants Actions or Behavior ATC Recognize and report indications of failed Letdown Flow Control Valve.

Alarms:

Letdown Flow Hi/Lo (Cabinet G, C-1)

Letdown HX Outlet Pressure Lo (Cabinet G, B-2)

Indications

Letdown flow goes to 0 gpm

CVC-113A indicates closed

Letdown Flow Control valve not responding to changes in controller output

Abnormal Charging AND Letdown flow mismatch.

Pressurizer level changing SRO Enter and direct the implementation of OP-901-112, Charging or Letdown Malfunction.

OP-901-112, Section E0, General BOP 1. Stop turbine load changes.

N/A 2. IF malfunction is due to failure of the Pressurizer Level Control System, THEN go to OP-901-110, PRESSURIZER LEVEL CONTROL MALFUNCTION.

N/A 3. IF a Charging Malfunction is indicated, THEN go to Subsection E1, Charging Malfunction.

SRO 4. IF a Letdown Malfunction is indicated, THEN go to Subsection E2, Letdown Malfunction.

OP-901-112, Section E2, Letdown Malfunction ATC 1. IF necessary, THEN maintain Pressurizer level by placing LETDOWN FLOW CONTROL VALVES controller (RC-IHIC-0110) in MAN, and control manually.

NOTE THE ATC may take manual control of the controller but the letdown valve will not respond.

Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 2 Page 8 of 21 Event

Description:

Letdown Flow Control Valve, CVC-113A, fails closed Time Position Applicants Actions or Behavior NOTE If all Charging Pumps are secured, then LETDOWN STOP VALVE (CVC 101) will close on high REGEN HX TUBE OUTLET temperature if RCS is 470°F.

ATC 2. Operate Charging Pumps as necessary to maintain Pressurizer level in accordance with Attachment 1, Pressurizer Level Versus Tave Curve.

NOTE This should not be applicable. If the crew delays taking action due to the failure, Pressurizer level will rise and they may choose to take action.

SRO/ATC 3. IF Pressurizer level falls below the minimum level for operation of Attachment 1, THEN perform the following:

3.1. Trip the Reactor.

3.2. Manually initiate Safety Injection Actuation.

3.3. Go to OP-902-000, STANDARD POST TRIP ACTIONS.

NOTE This should not be applicable.

N/A 4. IF a leak exists in Letdown System, THEN attempt to locate AND isolate leak.

N/A 5. IF leak has been isolated, THEN re-establish Letdown in accordance with OP-002-005, CHEMICAL AND VOLUME CONTROL.

ATC 6. IF the in service Letdown Flow Control valve (CVC 113A) OR (CVC 113B) is NOT controlling, THEN place standby Letdown Flow Control valve in service as follows:

NOTE To minimize thermal transients in the system, Letdown and Charging flows should be started as close together as possible.

ATC 6.1 IF restoring Letdown, THEN verify at least one charging pump in operation.

ATC 6.2 IF necessary to maintain Letdown Backpressure, THEN Letdown Backpressure Controller (CVC-IPIC-0201) may be controlled in MAN.

ATC 6.3 Place Letdown Flow Control Valve Selector switch to BOTH.

SRO 6.4 Verify open standby Letdown Flow Cntrl Vlv A(B) Outlet Isolation (CVC 114A) OR (CVC 114B). (Coordinates with NAO to perform)

Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 2 Page 9 of 21 Event

Description:

Letdown Flow Control Valve, CVC-113A, fails closed Time Position Applicants Actions or Behavior SRO 6.3 Slowly open standby Letdown Flow Control Valve Inlet Isolation (CVC 111A) OR (CVC 111B). (Coordinates with NAO to perform)

SRO 6.4 Close in service Letdown Flow Cntrl Vlv A(B) Outlet Isolation (CVC 114A) OR (CVC 114B). (Coordinates with NAO to perform)

ATC 6.5 Position Letdown Flow Control Valve Selector switch to select operable flow control valve placed in service.

ATC 6.6 IF letdown is still in service and Letdown Flow Control valve operates properly, THEN place Letdown Flow Controller (RC-IHIC-0110) in AUTO.

ATC 6.7 Close in service Letdown Flow Cntrl Vlv A(B) Outlet Isolation (CVC 114A) OR (CVC 114B).

ATC 6.8 Position Letdown Flow Control Valve Selector switch to select operable flow control valve placed in service.

ATC 6.9 IF letdown is still in service and Letdown Flow Control valve operates properly, THEN place Letdown Flow Controller (RC-IHIC-0110) in AUTO.

Examiner Note This event is complete when Letdown Flow Control Valve is in Service Or As directed by the Lead Evaluator Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 3 Page 10 of 21 Event

Description:

Component Cooling Water Pump A trips Time Position Applicants Actions or Behavior BOP Recognize and report indications of tripped CCW Pump.

Alarms:

CCW PUMP A TRIP/TROUBLE (Cabinet M, B-2 )

RCP 1A CCW FLOW LO (Cabinet H, H-3)

RCP 1B CCW FLOW LO (Cabinet H, H-5)

RCP 2A CCW FLOW LO (Cabinet H, H-7)

RCP 2B CCW FLOW LO (Cabinet H, H-10)

Indications

Amber trip/trouble light on CCW Pump A control switch

CCW System pressure abnormally low and dropping

CCW System and component flows abnormally low NOTE Based on how long the crew takes to align CCW Pump AB, red RCP Low Flow alarms may come in on CP-2. This should be called out by the ATC.

SRO Enter and direct the implementation of OP-901-510, Component Cooling Water System Malfunction.

OP-901-510, Component Cooling Water System Malfunction, Section E0 N/A 1. IF ANY of the following occur, THEN GO TO Subsection E1, System Leakage:

CCW Surge Tank level dropping

CCW Dry Cooling Towers isolated due to low CCW Surge Tank level

CMU-226, WATER STORAGE MAKEUP CCW SURGE TANK, cycling frequently

CCW header isolates due to low CCW Surge Tank level

Local observation of CCW leak reported to Control Room

2. IF ANY of the following occur, THEN GO TO Subsection E2, Loss of CCW Pump(s):

CCW system OR component flows low

Amber trip/trouble light on CCW PUMP A(B)(AB) Control Switch Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 3 Page 11 of 21 Event

Description:

Component Cooling Water Pump A trips Time Position Applicants Actions or Behavior OP-901-510, Component Cooling Water System Malfunction, Section E2

1. IF CCW is lost to in-service Shutdown Cooling train, THEN implement OP-901-131, SHUTDOWN COOLING MALFUNCTION, AND perform concurrently with this procedure.

N/A 2. IF Component Cooling Water Pump AB has tripped, THEN Start standby CCW Pump.

2.1 Place CCW ASSIGNMENT Switch to NORM Position.

BOP 3. IF Component Cooling Water Pump A has tripped, THEN align CCW Pump AB for Operation as follows:

3.1 Position CCW ASSIGNMENT switch to position A.

BOP 3.2 Verify Open the following valves:

CC-126A/CC-114A CCW SUCT & DISCH HEADER TIE VALVES AB TO A

CC-127A/CC-115A CCW SUCT & DISCH HEADER TIE VALVES AB TO A BOP 3.3 Start CC-0001AB, Component Cooling Water Pump AB.

SRO 3.4 Evaluate AB Electrical Bus alignment for Technical Specification Operability requirements.

With the AB Safety Bus aligned to Train B, credit cannot be taken for CCW Pump AB

The SRO should enter Tech Spec 3.7.3, TRM 3.7.3 and Cascading Tech Specs per OP-100-014.

This includes a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months requirement to verify off site electrical power. The CRS should vocalize this requirement and assign the OP-903-066 surveillance to either the BOP or ATC operator. The BOP is preferred.

Cascading Tech Specs also includes a 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months requirement to verify components that rely on Train B safety power operable per 3.8.1.1.d.

Examiner Note This event is complete when the SRO has addressed Technical Specifications OR As directed by the Lead Evaluator Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 4 Page 12 of 21 Event

Description:

Channel D ENI Safety Channel middle detector fails low Time Position Applicants Actions or Behavior Recognize and report indications of Log Channel Failure.

Alarms (The first 3 alarms are power dependent and may not actuate)

RPS CHANNEL TRIP LOCAL PWR DENSITY HI (Cabinet K, A-11)

LOCAL POWER DENSITY HI PRETRIP B/D (Cabinet K, C-11)

RPS CHANNEL D TROUBLE (Cabinet K, H-18)

STARTUP CHANNEL 1 NEUTRON FLUX HI (Cabinet H, K-3)

RCS BORON CHNL 1 DILUTION HI (Cabinet G, L-3)

Indications

Startup Channel 1 energized CP-2, RRS 1 Cabinet

Channel D Log Power Indicator on CP-7 failed low

Channel D Linear Power recorder reading low on CP-7 SRO Directs BOP to select High Volts Select Switch in Startup Channel 1 drawer to non-faulted channel (PRIMARY).

OP-500-008, Attachment 4.83, STARTUP CHANNEL 1 NEUTRON FLUX HI BOP 1. Either failure of log channel governing 5.3X10-6% relay or failure of 5.3X10-6% relay.

1.1 If reactor power is > 5.3X10-6% then select Primary (Log Channel C) or Alternate (Log Channel D) as appropriate in Startup Channel 1 drawer to de-energize Startup Channel 1.

N/A 1.2 If reactor power < 5.3X10-6% then allow continued operation of Startup Channel 1.

Examiner Note All BOP manipulations for OP-009-007 are located at CP-10 except as noted.

OP-009-007, Plant Protection System ,Section 6.2, Trip Channel Bypass Operation SRO 6.2.1 Refer to Attachment 11.11, PPS Bistable Bypass Chart to assist in determination of Trip Channels requiring placement in bypass.

Determines the following bistables are affected and need to be bypassed:

1 - HI LN POWER

2 - HI LOG POWER+

3 - HI LOCAL POWER

4 - LOW DNBR Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 4 Page 13 of 21 Event

Description:

Channel D ENI Safety Channel middle detector fails low Time Position Applicants Actions or Behavior NOTE + Hi Log Power is not required to be bypassed in MODE 1. However, the failed detector supplies the Log Power Channel which is applicable in MODE 2 and below. If a reactor trip were to occur, action would be required to bypass the channel in one hour. It is normal practice to bypass the channel for this reason.

SRO Directs BOP to bypass the HI LN POWER, HI LOG POWER+, HI LOCAL POWER, and LOW DNBR bistables in PPS Channel D within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months in accordance with OP-009-007, Plant Protection System.

BOP 6.2.2 To place a bistable in or remove a bistable from bypass, go to Attachment 11.10, Trip Channel Bypass Operation.

BOP 11.10.1 To Bypass a Trip Channel, perform the following:

11.10.1.1 Circle the bistable numbers selected for bypass under Step 11.10.1.4.

BOP 11.10.1.2 Check desired Trip Channel is not Bypassed on another PPS Channel.

BOP 11.10.1.3 Open key-locked portion of BCP in desired PPS Channel.

BOP 11.10.1.4 Depress Bypass push buttons for the desired Trip Channels BOP 11.10.1.5 Check all selected bistable Bypass push buttons remain in a Depressed state.

BOP 11.10.1.6 Check all selected bistable Bypass lights Illuminate on BCP for the desired Trip Channels.

CREW 11.10.1.7 Check all selected bistable Bypass lights Illuminate on ROM for the desired Trip Channels. (Verifies correct bistables lit on CP-7 PPS Channel D Remote Operator Module)

SRO Reviews the following Technical Specifications and determines applicable actions:

3.3.1 - Action 2

3.3.3.5 - No action required

3.3.3.6.a - Action 29 Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 4 Page 14 of 21 Event

Description:

Channel D ENI Safety Channel middle detector fails low Time Position Applicants Actions or Behavior Examiner Note This event is complete when the SRO has evaluated Technical Specifications and the PPS Trip Bistables are bypassed.

OR As directed by the Lead Evaluator Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 5 / 6/ 7 Page 15 of 21 Event

Description:

Main Steam line break outside Containment, SG 1, FW-184A fails to AUTO close on MSIS/ CC-ILS-7013A fails low, isolating Component Cooling Water to the Reactor Coolant Pumps Time Position Applicants Actions or Behavior ATC / BOP Recognize and report indications of a Main Steam Line Break.

Alarms (The fifth annunciator may come in if not already in from the previous event)

EXCORE /CPC CHNL D POWER DEVIATION (Cabinet K, K-14)

EXCORE /CPC CHNL B POWER DEVIATION (Cabinet K, K-12)

EXCORE /CPC CHNL C POWER DEVIATION (Cabinet K, K-13)

EXCORE /CPC CHNL A POWER DEVIATION (Cabinet K, K-11)

LOCAL POWER DENSITY HI PRETRIP B/D (Cabinet K, C-11)

Indications

Lowering Steam Generator Pressure CP-1, CP-8

Lowering Steam Generator Level CP-1, CP-8

Lowering Reactor Coolant System temperatures Tavg, Th, Tc CP-2, CP-7

Reactor Power Rising CP-2, CP-7 SRO Directs a manual reactor trip.

Note The SRO may also direct a manual actuation of SIAS and CIAS. If not the SRO should direct Emergency Boration per OP-901-103, Emergency Boration due to the uncontrolled cooldown. The following steps are applicable after the reactor is tripped and the crew is performing Standard Post Trip Actions.

OP-901-103, Emergency Boration

1. Place Makeup Mode selector switch to MANUAL.

Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 5 / 6/ 7 Page 16 of 21 Event

Description:

Main Steam line break outside Containment, SG 1, FW-184A fails to AUTO close on MSIS/ CC-ILS-7013A fails low, isolating Component Cooling Water to the Reactor Coolant Pumps Time Position Applicants Actions or Behavior

2. Align borated water source by performing one of the following (a. or b.):

a. Initiate Emergency Boration using Boric Acid Pump as follows:

Open Emergency Boration Valve, BAM-133.

Start one Boric Acid Pump.

Close recirc valve for Boric Acid Pump started:

BAM-126A Boric Acid Makeup Pump Recirc Valve A or

BAM-126B Boric Acid Makeup Pump Recirc Valve B or

b. Initiate Emergency Boration using Gravity Feed as follows:

Open the following Boric Acid Makeup Gravity Feed valves:

BAM-113A Boric Acid Makeup Gravity Feed Valve A

BAM-113B Boric Acid Makeup Gravity Feed Valve B

3. Close VCT Disch Valve, CVC-183.

4. Verify at least one Charging Pump operating and Charging Header flow 40 GPM.

OP-902-000, Standard Post Trip Actions ATC 1. Determine Reactivity Control acceptance criteria are met:

a. Check reactor power is dropping.

b. Check startup rate is negative.

c. Check less than TWO CEAs are NOT fully inserted.

BOP 2. Determine Maintenance of Vital Auxiliaries acceptance criteria are met:

a. Check the Main Turbine is tripped:

Governor valves closed

Throttle valves closed BOP b. Check the Main Generator is tripped:

GENERATOR BREAKER A tripped

GENERATOR BREAKER B tripped

EXCITER FIELD BREAKER tripped Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 5 / 6/ 7 Page 17 of 21 Event

Description:

Main Steam line break outside Containment, SG 1, FW-184A fails to AUTO close on MSIS/ CC-ILS-7013A fails low, isolating Component Cooling Water to the Reactor Coolant Pumps Time Position Applicants Actions or Behavior BOP c. Check station loads are energized from offsite electrical power as follows:

Train A

A1, 6.9 KV non safety bus

A2, 4.16 KV non safety bus

A3, 4.16 KV safety bus

A-DC electrical bus

A or C vital AC Instrument Channel Train B

B1, 6.9 KV non safety bus

B2, 4.16 KV non safety bus

B3, 4.16 KV safety bus

B-DC electrical bus

B or D vital AC Instrument Channel ATC 3. Determine RCS Inventory Control acceptance criteria are met:

a. Check that BOTH the following conditions exist:

Pressurizer level is 7% to 60%

Pressurizer level is trending to 33% to 60%

b. Check RCS subcooling is greater than or equal to 28ºF.

NOTE This safety function may or may not be met, depending on the speed the crew is working Standard Post Trip Actions. Either way, there are no contingencies necessary for this step.

ATC 4. Determine RCS Pressure Control acceptance criteria are met by checking that BOTH of the following conditions exist:

Pressurizer pressure is 1750 psia to 2300 psia

Pressurizer pressure is trending to 2125 psia to 2275 psia SRO/ATC 4.2 IF pressurizer pressure is less than 1684 psia, THEN verify the following have initiated.

SIAS

CIAS ATC If directed by SRO, initiate Safety Injection Actuation (SIAS), Main Steam Isolation (MSIS) and Containment Isolation Actuation (CIAS) at CP-7.

Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 5 / 6/ 7 Page 18 of 21 Event

Description:

Main Steam line break outside Containment, SG 1, FW-184A fails to AUTO close on MSIS/ CC-ILS-7013A fails low, isolating Component Cooling Water to the Reactor Coolant Pumps Time Position Applicants Actions or Behavior ATC 4.3 IF pressurizer pressure is less than 1621 psia, THEN verify no more than two RCPs are operating ATC 5. Determine Core Heat Removal acceptance criteria are met:

a. Check at least one RCP is operating.

b. Check operating loop T is less than 13ºF.

c. Check RCS subcooling is greater than or equal to 28ºF.

BOP 6. Determine RCS Heat Removal acceptance criteria are met:

a. Check that at least one steam generator has BOTH of the following:

Steam generator level is 5% to 80% NR

Main Feedwater is available to restore level within 50%-70%

NR.

NOTE The contingency for this step, since there will be a Main Steam Isolation Signal, is to verify Emergency Feedwater is available. This does not require a manual initiation of EFAS.

ATC b. Check RCS TC is 530 ºF to 550 ºF SRO b2. IF RCS TC is less than 530 ºF, THEN perform the following:

IF RCS TC is being controlled by an ESD, THEN REFER TO Appendix 13, "Stabilize RCS Temperature" and stabilize RCS temperature using the least affected steam generator.

NOTE Appendix 13 directs steps to address PTS after Representative CET temperature and Pressurizer pressure have both started to rise. The steps are also contained in the excess steam demand recovery procedure.

BOP c. Check steam generator pressure is 885 psia to 1040 psia.

BOP c1. IF steam generator pressure is less than 885 psia, THEN perform ALL of the following:

1) Verify steam bypass valves are closed.

2) Verify ADVs are closed.

c2. IF steam generator pressure is less than or equal to 666 psia, THEN verify MSIS is initiated.

NOTE When MSIS has initiated the BOP should verify that both MSIVs and both MFIVs, FW-184 A(B) close. FW-184A does not close automatically requiring BOP action to close FW-184A.

Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 5 / 6/ 7 Page 19 of 21 Event

Description:

Main Steam line break outside Containment, SG 1, FW-184A fails to AUTO close on MSIS/ CC-ILS-7013A fails low, isolating Component Cooling Water to the Reactor Coolant Pumps Time Position Applicants Actions or Behavior BOP d. Check Feedwater Control in Reactor Trip Override:

MAIN FW REG valves are closed

STARTUP FW REG valves are 13% to 21% open

Operating main Feedwater pumps are 3800 rpm to 4000 rpm NOTE With a MSIS, MAIN FW REG valves and STARTUP FW REG valves will be closed. Both MFW Pumps will be coasting down.

BOP e. Reset moisture separator reheaters, and check the temperature control valves closed.

ATC 7. Determine Containment Isolation acceptance criteria are met:

a. Check containment pressure is less than 16.4 psia.

b. Check NO containment area radiation monitor alarms OR unexplained rise in activity.

c. Check NO steam plant activity monitor alarms OR unexplained rise in activity.

BOP 8 Determine Containment Temperature and Pressure Control acceptance criteria are met:

a. Check containment temperature is less than or equal to 120ºF.

b. Check containment pressure is less than 16.4 psia.

N/A 9. IF ALL safety function acceptance criteria are met, AND NO contingency actions were performed, THEN GO TO OP-902-001, "Reactor Trip Recovery" procedure.

SRO 10. IF ANY safety function acceptance criteria are NOT met, OR ANY contingency action was taken, THEN GO TO Appendix 1, "Diagnostic Flowchart.

"Proper use of chart will result in use of OP-902-004, Excess Steam Demand Recovery BOP Secure AH-12 A or B at CP-18 on SRO direction after initiation of SIAS.

Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 5 / 6/ 7 Page 20 of 21 Event

Description:

Main Steam line break outside Containment, SG 1, FW-184A fails to AUTO close on MSIS/ CC-ILS-7013A fails low, isolating Component Cooling Water to the Reactor Coolant Pumps Time Position Applicants Actions or Behavior SRO After Excess Steam Demand is identified, direct ATC and BOP to monitor for the trigger points for the need to stabilize Reactor Coolant System temperature.

Critical parameters are Pressurizer pressure rising and Reactor Coolant System Representative CET temperature rising.

Steps for stabilizing Reactor Coolant System temperature following an excess steam demand are contained in 2 procedures.

Appendix 13 is used if the critical parameters are both rising before the SRO has entered OP-902-004, Excess Steam Demand Recovery.

Step 16 of OP-902-004 is used if both parameters start rising after the crew has entered OP-902-004.

CRITICAL TASK ESTABLISH REACTOR COOLANT SYSTEM TEMPERATURE CONTROL This task is satisfied by taking action to stabilize Reactor Coolant System temperature within the limits of the Reactor Coolant System Pressure/Temperature Limits curve using Atmospheric Dump Valve 2 and establishing EFW flow to Steam Generator 2. Action to address this task should prevent lifting a Pressurizer safety (2500 psia) or Steam Generator safety (1070 psig).

BOP When directed by the SRO to take action to stabilize Reactor Coolant System temperature:

Place the Atmospheric Dump Valve for Steam Generator 2 to manual and fully open Atmospheric Dump Valve 2.

Manually initiate Emergency Feedwater Actuation Signal for Steam Generator 2.

Place Emergency Feedwater Flow Control Valve to manual and commence feeding Steam Generator 2.

CRITICAL TASK ESTABLISH REACTOR COOLANT SYSTEM PRESSURE CONTROL This task is satisfied by taking action to stabilize RCS pressure within the limits of the Reactor Coolant System P/T curve and additionally maintain Reactor Coolant System pressure within 1500-1600 psid of the faulted steam generator. Action to address this task shall prevent lowering Subcooled Margin to < 28°F.

Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 5 / 6/ 7 Page 21 of 21 Event

Description:

Main Steam line break outside Containment, SG 1, FW-184A fails to AUTO close on MSIS/ CC-ILS-7013A fails low, isolating Component Cooling Water to the Reactor Coolant Pumps Time Position Applicants Actions or Behavior ATC When directed by the SRO to take action to stabilize Reactor Coolant System temperature:

IF Reactor Coolant System pressure is 1500 psia, THEN stabilize Reactor Coolant System pressure at a value not to exceed 1600 psid between the Reactor Coolant System and the lowest SG pressure.

IF Reactor Coolant System pressure is < 1500 psia, THEN stabilize Reactor Coolant System pressure at > HPSI shutoff head (1500-1600 psia).

Examiner Note Direct Simulator Operator to initiate Trigger 5 CRITICAL TASK TRIP ANY RCP NOT SATISFYING RCP OPERATING LIMITS This task is satisfied by securing all RCPs within 3 minutes of loss of CCW flow. This task becomes applicable after CC-ILS-7013A fails. The time requirement of 3 minutes is based on the RCP operating limit of 3 minutes without CCW cooling.

BOP Reports that the A to AB CCW Loop Isolations have closed. Reports RCP 1A, 2A, 1B, and 2B CCW Lost alarms on CP-18 ATC Momentarily places running Reactor Coolant Pump control switches on CP-2 to STOP and verifies the RCP secures.

Examiner Note This scenario is complete after Reactor Coolant System temperature and pressure have been stabilized and all RCPs are secured OR As directed by the Lead Evaluator.

Revision 1

Appendix D Scenario Outline Form ES-D-1 Facility: Waterford Scenario No.: 3 Op Test No.: 1 Examiners: Operators:

Initial Conditions: ~ 4% Reactor Power, MOC Turnover:

Protected Train is B, AB Bus is aligned to Train B, Raise power to ~ 10% to roll the Main Turbine Event Malf. Event Event No. No. Type* Description Secure the Auxiliary Feedwater Pump and raise power R - ATC to 10% to roll the Main Turbine in accordance with N - BOP OP-010-003, Plant Startup and OP-010-004, Power 1 N/A N - SRO Operations.

Plant Protection System Channel D Containment I - BOP Pressure (CIAS), CB-IPI-6701SMD, fails high I - SRO requiring Technical Specification entry and bypass of 2 CH08E1 TS - SRO channel trip bistables.

C - ATC Charging Pump B trips on overcurrent requiring C - SRO implementation of OP-901-112, Charging or Letdown 3 CV01B TS - SRO Malfunction.

Startup Feedwater Regulating Valve 1 fails closed C - BOP requiring implementation of OP-901-201, Feedwater 4 FW20A2 C - SRO Control Malfunction Large RCS Cold Leg break requiring implementation RC23A of OP-902-000, Standard Post Trip Actions and OP-L_L10 902-002, Loss of Coolant Accident Recovery 5 L_M10 M - All Procedure.

RP05A3 RP05B3 RP05C3 I - ATC Containment Spray fails to AUTO Actuate requiring 6 RP05D3 I - SRO manual actuation. (Critical Task 1 and 2)

Main Steam Line 2 Break Inside Containment requiring entry into OP-902-008, Functional Recovery 7 MS11B M - All Procedure.

C - BOP Containment Spray Pump A trips requiring action to 8 CS01A C - SRO close CS-125A.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 2012 NRC Exam Scenario 3 D-1 Rev 2

Scenario Event Description NRC Scenario 3 The crew assumes the shift at ~ 4% power with instructions to raise power to 10% to roll the Main Turbine. All requirements have been met to change modes from MODE 2 to MODE 1. The Shift Manager has given permission to change modes. The SRO should direct raising power using Control Element Assemblies and/or dilution in accordance with OP-010-003, Plant Startup and OP-010-004, Power Operations.

After the reactivity manipulation has been satisfied, CB-IPI-6701SMD, Containment Pressure (CIAS) fails high. The SRO should review Technical Specifications 3.3.1 and 3.3.2. Per Table 3.3-1 under Containment Pressure - High (Functional Unit 6) the SRO should enter Technical Specification 3.3.1 action 2. Per Table 3.3-3 under Functional Units 1b (Safety Injection, Containment Pressure-High), 3b (Containment Isolation, Containment Pressure-High), and 4c (Main Steam Line Isolation, Containment Pressure High) the SRO should enter Tech 3.3.2 action 13. The SRO should direct the BOP to bypass the Containment Pressure High (RPS) and Containment Pressure High (ESF) trip bistables in PPS Channel D within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . The BOP should bypass the trip bistables in accordance with OP-009-007, Plant Protection System.

After the trip bistables have been placed in bypass, Charging Pump B trips on overcurrent. The SRO should implement OP-901-112, Charging or Letdown Malfunction, Section E1, Charging Malfunction. The SRO should direct the ATC to start a standby charging pump after verifying a suction path available or isolate Letdown using CVC-101, Letdown Stop Valve. If Letdown is isolated, Charging and Letdown will be re-initiated using Attachment 2 of OP-901-112. The SRO should review and enter Technical Specification 3.1.2.4 and Technical Requirement Manual 3.1.2.4. Technical Specification 3.1.2.4 may be exited after aligning Charging Pump AB to replace Charging Pump B. However, Technical Requirement Manual 3.1.2.4 should not be exited while Charging Pump B remains inoperable.

After Charging and Letdown are re-established, FW-166A, Startup Feedwater Regulating Valve 1 fails closed. The SRO should direct the BOP to match Feed and Steam Flows to SG 1 by manually throttling open FW-173A, Feedwater Regulating Valve 1. The SRO should implement OP-901-201, Steam Generator Level Control Malfunction, Attachment 1, General Actions.

After the BOP has control of SG 1 level, an RCS leak occurs on RCS Cold Leg 1A that progresses rapidly to a Large Break Loss of Coolant Accident. A Seismic Event Annunciator will come in at the time of the break. When Containment Pressure exceeds the Containment Spray (CSAS) setpoint, Containment Spray fails to actuate. The ATC should manually initiate Containment Spray (CRITICAL TASK 1) and secure any running Reactor Coolant Pumps (CRITICAL TASK 2). The SRO should implement OP-902-000, Standard Post Trip Actions and diagnose to OP-902-002, Loss of Coolant Accident Recovery Procedure.

After the crew diagnoses to OP-902-002, Main Steam Line 2 breaks inside Containment. Containment Spray Pump A will trip on overcurrent. The SRO should either go to OP-902-009 Appendix 1, Diagnostics Flowchart and diagnose to OP-902-008, Functional Recovery OR go directly to the procedure based on two events in progress per OP-100-017, Emergency Operating Procedures Implementation Guide. When the SRO performs prioritization Containment Isolation (CI-1) should be the highest priority. (CRITICAL TASK 3)

The scenario can be terminated after the CRS has performed prioritization of Safety Functions and implements the first success path or at the lead examiners discretion.

2012 NRC Exam Scenario 3 D-1 Rev 2

NRC Scenario 3 CRITICAL TASKS

1. ESTABLISH CONTAINMENT TEMPERATURE AND PRESSURE CONTROL This task is satisfied by manually initiating Containment Spray Actuation Signal prior to exiting OP-902-000, Standard Post Trip Actions or Containment pressure exceeds 44 PSIG. This task becomes applicable after Containment Pressure rises above 17.7 PSIA. OP-902-000, Standard Post Trip Actions, directs this activity to satisfy the Containment Pressure and Temperature Control safety function.

2. TRIP ANY RCP NOT SATISFYING RCP OPERATING LIMITS This task is satisfied by securing all RCPs within 3 minutes of loss of Component Cooling Water flow. This task becomes applicable after Containment Spray is initiated. The time requirement of 3 minutes is based on the Reactor Coolant Pump operating limit of 3 minutes without Component Cooling Water cooling.

3. ESTABLISH CONTAINMENT ISOLATION This task is satisfied by prioritizing CI-1 as Priority 1 after performing Step 11 of OP-902-008, Functional Recovery. This task becomes applicable after the Main Steam Line Break occurs.

Scenario Quantitative Attributes

1. Total malfunctions (5-8) 7

2. Malfunctions after EOP entry (1-2) 3

3. Abnormal events (2-4) 2

4. Major transients (1-2) 2

5. EOPs entered/requiring substantive actions (1-2) 1

6. EOP contingencies requiring substantive actions (0-2) 1

7. Critical tasks (2-3) 3 2012 NRC Exam Scenario 3 D-1 Rev 2

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 1 Page 1 of 21 Event

Description:

Raise power to 10% to roll the Main Turbine Time Position Applicants Actions or Behavior OP-003-035, Auxiliary Feedwater, Section, 7.0 SRO Directs the BOP to secure the Auxiliary Feedwater Pump in accordance with OP-003-035, Auxiliary Feedwater.

BOP 7.1.1 Secure Auxiliary Feedwater Pump.

BOP 7.1.2 Place Auxiliary Feedwater Controller, FW-IFIC-8202, in Manual (MAN).

BOP 7.1.2.1 Set controller to minimum setting.

BOP 7.1.3 Open Auxiliary Feedwater Pump Discharge Pressure Cntrl, AFW-125.

OP-010-003, Plant Startup, Attachment 9.4 ATC 9.4.62 Raise Reactor power to 6% Calibrated Nuclear Power (PID 171) by CEA withdrawal or boron dilution.

ATC Commences adding PMU per reactivity plan per OP-002-005, Chemical and Volume Control.

OP-002-005, Section 6.9, VCT Makeup Using the Dilute Makeup Mode CAUTION THIS SECTION AFFECTS REACTIVITY. THIS EVOLUTION SHOULD BE CROSS-CHECKED AND COMPLETED PRIOR TO LEAVING CP-4.

6.9.1 Inform SM/CRS that this Section is being performed.

Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 1 Page 2 of 21 Event

Description:

Raise power to 10% to roll the Main Turbine Time Position Applicants Actions or Behavior NOTE When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change.

1.2.1.1 Power Defect Vs Power Level

1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (< 30 EFPD)

1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD)

1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD)

1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC (340 EFPD) 6.9.2 At SM/CRS discretion, calculate volume of Primary Makeup water to be added on Attachment 11.7, Calculation of Primary Makeup Water Volume for Direct Dilution or VCT Dilute Makeup Mode.

6.9.3 Set Primary Makeup Water Batch Counter to volume of Primary Makeup water desired.

6.9.4 Place Makeup Mode selector switch to DILUTE.

6.9.5 Open VCT Makeup Valve, CVC-510.

NOTE The Dilution Flow Totalizer will not register below 5 GPM. The Dilution Flow Totalizer is most accurate at >10 GPM.

CAUTION DILUTION SHALL IMMEDIATELY BE STOPPED IF PRE-POWER DEPENDENT INSERTION LIMIT (H-9, CABINET H) ALARM IS INITIATED OR ANY UNEXPECTED REACTIVITY CHANGE OCCURS.

6.9.6 If manual control of Primary Makeup Water flow is desired, then perform the following:

6.9.6.1 Verify Primary Makeup Water Flow controller, PMU-IFIC-0210X, in Manual.

6.9.6.2 Adjust Primary Makeup Water Flow controller, PMU-IFIC-0210X, output to > 5 GPM flow rate.

Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 1 Page 3 of 21 Event

Description:

Raise power to 10% to roll the Main Turbine Time Position Applicants Actions or Behavior N/A 6.9.7 If automatic control of Primary Makeup Water flow is desired, then perform the following:

6.9.7.1 Place Primary Makeup Water Flow controller, PMU-IFIC-0210X, in Auto.

6.9.7.2 Adjust Primary Makeup Water Flow controller, PMU-IFIC-0210X, setpoint potentiometer to > 5 GPM flow rate.

6.9.8 Verify Primary Makeup Water Control Valve, PMU-144, Intermediate or Open 6.9.9 Observe Primary Makeup water flow rate for proper indication 6.9.10 Operate VCT Inlet/Bypass to Holdup Tanks, CVC-169 Control Switch to BMS/Auto positions as necessary to maintain VCT pressure and level within normal operating bands.

6.9.11 When Primary Makeup Water Batch Counter has counted down to desired value, then verify Primary Makeup Water Control Valve, PMU-144, Closed.

NOTE Step 6.9.12 may be repeated as necessary to achieve desired total Primary Makeup Water addition for plant conditions.

6.9.12 If additional Primary Makeup Water addition is required and with SM/CRS permission, then perform the following:

6.9.12.1 Reset Primary Makeup Water Batch Counter.

6.9.12.2 Verify Primary Makeup Water Control Valve, PMU-144, Intermediate or Open.

6.9.12.3 Observe Primary Makeup water flow rate for proper indication.

6.9.12.4 When Primary Makeup Water Batch Counter has counted down to desired value, then verify Primary Makeup Water Control Valve, PMU-144, Closed.

OP-010-003, Plant Startup, Attachment 9.4 9.4.62.1 Set Plant Monitoring Computer to Mode 1 in accordance with OP-004-012, Plant Computer System.

9.4.63 At 6% power, verify CPCs are calculating PQASI (PID 266).

9.4.64 As directed by SM/CRS, initiate ASI control in accordance with Attachment 9.13, Axial Shape Control Guidelines.

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Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 1 Page 4 of 21 Event

Description:

Raise power to 10% to roll the Main Turbine Time Position Applicants Actions or Behavior 9.4.65 If PQASI is outside the band of -0.48 to +0.48, then limit Reactor power to maintain CPC Total Raw Flux, DKSUM (PID 272) <43 on the most limiting channel.

CAUTION IF CPC TOTAL RAW FLUX, DKSUM (PID 272) IS GREATER THAN 51, AND PQASI (PID 266)

EXCEEDS THE BAND OF -0.5 TO +0.5, THEN A CPC AUX TRIP WILL OCCUR.

9.4.66 If PQASI is within the band of -0.48 to +0.48, then continue power increase to ~10%.

Examiner Note This event is complete after the Reactivity Manipulation is satisfied OR As directed by the Lead Evaluator Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 2 Page 5 of 21 Event

Description:

Containment Pressure PPS Channel D (CIAS), CB-IPI-6701SMD, fails high Time Position Applicants Actions or Behavior ATC/BOP Recognizes and reports indications of failed channel.

Alarms:

RPS CHANNEL TRIP CNTMT PRESSURE HI (Cabinet K, A-17)

CNTMT PRESSURE HI PRETRIP B/D (Cabinet K, C-17)

RPS CHANNEL D TROUBLE (Cabinet K, H-18)

ESFAS CHANNEL TRIP CNTMT PRESSURE HI (Cabinet K, L-17)

CNTMT PRESSURE HI ESFAS PRETRIP B/D (Cabinet K, N-17)

Indications:

PPS Channel D Containment Pressure (CIAS), CB-IPI-6701SMD failed high on CP-7

All other Containment Pressure instruments reading normal on CP-7

Pretrip and Trip Bistable Lights illuminated for Containment Pressure HI CNT PRESS (RPS and ESF) on Channel D CP-7 ROM.

Examiner Note All BOP manipulations for OP-009-007 are located at CP-10 except as noted.

OP-009-007, Plant Protection System ,Section 6.2, Trip Channel Bypass Operation SRO 6.2.1 Refer to Attachment 11.11, PPS Bistable Bypass Chart to assist in determination of Trip Channels requiring placement in bypass.

Determines the following bistables are affected and need to be bypassed:

13 - HI CNT PRESS (RPS)

16 - HI CNT PRESS (SIAS/CIAS/MSIS)

SRO Directs BOP to bypass the HI CNT PRESS (RPS) and HI CNT PRESS (SIAS/CIAS/MSIS) bistables in PPS Channel D within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months in accordance with OP-009-007, Plant Protection System.

BOP 6.2.2 To place a bistable in or remove a bistable from bypass, go to Attachment 11.10, Trip Channel Bypass Operation.

BOP 11.10.1 To Bypass a Trip Channel, perform the following:

11.10.1.1 Circle the bistable numbers selected for bypass under Step 11.10.1.4. (Circles bistable numbers 13 and 16 in Step 11.10.1.4 table)

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Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 2 Page 6 of 21 Event

Description:

Containment Pressure PPS Channel D (CIAS), CB-IPI-6701SMD, fails high Time Position Applicants Actions or Behavior BOP 11.10.1.2 Check desired Trip Channel is not Bypassed on another PPS Channel.

BOP 11.10.1.3 Open key-locked portion of BCP in desired PPS Channel.

BOP 11.10.1.4 Depress Bypass push buttons for the desired Trip Channels BOP 11.10.1.5 Check all selected bistable Bypass push buttons remain in a Depressed state.

BOP 11.10.1.6 Check all selected bistable Bypass lights Illuminate on BCP for the desired Trip Channels.

CREW 11.10.1.7 Check all selected bistable Bypass lights Illuminate on ROM for the desired Trip Channels. (Verifies correct bistables lit on CP-7 PPS Channel D Remote Operator Module)

SRO Reviews the following Technical Specifications and determines applicable actions:

3.3.1 action 2

3.3.2 actions 13

3.3.3.5 - no actions required

3.3.3.6 - no actions required Examiner Note This event is complete when bistables are bypassed and Technical Specifications have been addressed OR As directed by the Lead Evaluator Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 3 Page 7 of 21 Event

Description:

Charging Pump B trips on Instantaneous Overcurrent Time Position Applicants Actions or Behavior Note All controls for the Charging manipulations are on CP-4 ATC Recognize and report indications of Charging Pump B trip.

Alarms:

Charging Pump B Trip/Trouble (Cabinet G, B-6)

Charging Pumps Header Flow Lo (Cabinet G, H-5)

Indications:

Charging flow and Charging Header pressure drop

Charging Pump B control switch indicates stop

REGEN HX TUBE OUTLET temperature (CVC-ITI-0221) rising Examiner Note There are steps in off normal OP-901-112, Charging or Letdown Malfunction, to manually start a standby Charging Pump after verifying a suction path. It is acceptable for the SRO to direct this action prior to entering OP-901-112 to avoid isolating the Charging and Letdown system on high temperature.

If this is directed, the SRO should still enter OP-901-112 even after a Charging Pump is running.

SRO Enters and directs the implementation of OP-901-112, Charging or Letdown Malfunction.

OP-901-112, Charging or Letdown Malfunction SRO 1. Stop turbine load changes.

N/A 2. IF malfunction is due to failure of the Pressurizer Level Control System, THEN go to OP-901-110, PRESSURIZER LEVEL CONTROL MALFUNCTION SRO 3. IF a Charging Malfunction is indicated, THEN go to Subsection E1, Charging Malfunction.

SRO should evaluate E0 and go to sub-section E1.

NOTE If all Charging Pumps are secured, then LETDOWN STOP VALVE (CVC 101) will close on high REGEN HX TUBE OUTLET temperature if RCS is 470°F.

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Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 3 Page 8 of 21 Event

Description:

Charging Pump B trips on Instantaneous Overcurrent Time Position Applicants Actions or Behavior This condition is applicable to the plant conditions. Regen Heat Exchanger temperature will rise to the 470 °F setpoint. Time is available for the crew to take action prior to isolation.

CAUTION THE REACTOR COOLANT SYSTEM WILL BE BORATED IF A CHARGING PUMP IS STARTED WITH THE RWSP AS THE MAKEUP WATER SOURCE.

ATC 1. IF Charging Pumps have tripped, THEN perform the following:

1.1 Verify open EITHER VCT DISCH VALVE (CVC 183) OR RWSP TO CHARGING PUMP (CVC 507).

1.2 IF Letdown has NOT isolated, THEN attempt to restart Charging Pump(s).

1.3 IF the Charging Pump can NOT be restarted, THEN verify closed LETDOWN STOP VALVE (CVC 101).

1.4 IF the reason for the Charging pump trip is corrected AND Pressurizer level is in normal operating band, THEN place Charging and Letdown in service in accordance with Attachment 2

The ATC operator should verify a Charging Pump suction path via CVC-183 prior to starting another Charging Pump. Either Charging Pump A or AB can be started. This action is typically directed by the SRO.

If the crew does not start another Charging Pump prior to Letdown isolating at 470 °F, then the crew should re-establish Charging and Letdown in accordance with Attachment 2.

SRO 2. IF normal Charging flow can NOT be established AND Pressurizer level falls below minimum Pressurizer level for operation in accordance with Attachment 1, Pressurizer Level Versus Tave Curve, THEN perform the following:

This step should not be applicable due to the duration of the malfunction.

CREW 3. IF the PMC is available, THEN display PMC Group CVCS and monitor Charging System parameters to determine cause of Charging malfunction.

This data can be retrieved by any member of the crew. PMC point D39704, CVCS CHG PMP MTR B OVLD TRIP and D39702, CVCS CHG PMP MTR B TRP/TRBL will provide indication of the electrical failure of Charging Pump B.

SRO Evaluates Tech Spec and TRM 3.1.2.4 and enters both.

Tech Spec 3.1.2.4 can be exited by aligning Charging Pump AB to replace B for SIAS.

The SRO should remain in TRM 3.1.2.4 after this operation.

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Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 3 Page 9 of 21 Event

Description:

Charging Pump B trips on Instantaneous Overcurrent Time Position Applicants Actions or Behavior ATC Align Charging Pump AB to replace B on SIAS by aligning the Pump AB Assignment switch to the B position on CP-4.

SRO Exit Tech Spec 3.1.2.4. Crew must remain in TRM 3.1.2.4.

Examiner Note This event is complete after Charging Pump AB is aligned to replace Charging Pump B Or As directed by the Lead Evaluator Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 4 Page 10 of 21 Event

Description:

Startup Feedwater Regulating Valve 1 fails closed Time Position Applicants Actions or Behavior BOP Recognize and report indications of Startup Feedwater Reg Valve failure.

Alarms:

Steam Generator 1 Steam/FW Flow Signal Dev (Cabinet F, T-17)

Steam Generator 2 Steam/FW Flow Signal Dev (Cabinet F, U-17)

Indications:

Steam Generator 1 Level Lowering (SG-ILR1-1105 and 1111)

Deviation between steam flow AND feedwater flow on SG 2 SRO Directs BOP to match Feedwater flow and Steam flow on Steam Generator 1 and restore level to 50-70% NR.

BOP Adjusts Main Feed Reg Valve 1 to Match Feedwater Flow and Steam Flow.

SRO Enters and directs the implementation of OP-901-201, Steam Generator Level Malfunction OP-901-201, Steam Generator Level Malfunction, E0, General N/A 1. If Steam Generator level is < 41% NR and there is no Feedwater flow to the Steam Generator, then perform the following:

1.1 Trip the Reactor.

1.2 Go to OP-902-000, Standard Post Trip Actions SRO 2. Go to Attachment 1, General Actions.

OP-901-201, Steam Generator Level Malfunction, Attachment 1, General Actions SRO Did a Reactor Trip occur? NO - Continues though flowchart Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 4 Page 11 of 21 Event

Description:

Startup Feedwater Regulating Valve 1 fails closed Time Position Applicants Actions or Behavior SRO/BOP Observe the affected Steam Generator FWCS controllers AND note ANY controllers that are behaving erratically.

Steam Generator 1 FW IFIC 1111 , S/G 1 FWCS Master Controller FW IHIC 1111 , S/G 1 Main FRV Controller FW IHIC 1105 , S/G 1 S / U FRV Controller FW IHIC 1107 , SGFP A Speed Controller Steam Generator 2 FW IFIC 1121 , S/G 2 FWCS Master Controller FW IHIC 1121 , S/G 2 Main FRV Controller FW IHIC 1106 , S/G 2 S / U FRV Controller FW IHIC 1108 , SGFP B Speed Controller NOTE Should determine that no controllers are malfunctioning.

N/A Place appropriate controllers for the affected FWCS in manual AND establish control of S/G level. (controllers in MANUAL prior to the event)

SRO/BOP Is the output of the affected FWCS Master Controller behaving erratically?

No SRO/BOP Verify SGFP Discharge pressure for BOTH SGFP ' s is matched AND is greater than S / G pressures.

The BOP should verify the running FW Pump Discharge pressure is greater than Steam Generator Pressure. Only one FW pump is running at this time.

SRO Stop turbine load changes except to match Tave and Tref.

May be applicable if the crew has recommenced the power ascension.

Otherwise this is N/A.

SRO/BOP Review the following guidelines AND restore S /G level to 50-70% NR:

1. IF one SGFP Speed controller is in auto, THEN use its output to help set the SGFP Speed controller that is in manual.

2. Momentary taps on the raise AND lower buttons of the Main Feedwater Reg Valve Controller have a noticeable impact on associated Steam Generator level.

3. Use the Startup Feedwater Reg Valve Controller to control Steam Generator level at low power levels.

4. Use indications on the unaffected FWCS controllers to help set affected FWCS controllers.

Only 2 apples in this case Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 4 Page 12 of 21 Event

Description:

Startup Feedwater Regulating Valve 1 fails closed Time Position Applicants Actions or Behavior SRO/BOP Check the following Control Channel indicators to determine if a Control Channel has failed: (See Note 3)

FW IFR 1111, Steam Generator 1 Feedwater Flow (green pen )

FW IFR 1011, Steam Generator 1 Steam Flow (red pen )

FW IFR 1121, Steam Generator 2 Feedwater Flow (green pen )

FW IFR 1021, Steam Generator 2 Steam Flow (red pen )

SG ILR1111, Steam Generator 1 Downcomer Level (green pen )

SG ILR1105, Steam Generator 1 Downcomer Level (red pen )

SG ILR1121, Steam Generator 2 Downcomer Level (green pen )

SG ILR1106, Steam Generator 2 Downcomer Level (red pen )

Note Should determine no failed instruments.

SRO Control Channel level deviation of > 7%?

NO N/A Verify applicable controllers shifted to manual per automatic actions.

Note The Main Feed Reg Valve B, Startup Feed Reg Valve B, and Main Feedwater Pump B were already in manual.

SRO/BOP Determine AND correct the cause of the malfunction.

BOP should note that Startup Feedwater Reg Valve 1 is not responding to controller output.

The SRO should discuss with the BOP necessary contingency actions necessary due to controlling Feedwater Reg Valve 1 in MANUAL Examiner Note This event is complete after the SRO has completed the flowchart and Steam Generator 1 level is being controlled OR As directed by the Lead Evaluator.

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Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 5 Page 13 of 21 Event

Description:

Large RCS Cold Leg Break/CSAS Fails to Auto Actuate Time Position Applicants Actions or Behavior ATC Recognize and report indications of Loss of Coolant Accident.

Alarms:

Pressurizer Pressure Hi/Lo (Cabinet H, E-1)

Pressurizer Level Hi/Lo (Cabinet H, B-1)

Containment Pressure Hi/Lo (Cabinet M, H-4, Cabinet N, H-14)

Containment Water Leakage Hi (Cabinet N, L-20)

Containment Water Leakage Hi-Hi (Cabinet N, K-20)

Indications:

RCS pressure dropping (CP-7, CP-2)

Pressurizer level lowering (CP-2, CP-8, QSPDS 1)

Backup Charging Pump starts (CP-4)

Letdown flow goes to minimum (CP-4)

SRO Directs ATC and BOP to carry out Standard Post trip Actions.

OP-902-000, Standard Post Trip Actions ATC 1. Determine Reactivity Control acceptance criteria are met:

a. Check reactor power is dropping.

b. Check startup rate is negative.

c. Check less than TWO CEAs are NOT fully inserted.

BOP 2. Determine Maintenance of Vital Auxiliaries acceptance criteria are met:

a. Check the Main Turbine is tripped:

Governor valves closed

Throttle valves closed BOP b. Check the Main Generator is tripped:

GENERATOR BREAKER A tripped

GENERATOR BREAKER B tripped

EXCITER FIELD BREAKER tripped Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 5 Page 14 of 21 Event

Description:

Large RCS Cold Leg Break/CSAS Fails to Auto Actuate Time Position Applicants Actions or Behavior BOP c. Check station loads are energized from offsite electrical power as follows:

Train A

A1, 6.9 KV non safety bus

A2, 4.16 KV non safety bus

A3, 4.16 KV safety bus

A-DC electrical bus

A or C vital AC Instrument Channel Train B

B1, 6.9 KV non safety bus

B2, 4.16 KV non safety bus

B3, 4.16 KV safety bus

B-DC electrical bus

B or D vital AC Instrument Channel ATC 3. Determine RCS Inventory Control acceptance criteria are met:

a. Check that BOTH the following conditions exist:

Pressurizer level is 7% to 60%

Pressurizer level is trending to 33% to 60%

b. Check RCS subcooling is greater than or equal to 28ºF.

Note This will not be met due to the LOCA ATC 4. Determine RCS Pressure Control acceptance criteria are met by checking that BOTH of the following conditions exist:

Pressurizer pressure is 1750 psia to 2300 psia

Pressurizer pressure is trending to 2125 psia to 2275 psia 4.2 IF pressurizer pressure is less than 1684 psia, THEN verify the following have initiated.

SIAS

CIAS 4.3 IF pressurizer pressure is less than 1621 psia, THEN verify no more than two RCPs are operating 4.4 IF pressurizer pressure is less than the minimum RCP NPSH of Appendix 2-A, "RCS Pressure and Temperature Limits", THEN stop ALL RCPs.

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Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 5 Page 15 of 21 Event

Description:

Large RCS Cold Leg Break/CSAS Fails to Auto Actuate Time Position Applicants Actions or Behavior ATC 5. Determine Core Heat Removal acceptance criteria are met:

a. Check at least one RCP is operating.

b. Check operating loop T is less than 13ºF.

c. Check RCS subcooling is greater than or equal to 28ºF.

Note If Reactor All Coolant Pumps are secured, this step can be skipped.

BOP 6. Determine RCS Heat Removal acceptance criteria are met:

a. Check that at least one steam generator has BOTH of the following:

Steam generator level is 5% to 80% NR

Main Feedwater is available to restore level within 50%-70%

NR.

Note Main Feedwater will be isolated on MSIS a2. Verify Emergency Feedwater is available to restore level in at least one steam generator within 50%-70% NR [60-80% NR].

ATC b. Check RCS TC is 530 ºF to 550 ºF BOP c. Check steam generator pressure is 885 psia to 1040 psia.

BOP d. Check Feedwater Control in Reactor Trip Override:

MAIN FW REG valves are closed

STARTUP FW REG valves are 13% to 21% open

Operating main Feedwater pumps are 3800 rpm to 4000 rpm Note After MSIS Feedwater pumps will be coasting down and feedwater control valves will be closed.

BOP e. Reset moisture separator reheaters, and check the temperature control valves closed.

ATC 7. Determine Containment Isolation acceptance criteria are met:

a. Check containment pressure is less than 16.4 psia.

b. Check NO containment area radiation monitor alarms OR unexplained rise in activity.

c. Check NO steam plant activity monitor alarms OR unexplained rise in activity.

Note Wont be met because of Containment Pressure and activity Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 5 Page 16 of 21 Event

Description:

Large RCS Cold Leg Break/CSAS Fails to Auto Actuate Time Position Applicants Actions or Behavior a1. IF containment pressure is greater than or equal to 17.1 psia, THEN verify the following:

CIAS is initiated

SIAS is initiated

MSIS is initiated BOP 8 Determine Containment Temperature and Pressure Control acceptance criteria are met:

a. Check containment temperature is less than or equal to 120ºF.

lsutgr-4

b. Check containment pressure is less than 16.4 psia.

8.1 Verify at least three containment fan coolers are operating.

8.2 IF containment pressure is greater than or equal to 17.1 psia, THEN verify ALL available containment fan coolers are operating in emergency mode.

CRITICAL TASK ESTABLISH CONTAINMENT TEMPERATURE AND PRESSURE CONTROL This task is satisfied by manually initiating Containment Spray Actuation Signal prior to exiting OP-902-000, Standard Post Trip Actions or Containment pressure exceeds 44 PSIG.

This task becomes applicable after Containment Pressure rises above 17.7 PSIA.

CRITICAL TASK TRIP ANY RCP NOT SATISFYING RCP OPERATING LIMITS This task is satisfied by securing all RCPs within 3 minutes of loss of Component Cooling Water flow.

This task becomes applicable after Containment Spray is initiated.

The time requirement of 3 minutes is based on the Reactor Coolant Pump operating limit of 3 minutes without Component Cooling Water cooling.

8.3 IF containment pressure is greater than or equal to 17.7 psia, THEN verify ALL of the following:

CSAS is initiated

ALL available containment spray pumps are delivering flow greater than 1750 gpm

ALL RCPs are secured Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 5 Page 17 of 21 Event

Description:

Large RCS Cold Leg Break/CSAS Fails to Auto Actuate Time Position Applicants Actions or Behavior N/A 9. IF ALL safety function acceptance criteria are met, AND NO contingency actions were performed, THEN GO TO OP-902-001, "Reactor Trip Recovery" procedure.

SRO 10. IF ANY safety function acceptance criteria are NOT met, OR ANY contingency action was taken, THEN GO TO Appendix 1, "Diagnostic Flowchart.

Proper use of chart will result in use of OP-902-002, Loss of cooling Accident Recovery.

OP-902-002, Loss of Coolant Accident Recovery SRO 1. Confirm diagnosis of a LOCA:

a. Check Safety Function Status Check Acceptance criteria are satisfied.

b. IF Steam Generator sample path is available, THEN direct Chemistry to sample BOTH Steam Generators for activity.

CREW 2. Announce a Loss of Coolant Accident is in progress using the plant page.

SRO 3. Advise the Shift Manager to REFER TO EP-001-001, "Recognition &

Classification of Emergency Condition" and implement the Emergency Plan.

N/A 4. IF power has been interrupted to either 3A or 3B safety buses, THEN perform Appendix 20, "Operation of DCT Sump Pumps".

SRO 5. REFER TO Section 6.0, "Placekeeper" and record the time of the reactor trip.

Examiner Note This event is complete after the SRO enters OP-902-002 Or As directed by the Lead Evaluator.

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Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 6 Page 18 of 21 Event

Description:

Main Steam Line 2 Break Inside Containment/Containment Spray Pump A Trips/OP-902-008 Time Position Applicants Actions or Behavior BOP Recognizes and reports indication of Main Steam Line Break on SG 2 Alarms

SG 2 Pressure Lo Pretrip and Trip Alarms on CP-2

SG 2 Level Lo Pretrip and Trip Alarms Indications

SG 2 Pressure lowering on CP-8 and CP-1 indicators

SG 2 Level lowering on CP-8 and CP-1 indicators SRO Recognize two events in progress and either goes directly to OP-902-008, Functional Recovery, or returns to the diagnostics flowchart and diagnoses into OP-902-008.

OP-902-008, Functional Recovery CREW 1. Announce that the Functional Recovery Procedure is in progress using the plant page.

SRO 2 Advise the Shift Manager to REFER TO EP-001-001, "Recognition &

Classification of Emergency Condition" and implement the Emergency Plan.

SRO 3 REFER TO the "Placekeeper" and record the time of the reactor trip.

N/A 4. IF pressurizer pressure is less than 1621 psia, AND SIAS is actuated, THEN

a. Verify no more than two RCPs are operating.

b. IF pressurizer pressure is less than the minimum RCP NPSH of Appendix 2A-D, "RCS Pressure and Temperature Limits", THEN stop ALL RCPs.

N/A 5. IF RCPs are operating, THEN:

a. IF a CSAS is initiated, THEN stop ALL RCPs.

b. Verify CCW available to RCPs.

c. IF RCS TC is less than 382ºF [384ºF], THEN verify no more than two RCPs are operating.

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Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 6 Page 19 of 21 Event

Description:

Main Steam Line 2 Break Inside Containment/Containment Spray Pump A Trips/OP-902-008 Time Position Applicants Actions or Behavior NOTE The Shift Chemist should be notified if a SIAS or CIAS has occurred. The secondary sampling containment isolation valves should not be opened following an SIAS or CIAS until directed by the Shift Chemist.

SRO 6. Direct Chemistry to sample BOTH steam generators for activity and boron.

N/A 7. IF power is lost to both 3A and 3B safety buses and NOT expected to be restored within 30 minutes, THEN perform the following:

N/A 8. IF power is lost to both 3A and 3B safety buses and NOT expected to be restored within 30 minutes, THEN perform the following to reduce unnecessary station loads:

N/A 9. IF power has been interrupted to either 3A or 3B safety buses, THEN perform Appendix 20, "Operation of DCT Sump Pumps".

BOP 10. Place Hydrogen Analyzers in service as follows:

Train A

a. Place Train A H2 ANALYZER CNTMT ISOL VALVE keyswitch to OPEN.

b. Place H2 ANALYZER A POWER to ON.

c. Check H2 ANALYZER A Pumps indicate ON.

Train B

a. Place Train B H2 ANALYZER CNTMT ISOL VALVE keyswitch to OPEN.

b. Place H2 ANALYZER B POWER to ON.

c. Check H2 ANALYZER B Pumps indicate ON.

CRITICAL TASK ESTABLISH CONTAINMENT ISOLATION This task is satisfied by prioritizing CI-1 as Priority 1 after performing Step 11 of OP-902-008, Functional Recovery This task becomes applicable after the Main Steam Line Break occurs.

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Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 6 Page 20 of 21 Event

Description:

Main Steam Line 2 Break Inside Containment/Containment Spray Pump A Trips/OP-902-008 Time Position Applicants Actions or Behavior SRO 11. Identify success paths to be used and prioritize Safety Functions.

SRO should determine priorities and paths as follows on the Safety Function Tracking Sheet: (Priorities may vary depending on time parameters checked; however, Priority1 should be CI-1)

Reactivity Control, RC-1 = 5

Maintenance of Vital Auxiliaries (DC), MVA-DC-1 = 6

Maintenance of Vital Auxiliaries (AC), MVA-AC-1 = 7

RCS Inventory Control, IC-2 = 2

RCS Pressure Control, PC-2 = 8

RCS and Core Heat Removal, HR-2 = 3

Containment Isolation, CI-1 = 1 (CRITICAL)

Containment Temperature and Pressure Control, CTPC-2 = 4 Note The SRO may choose to two address safety functions in parallel CONTAINMENT ISOLATION, CI-1 SRO/BOP 1. IF ANY of the following conditions exist:

Containment pressure is greater than 17.1 psia

Pressurizer pressure is less than 1684 psia

Containment area radiation monitors greater than the Hi Alarm setpoint THEN perform BOTH of the following:

a. Verify CIAS is initiated.

b. Verify that an isolation valve is closed for each containment penetration required to be closed.

b1. IF ANY containment fan cooler is NOT operating AND containment pressure is greater than 17.1 psia, THEN REFER TO Appendix 21-B, "CFC CCW Override" and close the associated Containment Fan Cooler CCW Isolation Valves.

b2. IF ANY CS-125, Containment Spray Header Isolation is open AND the associated CS pump is NOT operating, THEN REFER TO Appendix 21-A, "CS-125 Override," and close the valve.

N/A 2. IF a SGTR is indicated by ANY of the following:

SRO/ATC 3. Check the following CCW Radiation Monitor AB indications:

Hi Alarm clear

No abnormal rise in radiation monitor reading Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 6 Page 21 of 21 Event

Description:

Main Steam Line 2 Break Inside Containment/Containment Spray Pump A Trips/OP-902-008 Time Position Applicants Actions or Behavior

4. Check CI-1, Automatic/Manual Isolation is satisfied by ANY of the following:

Condition 1

a. IF steam plant activity monitor alarms or an unexplained rise in steam plant activity exists, THEN ALL release paths from the most affected steam generator to the environment are closed.

b. Containment pressure is less than 17.1 psia.

c. NO Containment area radiation monitor alarms or unexplained rise.

d. IF SGTR diagnosed, THEN steam generator pressure less than 1000 psia [960 psia] AND NOT steaming via ADV.

Condition 2

a. IF steam plant activity monitor alarms or an unexplained rise in steam plant activity exists, THEN ALL release paths from the most affected steam generator to the environment are closed.

b. Each containment penetration required to be closed for current plant conditions has an isolation valve closed.

c. IF SGTR diagnosed, THEN steam generator pressure less than 1000 psia [960 psia] AND NOT steaming via ADV.

Examiner Note This event is complete after SRO prioritizes Safety Functions and implements highest priority path Or As directed by the Lead Evaluator.

Revision 1

Appendix D Scenario Outline Form ES-D-1 Facility: Waterford 3 Scenario No.: 4 Op Test No.: 1 Examiners: Operators:

Initial Conditions: ~ 100% Reactor Power, BOC Turnover:

Protected Train is B, AB Bus is aligned to Train B, HPSI Pump A is OOS Event Malf. Event Event No. No. Type* Description Steam Generator 2 Level Control Transmitter, SG-ILT-1106, fails low requiring implementation of I - BOP OP-901-201, Steam Generator Level Control 1 SG05B I - SRO Malfunction.

I - ATC Pressurizer Level Control Channel Level Transmitter, I - SRO RC-ILT-0110X, fails high requiring implementation of 2 RC15A1 TS - SRO OP-901-110, Pressurizer Level Control Malfunction.

Steam Generator 2 develops a tube leak requiring implementation of OP-901-202, Steam Generator 3 SG01B TS - SRO Tube Leakage.

R - ATC Steam Generator 2 tube leakage requires N - BOP implementation of OP-901-212, Rapid Plant Power 4 N/A N - SRO Reduction.

Instrument Air Leak requiring implementation of OP-901-511, Instrument Air Malfunction and a manual IA03D C - ATC reactor trip. After the reactor trip the leak is located 5 IAR28 C - SRO and isolated.

Primary to Secondary Leakage in Steam Generator 2 rises to greater than Charging Pump Capacity (Steam 6 SG01B M - All Generator Tube Rupture) (Critical Task 2 and 3)

A Startup Transformer B fault occurs, causing loss of power to the B3 bus which powers the only OPERABLE HPSI Pump. Emergency Diesel ED02D C - BOP Generator B fails to AUTO start requiring operator 7 EG08B C - SRO action to re-energize the B3 bus. (Critical Task 1)

High Pressure Safety Injection Pump B fails to auto C - BOP start requiring action to start the HPSI Pump. (Critical 8 SI02B C - SRO Task 1)

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 2012 NRC Exam Scenario 4 D-1 Rev 2

Scenario Event Description NRC Scenario 4 The crew assumes the shift at 100% power with instructions to maintain 100% power. High Pressure Safety Injection Pump A is out of service and danger tagged, due to high pump bearing vibration during its quarterly IST. Since it occurred just prior to shift turnover and the AB bus is aligned to Train B, High Pressure Safety Injection Pump AB has not yet been aligned for service. The Work Management Center is working in that direction.

After taking the shift, Steam Generator 2 Level Control Transmitter, SG-ILT-1106 fails low. The SRO should direct the BOP to match feedwater and steam flow using Feedwater Regulating Valve 2, FW-173B and stabilize SG 2 level 50-70% Narrow Range. The SRO should enter OP-901-201, Steam Generator Level Control Malfunction and implement Attachment 1, General Actions.

After the crew has restored Steam Generator 2 to between 50 and 70% Narrow Range, Pressurizer Level Control Channel Level Transmitter, RC-ILT-0110X, fails high. The SRO should enter OP-901-110, Pressurizer Level Control Malfunction and implement Section E1. The crew should take manual control of the Pressurizer Level Controller and/or operate Charging Pumps to restore Pressurizer level, swap control to the Channel Y level channel, and return the Pressurizer Level Controller back to AUTO. The SRO should review Technical Specifications 3.3.3.5 and 3.3.3.6 and OP-903-013, Monthly Channel Checks. The SRO should determine that TS 3.3.3.6 requirements are met, but enter TS 3.3.3.5 Action a.

After Pressurizer Level Control is in AUTO, Steam Generator 2 develops a tube leak at ~ 11 gpm. The SRO should implement OP-901-202, Steam Generator Tube Leakage or High Activity. The SRO should determine that based on leak indications, Technical Specification 3.4.5.2 is not met for Primary-to-Secondary Leakage or Identified Leakage and enter TS 3.4.5.2 Action a. The SRO should also determine that the current leakage requires implementation of OP-901-212, Rapid Plant Power Reduction.

After the reactivity manipulation has been satisfied, an Instrument Air leak occurs. The SRO should implement OP-901-511, Instrument Air Malfunction. SA-125, Station Air to Instrument Air cross-connect valve, fails to open at set pressure and Instrument Air Header Pressure drops to less than 65 psig. The SRO should order a manual reactor trip and the crew should perform the actions of OP-902-000, Standard Post Trip Actions. If a leak location investigation is initiated, the leak will be found and isolated.

If an operator is sent to SA-125 the operator will be able to open the valve by adjusting the local controller. Neither of these actions will be performed prior to reaching the reactor trip criteria of OP-901-511.

After the SRO has entered OP-902-007, Steam Generator Tube Rupture Recovery, Primary to Secondary leakage rises to greater than Charging Pump capacity. The SRO should order a manual actuation of Safety Injection and Containment Isolation. After Safety Injection is actuated, Startup Transformer B fails and Emergency Diesel Generator B fails to AUTO start. Additionally, when power is restored High Pressure Safety Injection Pump B fails to auto start. The BOP should perform a manual start of Emergency Diesel Generator B, verify that the Emergency Diesel Generator automatically loads, and manually start High Pressure Safety Injection Pump B (CRITICAL TASK 1). The crew should start a rapid cooldown of the Reactor Coolant System to less than 520°F T-hot. Since MS-319A is out of service due to the IA line rupture the BOP should select an alternate Steam Bypass Valve to perform the cooldown. The crew should also depressurize the Reactor Coolant System to prevent lifting secondary safety valves on Steam Generator 2 (CRITICAL TASK 2), and isolate Steam Generator 2 (CRITICAL TASK 3).

The scenario can be terminated after Steam Generator 2 is isolated or at the lead examiners discretion.

2012 NRC Exam Scenario 4 D-1 Rev 2

NRC Scenario 4 CRITICAL TASKS

1. ESTABLISH RCS INVENTORY CONTROL This task applies upon loss of power to the B3 bus. This task is satisfied by the crew taking action to start and load Emergency Diesel Generator B and manually start High Pressure Safety Injection Pump B.

2. PREVENT OPENING MAIN STEAM SAFETY VALVES.

This task is satisfied by the crew taking action to maintain Steam Generator 2 pressure below the lowest secondary safety valve setpoint by taking action to reduce RCS pressure to < 1085 psia.

3. ISOLATE RUPTURED STEAM GENERATOR This task is satisfied by isolating Steam Generator 2 in accordance with OP-902-007, Steam Generator Tube Rupture Recovery, Step 17 after RCS THOT is reduced below 520°F.

Scenario Quantitative Attributes

1. Total malfunctions (5-8) 7

2. Malfunctions after EOP entry (1-2) 2

3. Abnormal events (2-4) 4

4. Major transients (1-2) 1

5. EOPs entered/requiring substantive actions (1-2) 1

6. EOP contingencies requiring substantive actions (0-2) 0

7. Critical tasks (2-3) 3 2012 NRC Exam Scenario 4 D-1 Rev 2

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

Description:

FWCS 2 Steam Generator Level Transmitter SG-ILT-1106 fails low Time Position Applicants Actions or Behavior BOP Recognize and report indications of failed Steam Generator level instrument.

Alarms

SG 2 FW Contl Lvl Signal Dev/Pwr Lost (Cabinet F, T-19)

SG 2 Level Hi/Lo (Cabinet F, U-18)

Indications

Controllers for Steam Generator 2 shift to MANUAL.

o Main Feedwater Regulating Valve B Controller.

o Startup Feedwater Regulating Valve B Controller o Main Feedwater Pump B Speed Controller SRO Enter and direct the implementation of OP-901-201, Steam Generator Level Control Malfunction OP-901-201, Steam Generator Level Control Malfunction, Section E0, General N/A 1. If Steam Generator level is <41% NR and there is no Feedwater flow to the Steam Generator, then perform the following:

1.1 Trip the Reactor.

1.2 Go to OP-902-000, Standard Post Trip Actions SRO 2. Go to Attachment 1, General Actions.

OP-901-201, Steam Generator Level Control Malfunction, Attachment 1, General Actions SRO Did a Reactor Trip occur? NO - Continues though flowchart Scenario 4, Revision 1

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

Description:

FWCS 2 Steam Generator Level Transmitter SG-ILT-1106 fails low Time Position Applicants Actions or Behavior SRO/BOP Observe the affected Steam Generator FWCS controllers AND note ANY controllers that are behaving erratically.

Steam Generator 1 FW IFIC 1111 , S/G 1 FWCS Master Controller FW IHIC 1111 , S/G 1 Main FRV Controller FW IHIC 1105 , S/G 1 S / U FRV Controller FW IHIC 1107 , SGFP A Speed Controller Steam Generator 2 FW IFIC 1121 , S/G 2 FWCS Master Controller FW IHIC 1121 , S/G 2 Main FRV Controller FW IHIC 1106 , S/G 2 S / U FRV Controller FW IHIC 1108 , SGFP B Speed Controller NOTE Should determine that no controllers are malfunctioning.

SRO/BOP Place appropriate controllers for the affected FWCS in manual AND establish control of S/G level. (Determines proper controllers in MANUAL)

SRO/BOP Is the output of the affected FWCS Master Controller behaving erratically?

No SRO/BOP Verify SGFP Discharge pressure for BOTH SGFP's is matched AND is greater than S/G pressures.

N/A Stop turbine load changes except to match Tave and Tref.

SRO/BOP Review the following guidelines AND restore S /G level to 50-70% NR:

1. IF one SGFP Speed controller is in auto, THEN use its output to help set the SGFP Speed controller that is in manual.

2. Momentary taps on the raise AND lower buttons of the Main Feedwater Reg Valve Controller have a noticeable impact on associated Steam Generator level.

3. Use the Startup Feedwater Reg Valve Controller to control Steam Generator level at low power levels.

4. Use indications on the unaffected FWCS controllers to help set affected FWCS controllers.

Scenario 4, Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 1 Page 3 of 23 Event

Description:

FWCS 2 Steam Generator Level Transmitter SG-ILT-1106 fails low Time Position Applicants Actions or Behavior SRO/BOP Check the following Control Channel indicators to determine if a Control Channel has failed: (See Note 3)

FW IFR 1111, Steam Generator 1 Feedwater Flow (green pen )

FW IFR 1011, Steam Generator 1 Steam Flow (red pen )

FW IFR 1121, Steam Generator 2 Feedwater Flow (green pen )

FW IFR 1021, Steam Generator 2 Steam Flow (red pen )

SG ILR1111, Steam Generator 1 Downcomer Level (green pen )

SG ILR1105, Steam Generator 1 Downcomer Level (red pen )

SG ILR1121, Steam Generator 2 Downcomer Level (green pen )

SG ILR1106, Steam Generator 2 Downcomer Level (red pen )

Note

SG ILR1106, Steam Generator 2 Downcomer Level (red pen ) is the failed instrument.

SRO Control Channel level deviation of >7%?

YES SRO Verify applicable controllers shifted to manual per automatic actions.

Note The Main Feed Reg Valve B, Startup Feed Reg Valve B, and Main Feedwater Pump B will have shifted to manual.

SRO Determine AND correct the cause of the malfunction.

Coverage of the flow chart in Attachment 1 should conclude that the failed instrument is the problem.

The SRO should discuss with the BOP necessary contingency actions necessary with the listed controllers in MANUAL. This should include actions on a Reactor trip or on Steam Generator High Level Override.

Examiner Note This event is complete when the flow chart in Attachment 1 has been completed and the contingencies have been discussed and the BOP has performed manual control during the power reduction Or As directed by the Lead Evaluator This failure requires additional actions by the BOP during the power reduction and after the Reactor trip later in the scenario.

Scenario 4, Revision 1

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

Description:

Pressurizer Level Control Channel Level Transmitter, RC-ILT-0110X fails high Time Position Applicants Actions or Behavior ATC Recognize and report indications of failed instrument.

Alarms:

PRESSURIZER LEVEL HI/LO (Cabinet H, B-1)

PRESSURIZER LEVEL HI-HI (Cabinet H, A-1)

LETDOWN FLOW HI/LO (Cabinet G, C-1)

LETDOWN HX OUTLET PRESS HI (Cabinet G, A-2)

Indications

Mismatch between Charging (CVC-IFI-0212) AND Letdown (CVC-IFI-0202) flow indications. Letdown rises to maximum, with 1 charging pump running

Deviation between indicated level AND programmed level as indicated on Pressurizer level recorder (RC-ILR-0110).

RC-ILI-0110X reading ~ 100%

Actual Pressurizer level RC-ILI-0110Y slowly lowering.

Pressurizer Backup Heaters energize SRO May direct the ATC to take manual control of Pressurizer Level Controller, RC-ILIC-0110 and match Letdown flow and Charging flow prior to entering procedure.

SRO Enter and direct the implementation of OP-901-110, Pressurizer Level Control Malfunction.

OP-901-110, Section E0, General Actions N/A 1. Stop Turbine load changes.

N/A 2. IF malfunction is due to failure of Letdown Flow Control valve, THEN GO TO OP-901-112, CHARGING/LETDOWN MALFUNCTION.

S 3. IF malfunction is due to failure of Pressurizer Level Control Channel RO (incorrect readings on EITHER RC-ILI-0110X OR RC-ILI-0110Y),

THEN GO TO Subsection E1, Pressurizer Level Control Channel Malfunction.

OP-901-110, Section E1, Pressurizer Level Control Channel Malfunction NOTE Selecting the non-faulted channel may cause automatic actions to occur if actual level is not at program level.

Scenario 4, Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 2 Page 5 of 23 Event

Description:

Pressurizer Level Control Channel Level Transmitter, RC-ILT-0110X fails high Time Position Applicants Actions or Behavior ATC 1. Place Pressurizer Level Controller (RC-ILIC-0110) in MAN AND adjust OUTPUT to slowly adjust letdown flow to restore Pressurizer level.

ATC 2. Transfer Pressurizer Level Control CHANNEL SELECT switch to non-faulted channel.

ATC 3. Transfer Pressurizer CHANNEL SELECT LO LEVEL HEATER CUTOFF switch to non-faulted channel.

ATC 4. Verify desired backup Charging pumps in AUTO.

ATC 5. Verify ALL PROPORTIONAL AND BACKUP HEATER BANKS reset.

ATC 6. Place Pressurizer Level Controller (RC-ILIC-0110) in AUTO and verify Pressurizer Level is being restored to setpoint.

ATC 7. Verify Pressurizer level controlling at program setpoint in accordance with Attachment 1, Pressurizer Level Versus Tave Curve.

SRO 8. Refer to Technical Specifications 3.3.3.5 and 3.3.3.6 for Remote Shutdown and Accident Monitoring operability determination.

Note The SRO should review Technical Specifications 3.3.3.5 and 3.3.3.6 and OP-903-013, Monthly Channel Checks. The SRO should determine that TS 3.3.3.6 requirements are met, but enter TS 3.3.3.5 Action a.

Examiner Note This event is complete after Pressurizer Level Control System is selected to non-faulted channel and returned to automatic operation and Technical Specifications have been addressed OR As directed by the Lead Evaluator Scenario 4, Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 3/4 Page 6 of 23 Event

Description:

Steam Generator 2 develops a tube leak/ Rapid Plant Power Reduction Time Position Applicants Actions or Behavior ATC Recognize and report indications of Steam Generator Tube Leakage.

Alarms:

RAD MONITORING SYS ACTIVITY HI-HI (Cabinet L, A-9)

VACUUM PUMPS EXHAUST ACTIVITY HI (Cabinet E, C-3)

Indications

RM-11 Rad Monitor indication will display rising activity on Main Steam Rad Monitor 2, Steam Generator 2 N-16 Rad Monitor, Main Condenser Vacuum Pumps WRGM, and the Blowdown radiation monitor.

Steam Generator tube leakage indication rising as indicated on PMC Group PSLR (PMC PID C48304).

SRO Enter and direct the implementation of OP-901-202, Steam Generator Tube Leakage or High Activity.

OP-901-202, Steam Generator Tube Leakage or High Activity SRO 1. IF Pressurizer level CANNOT be maintained with available Charging Pumps, THEN perform the following:

1.1 Manually trip Reactor.

1.2 Manually initiate Safety Injection Actuation (SIAS) AND Containment Isolation Actuation (CIAS).

1.3 GO TO OP-902-000, STANDARD POST TRIP ACTIONS.

NOTE (1) The calculated Primary to Secondary Leak Rate values must be considered valid, unless the reading can be quickly diagnosed as incorrect due to an obvious malfunction of the PMC or AE Discharge Rad Monitor.

(2) The AE Discharge Rad Monitor is considered the primary Rad Monitor which has the sensitivity to measure small Primary to Secondary Leakage. The AE Discharge Rad Monitor reading inputs into the Primary to Secondary Leak Calculation on PMC Group PLSR. The MS Line N16 Rad Monitors may be used as verification of AE Discharge Rad Monitor or as primary indication if the AE Discharge Rad Monitor is OOS.

Scenario 4, Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 3/4 Page 7 of 23 Event

Description:

Steam Generator 2 develops a tube leak/ Rapid Plant Power Reduction Time Position Applicants Actions or Behavior ATC 2. Determine RCS leak rate using ANY of the following:

Calculated Steam Generator leakage displayed on PMC Group PSLR (PMC PID C48304)

Calculated Steam Generator leakage displayed on PMC PID C48251 (RE5501 CH1 LEAK RATE) and C48252 (RE5501 CH2 LEAK RATE)

Approximate RCS leak rate by subtracting total of Letdown flow AND RCP CBO flow from Charging Flow

Calculated Charging / Letdown Mismatch displayed on PMC Group Leakrate (PMC PID S13001)

RCS Leak Rate calculation in accordance with OP-903-024, REACTOR COOLANT SYSTEM WATER INVENTORY BALANCE

Calculated steam generator leakage based upon chemistry sample, per CE-003-705, DETERMINATION OF PRIMARY-TO-SECONDARY LEAK RATE NOTE Any rise >30 GPD/HR followed by a subsequent lowering of the rate of change would indicate a spike and a rapid power reduction is not required.

SRO 3. IF Primary to Secondary Leakage in any Steam Generator is 75 GPD

(~0.05 GPM) AND the rate of change is rising by 30 GPD/HR (~0.02 GPM/HR), THEN perform the following:

3.1 Commence a rapid plant shutdown in accordance with OP-901-212, RAPID PLANT POWER REDUCTION, AND concurrently with this Procedure, reduce Plant Power to 50% within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

3.2 WHEN Plant Power is 50%, THEN in accordance with OP-901-212, RAPID PLANT POWER REDUCTION, AND concurrently with this Procedure, be in Mode 3 within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months AND Mode 5 in the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

Examiner Note

These conditions will be met. The CRS should enter OP-901-212 and perform it concurrently with OP-901-202.

Steps 4-6 are not applicable to the event. Steps 7 through 15 of Steam Generator Tube Leakage or High Activity are listed here. The CRS should begin the steps of Rapid Plant Power Reduction before working these steps. The steps of OP-901-212, Rapid Plant Power Reduction follow step 15 of OP-901-202.

Scenario 4, Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 3/4 Page 8 of 23 Event

Description:

Steam Generator 2 develops a tube leak/ Rapid Plant Power Reduction Time Position Applicants Actions or Behavior SRO 7. Notify Chemistry Department to perform the following:

7.1 Provide current Plant status including the following:

Primary to Secondary Leakrate

Primary to Secondary Leakage Rate of Change

Plant action(s) Operations is OR will be implementing (example: plant shutdown, rapid plant shutdown, monitoring) 7.2 Carry out actions in accordance with UNT-005-032, STEAM GENERATOR PRIMARY-TO-SECONDARY LEAKAGE.

7.3 Begin sampling Steam Generators for activity.

7.4 Quantify Steam Generator Tube leakage.

SRO 8. Notify Radiation Protection to carry out the actions of UNT-005-032, STEAM GENERATOR PRIMARY-TO-SECONDARY LEAKAGE.

BOP 9. Verify BD-303, DISCHARGE TO WASTE, Locked Closed.

BOP 10. Verify BD-1162, BD FLASH TANK VENT, Closed.

BOP 11. Verify CD-145, CD DUMP TO WASTE POND, Closed.

11.1 Notify Chemistry prior to dumping Condensate from the Condenser Hotwell to the CST.

BOP 12. Establish AND monitor a PMC Trend of the following PMC points:

C48304 PRI TO SEC LEAKAGE

C48305 PRI TO SEC LEAK RATE CHANGE (GPD/HR)

C48251 RE5501 CH1 LEAK RATE

C48252 RE5501 CH2 LEAK RATE N/A 13. IF Primary to Secondary Leakage is 5 GPD AND <15 GPD THEN monitor the N-16 and Condenser Air Evacuation Radiation Monitors every 15 minutes for rising trends SRO 14. Advise Shift Manager to perform the following:

Review EP-001-001, RECOGNITION AND CLASSIFICATION OF EMERGENCY CONDITIONS.

Review OI-035-000, NOTIFICATION MATRIX, AND as a minimum notify the Duty Plant Manager AND Duty Operations Manager as soon as possible.

Scenario 4, Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 3/4 Page 9 of 23 Event

Description:

Steam Generator 2 develops a tube leak/ Rapid Plant Power Reduction Time Position Applicants Actions or Behavior NOTE Until arrangements are made for disposal of radioactively contaminated resin, Condensate Polisher Vessels should NOT be placed in service with resin loaded in the vessel.

N/A 15. Remove from service ANY Condensate Polisher Vessels which are loaded with resin in accordance with OP-003-031, CONDENSATE POLISHER/BACKWASH TREATMENT.

15.1 Do not place in service any condensate polisher vessel loaded with resin without the coordination of Chemistry.

OP-901-212, Rapid Plant Power Reduction NOTE (1) A rapid power reduction is defined as approximately 30 MW/minute load reduction on the main turbine.

(2) Power Reduction may be stopped at any point.

(3) Some Steps of this procedure may not be applicable due to plant conditions. In these cases SM/CRS may NA the step.

(4) Steps within this procedure may be performed concurrently or out of sequence with SM/CRS concurrence.

(5) During power reduction PMC PID C24650, COLSS DESCENDING PWR TRACK (DUMOUT19),

will automatically select and display the correct power indication. OP-010-003, Plant Startup, provides greater detail on which power indications are displayed by PID C24650 based on power level and whether or not the UFM is in service.

ATC 1. Begin RCS Boration by one of the following methods:

SRO/ATC 1.1 0 up to 170 EFPD:

1.1.1 Direct Boration Or 1.1.2 Emergency Boration using two Charging Pumps OP-002-005, Chemical and Volume Control System, Section 6.7, Direct Boration CAUTION (1) THIS SECTION AFFECTS REACTIVITY. THIS EVOLUTION SHOULD BE CROSS-CHECKED AND COMPLETED PRIOR TO LEAVING CP-4.

(2) AT LEAST ONE REACTOR COOLANT PUMP IN EACH LOOP SHOULD BE OPERATING PRIOR TO PERFORMING DIRECT BORATION OPERATIONS TO ENSURE PROPER CHEMICAL MIXING.

Scenario 4, Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 3/4 Page 10 of 23 Event

Description:

Steam Generator 2 develops a tube leak/ Rapid Plant Power Reduction Time Position Applicants Actions or Behavior ATC 6.7.1 Inform SM/CRS that this Section is being performed.

NOTE When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change.

1.2.1.1 Power Defect Vs Power Level

1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD)

1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD)

1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD)

1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC (340 EFPD)

ATC 6.7.2 At SM/CRS discretion, calculate volume of Boric Acid to be added on Attachment 11.6, Calculation of Boric Acid Volume for Direct Boration or VCT Borate Makeup Mode.

ATC 6.7.3 Set Boric Acid Makeup Batch Counter to volume of Boric Acid desired.

ATC 6.7.4 Verify Boric Acid Makeup Pumps selector switch aligned to desired Boric Acid Makeup Pump A(B).

ATC 6.7.5 Place Direct Boration Valve, BAM-143, control switch to AUTO.

ATC 6.7.6 Place Makeup Mode selector switch to BORATE.

ATC 6.7.7 Verify selected Boric Acid Makeup Pump A(B) Starts.

ATC 6.7.8 Verify Direct Boration Valve, BAM-143, Opens.

NOTE The Boric Acid Flow Totalizer will not register below 3 GPM. The Boric Acid Flow Totalizer is most accurate in the range of 10 - 25 GPM.

Scenario 4, Revision 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 3/4 Page 11 of 23 Event

Description:

Steam Generator 2 develops a tube leak/ Rapid Plant Power Reduction Time Position Applicants Actions or Behavior ATC 6.7.9 If manual control of Boric Acid flow is desired, then perform the following: