ML14234A349
| ML14234A349 | |
| Person / Time | |
|---|---|
| Site: | Cooper  |
| Issue date: | 08/04/2014 |
| From: | Vincent Gaddy Operations Branch IV |
| To: | Nebraska Public Power District (NPPD) |
| References | |
| 50-298/14-07 50-298/OL-14 | |
| Download: ML14234A349 (245) | |
Text
ES-301 Administrative Topics Outline Form ES-301-1 Facility: ____________Cooper Nuclear Station____________ Date of Examination: _____2014____
Examination Level: RO X SRO Operating Test Number: ____1_____
Administrative Topic (see Note) Type Describe activity to be performed Code*
Conduct of Operations R,D Suppression Pool Temp Calculation SKL034-21-131 K/A: 2.1.12 (2.9/4.0)
Conduct of Operations R,N Determine RHR Pump NPSH Flow Limit SKL034-50-XX K/A: 2.1.25 (3.9/4.2)
Equipment Control R,D Perform Diesel Generator Fuel Oil Availability SKL034-50-78 K/A 2.2.37 (3.6/4.6)
Radiation Control R,D Radiation Protection Table Top SKL034-30-63 K/A 2.3.13 (3.4/3.8)
Emergency Procedures/Plan NOTE: All items (5 total) are required for SROs. RO applicants require only 4 items unless they are retaking only the administrative topics, when all 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)
Rev 2 (6/13/14)
ES-301 Administrative Topics Outline Form ES-301-1 Facility: ____________Cooper Nuclear Station____________ Date of Examination: _____2014____
Examination Level: RO SRO X Operating Test Number: __________
Administrative Topic (see Note) Type Describe activity to be performed Code*
R,N Determine required Actions for Plant Chemistry Out of Conduct of Operations Specification SKL034-50-80 K/A 2.1.34 (SRO 3.5)
R,D Determine Shift Staffing Requirements for Mode Change Conduct of Operations K/A 2.1.4 (SRO 3.4)
SKL034-20-114 R,D Determine Post-Maintenance Testing Requirements Equipment Control K/A 2.2.7 (2.0/3.2)
SKL034-50-18 R,D Radiation Protection Table Top Radiation Control K/A 2.3.13 (3.4/3.8)
SKL034-30-63 S,D Protective Action Recommendation (PAR) Table Top X Emergency Procedures/Plan K/A 2.4.44 (2.1 / 4.0)
SKL034-30-61 NOTE: All items (5 total) are required for SROs. RO applicants require only 4 items unless they are retaking only the administrative topics, when all 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)
Rev 2 (6/13/14)
ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Facility: ____Cooper Nuclear Station_______________ Date of Examination: _____2014____
Exam Level: RO X 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)
System / JPM Title Type Code* Safety Function
- a. Placing SDG In Service From Control Room S, L, D, P 6 K/A 262001.K4.06 (3.6 / 3.9) and 264000.A4.04 (3.7/3.7)
- b. Shifting from Single Element to Auto (3 element) A, S, D 2 K/A 259002 A4.06 (3.1/3.2)
- c. Recover from Manual Scoop Tube Operations S, D 1 K/A A.2.05 (RO 3.1 / SRO 3.1) A 2.09 (RO3.1 / SRO 3.0)
- d. Transfer RPSPP1B from RPS MG Set B to CDP-1A S, N 7 K/A 212000 A1.11 (3.4 / 3.3) and 212000.A2.02 (3.7/3.9)
- e. RPV Depressurization with RWCU A, S, E, L, N 3 K/A 204000 A4.03 (3.2 / 3.6), 204000.A1.04 (2.8/2.8)
- g. Startup the Suppression Pool Cooling Mode of RHR (Alternate Path) A, S, D 5 K/A 219000 A4.02 (3.7 / 3.5)
- h. Separation of REC Critical Loops S, E, M 8 K/A 295018 A1A.03 (3.3 / 3.4) and AK3.07 (3.1/3.2)
In-Plant Systems (3 for RO); (3 for SRO-I); (3 or 2 for SRO-U)
- i. Operate the Diesel Fire Pump Manually A, E, D 8 K/A 286000; A4.06(3.4/3.4)
- j. Place 24 VDC Batteries and Associated Chargers in service D 6 K/A: 263000 K4.01(3.1/3.4) and 2.2.2 (4.6/4.1)
@ 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 Rev 2 (6/13/14)
(A)lternate path 4-6 / 4-6 / 2-3 (C)ontrol room (D)irect from bank 9/8/4 (E)mergency or abnormal in-plant 1/1/1 (EN)gineered safety feature - / - / 1 (control room system)
(L)ow-Power / Shutdown 1/1/1 (N)ew or (M)odified from bank including 1(A) 2/2/1 (P)revious 2 exams 3 / 3 / 2 (randomly selected)
(R)CA 1/1/1 (S)imulator Rev 2 (6/13/14)
ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Facility: ____Cooper Nuclear Station_______________ Date of Examination: _____2014____
Exam Level: RO SRO-I X 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)
System / JPM Title Type Code* Safety Function
- a. Placing SDG In Service From Control Room S, L, D, P 6 K/A 262001.K4.06 (3.6 / 3.9) and 264000.A4.04 (3.7/3.7)
- b. Shifting from Single Element to Auto (3 element) A, S, D 2 K/A 259002 A4.06 (3.1/3.2) c.
- d. Transfer RPSPP1B from RPS MG Set B to CDP-1A S, N 7 K/A 212000 A1.11 (3.4 / 3.3) and 212000.A2.02 (3.7/3.9)
- e. RPV Depressurization with RWCU A, S, E, L, N 3 K/A 204000 A4.03 (3.2 / 3.6), 204000.A1.04 (2.8/2.8)
- f. Start HPCI From The ASD Room S, D, EN 4 K/A 206000 A1.02 (4.2/4.2) g Startup the Suppression Pool Cooling Mode of RHR (Alternate Path) A, S, D 5 K/A 219000 A4.02 (3.7 / 3.5)
- h. Separation of REC Critical Loops S, E, M 8 K/A 295018 A1A.03 (3.3 / 3.4) and AK3.07 (3.1/3.2)
In-Plant Systems (3 for RO); (3 for SRO-I); (3 or 2 for SRO-U)
- i. Operate the Diesel Fire Pump Manually A, E, D 8 K/A 286000; A4.06(3.4/3.4)
- j. Place 24 VDC Batteries and Associated Chargers in service D 6 K/A: 263000 K4.01(3.1/3.4) and 2.2.2 (4.6/4.1)
- l. k. Conduct Alternate Rod Insertion (Vent Scram Air Header) E, R, D 1 K/A: 295037 EA1.05 (3.9/4.0)
@ 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 Rev 2 (6/13/14)
(A)lternate path 4-6 / 4-6 / 2-3 (C)ontrol room (D)irect from bank 9/8/4 (E)mergency or abnormal in-plant 1/1/1 (EN)gineered safety feature - / - / 1 (control room system)
(L)ow-Power / Shutdown 1/1/1 (N)ew or (M)odified from bank including 1(A) 2/2/1 (P)revious 2 exams 3 / 3 / 2 (randomly selected)
(R)CA 1/1/1 (S)imulator Rev 2 (6/13/14)
ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Facility: ____Cooper Nuclear Station_______________ Date of Examination: _____2014____
Exam Level: RO SRO-I SRO-U X Operating Test No.: _____ 1 _____
Control Room Systems (8 for RO); (7 for SRO-I); (2 or 3 for SRO-U, including 1 ESF)
System / JPM Title Type Code* Safety Function a.
b.
c.
- d. Transfer RPSPP1B from RPS MG Set B to CDP-1A S, N 7 K/A 212000 A1.11 (3.4 / 3.3) and 212000.A2.02 (3.7/3.9)
- e. RPV Depressurization with RWCU K/A 204000 A4.03 (3.2 / 3.6), 204000.A1.04 (2.8/2.8) A, S, E, L, N 3
h.
In-Plant Systems (3 for RO); (3 for SRO-I); (3 or 2 for SRO-U)
- i. Operate the Diesel Fire Pump Manually A, E, D 8 K/A 286000; A4.06(3.4/3.4) j.
@ 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 (C)ontrol room (D)irect from bank 9/8/4 (E)mergency or abnormal in-plant 1/1/1 (EN)gineered safety feature - / - / 1 (control room system)
(L)ow-Power / Shutdown 1/1/1 (N)ew or (M)odified from bank including 1(A) 2/2/1 (P)revious 2 exams 3 / 3 / 2 (randomly selected)
(R)CA 1/1/1 (S)imulator Rev 2 (6/13/14)
Nebraska Public Power District SKL034-21-131 (41928)
Cooper Nuclear Station Page 1 of 12 Job Performance Measure for Operations Revision 03 Task No.: 200225A0501 Task
Title:
Suppression Pool Temp Calculation (Alternate Path)
Trainee: Examiner:
Pass Fail Examiner Signature: Date:
ALTERNATE PATH JPM Additional Program Information:
- 1. Appropriate Performance Locations: Control Room / Classroom / Simulator
- 3. Evaluation Method: Simulate Perform
- 4. Performance Time: 10 minutes
- 5. K/A: 2.1.25 (3.9/4.2)
NOTE: THIS IS AN ALTERNATE PATH JPM. Some temperatures are upscale and an alternate method must be used to obtain the average temperature.
Directions to Examiner:
- 1. The intent of this JPM is to present a trainee a set of conditions for determination of average Torus temperature upon loss of SPDS and to make expected recommendations to the Control Room Supervisor, in accordance with procedure 5.8.9, Average Suppression Pool Temperature Calculation.
- 2. If this JPM is performed on the Simulator, only the cues preceded by "#" should be given.
- 3. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes/comments section below.
- 4. Give the trainee his copy of the Directions to the Trainee (Attachment 2) when ready to start the JPM.
- 5. IF NOT performing in the simulator, give the trainee a copy of Attachment 3.
- 6. Brief the trainee and tell the trainee to begin.
Notes/Comments: ____________________________________________________________
Nebraska Public Power District SKL034-21-131 (41928)
Cooper Nuclear Station Page 2 of 12 Job Performance Measure for Operations Revision 03 Task No.: 200225A0501 Task
Title:
Suppression Pool Temp Calculation (Alternate Path)
Directions to Trainee:
When I tell you to begin, you are to use the provided attachment to determine average Torus temperature and make expected recommendations to the Control Room Supervisor, in accordance with procedure 5.8.9, Average Suppression Pool Temperature Calculation.
Before you start, I will state the general plant conditions, the Initiating Cues, and answer any questions you may have.
During task performance, state the actions you are taking, e.g.: repositioning controls and observing instrumentation.
If being simulated in the Control Room:
When simulating, physically point to any meters, gauges, recorders and controls you would be using. State the position of controls as you would have manipulated them in order to complete the assigned task.
General Conditions:
- 1. RHR A Loop is in Torus cooling
- 2. Activities have been in progress that added significant heat to the torus.
- 3. PMIS/SPDS is unavailable.
General
References:
- 1. Procedure 5.8.9; Average Suppression Pool Temperature Calculations General Tools and Equipment:
- 1. None Special Conditions, References, Tools, Equipment:
- 1. Critical checks denoted by "*".
- 2. Simulator cues denoted by "#".
Nebraska Public Power District SKL034-21-131 (41928)
Cooper Nuclear Station Page 3 of 12 Job Performance Measure for Operations Revision 03 Task No.: 200225A0501 Task
Title:
Suppression Pool Temp Calculation (Alternate Path)
Task Standards:
- 1. The examinee determines the normal temperature recorders (TR-24 and TR-25) have an upscale indication and transitions to the temperature recorder (TR-131) for the running RHR loop which is in suppression pool cooling and records the temperature of the heat exchanger inlet.
- 2. 100% of critical elements successfully completed without error.
- 3. 100% of safety and radiological work practices.
Initiating Cue(s):
You are to determine average Torus temperature per ESP 5.8.9. Average Suppression Pool Temperature Calculation.
Return the completed Attachment 1 of 5.8.9 to the Control Room Supervisor when you have completed this task.
Nebraska Public Power District SKL034-21-131 (41928)
Cooper Nuclear Station Page 4 of 12 Job Performance Measure for Operations Revision 03 Task No.: 200225A0501 Task
Title:
Suppression Pool Temp Calculation (Alternate Path)
Start Time: ___________
Performance Checklist Standards Sat Unsat
- 1. Obtains Procedure Obtained Procedure 5.8.9, Attachment 1.
5.8.9, SP Temperature Calculations
- 2. Record time. The operator recorded the current time on Attachment 1 of 5.8.9.
NOTE to Examiner: Examinee may not record readings once upscale temperatures are noticed.
- 3. Notes that two The operator recorded the four (4) highest temperatures are suppression pool temperatures but notes that upscale and proceeds two are upscale and proceeds to Step 3.2.
to Step 3.2.
CUE: When the Operator finds the correct recorders provide them with the marked up pictures of the recorders (Attachment 3) and tell him to use them instead of the values on the panel mounted recorders.
- 4. Recognizes that A The operator noted that A RHR is in Torus RHR is in Torus Cooling and performs step 3.2.1.
Cooling.
CUE: When the Operator finds the correct recorder provide them with the marked up picture of the recorder (Attachment 3) and tell him to use them instead of the values on the panel mounted recorder.
- 5. Finds temperature on The operator noted that the temperature for PC-TR-131 for RHR A the suction of the RHR loop in SPC is 120°F Loop. on RHR-TR-131 CH1.
Allowable values: 120°F
Nebraska Public Power District SKL034-21-131 (41928)
Cooper Nuclear Station Page 5 of 12 Job Performance Measure for Operations Revision 03 Task No.: 200225A0501 Task
Title:
Suppression Pool Temp Calculation (Alternate Path)
Performance Checklist Standards Sat Unsat
- 6. Returns the completed The operator returned the completed Attachment 1 to the Attachment 1 to the Control Room Supervisor.
examiner.
The CRS accepts the completed form.
Stop Time: __________ Stop Time: __________
Nebraska Public Power District SKL034-21-131 (41928)
Cooper Nuclear Station Page 6 of 12 Job Performance Measure for Operations Revision 03 Task No.: 200225A0501 Task
Title:
Suppression Pool Temp Calculation (Alternate Path)
ATTACHMENT 1 SIMULATOR SET-UP A. Materials required None B. Initialize the Simulator in any IC that has or had the reactor at power (IC-18, 19 or 20 suggested)
Batch File name - None.
C. Change the Simulator conditions from those of the IC as follows:
- 1. Triggers Number File Name Description None
- 2. Malfunctions Number Title Trigger TD Severity Ramp Initial None
- 3. Remotes Number Title Trigger Value Ramp None
- 4. Overrides
Nebraska Public Power District SKL034-21-131 (41928)
Cooper Nuclear Station Page 7 of 12 Job Performance Measure for Operations Revision 03 Task No.: 200225A0501 Task
Title:
Suppression Pool Temp Calculation (Alternate Path)
Instrument Tag Trigger TD Value Ram p
PC-TR-24 Channel 1 20A1AR1 Chan 1 N/A N/A 115.10F N/A PC-TR-24 Channel 2 20A1AR1 Chan 2 N/A N/A 250.00F N/A PC-TR-24 Channel 3 20A1AR1 Chan 3 N/A N/A 121.90F N/A PC-TR-24 Channel 4 20A1AR1 Chan 4 N/A N/A 124.90F N/A PC-TR-24 Channel 5 20A1AR1 Chan 5 N/A N/A 118.20F N/A PC-TR-24 Channel 6 20A1AR1 Chan 6 N/A N/A 120.30F N/A PC-TR-24 Channel 7 20A1AR1 Chan 7 N/A N/A 121.00F N/A PC-TR-24 Channel 8 20A1AR1 Chan 8 N/A N/A 118.10F N/A PC-TR-25 Channel 1 20A1AR2 Chan 1 N/A N/A 118.10F N/A PC-TR-25 Channel 2 20A1AR2 Chan 2 N/A N/A 128.20F N/A PC-TR-25 Channel 3 20A1AR2 Chan 3 N/A N/A 124.90F N/A PC-TR-25 Channel 4 20A1AR2 Chan 4 N/A N/A 250.00F N/A PC-TR-25 Channel 5 20A1AR2 Chan 5 N/A N/A 115.20F N/A PC-TR-25 Channel 6 20A1AR2 Chan 6 N/A N/A 124.30F N/A PC-TR-25 Channel 7 20A1AR2 Chan 7 N/A N/A 117.00F N/A PC-TR-25 Channel 8 20A1AR2 Chan 8 N/A N/A 125.10F N/A RHR-TR-131 Channel 1 07A1AR6 Chan 1 N/A N/A 1200F N/A RHR-TR-131 Channel 2 07A1AR6 Chan 2 N/A N/A 950F N/A RHR-TR-131 Channel 3 07A1AR6 Chan 3 N/A N/A 1180F N/A RHR-TR-131 Channel 4 07A1AR6 Chan 4 N/A N/A 880F N/A RHR-TR-131 Channel 5 07A1AR6 Chan 5 N/A N/A 980F N/A RHR-TR-131 Channel 6 07A1AR6 Chan 6 N/A N/A 980F N/A
Nebraska Public Power District SKL034-21-131 (41928)
Cooper Nuclear Station Page 8 of 12 Job Performance Measure for Operations Revision 03 Task No.: 200225A0501 Task
Title:
Suppression Pool Temp Calculation (Alternate Path)
- 5. Panel Set-up (suggested. Any setup is allowed that supports performance of this JPM.
- a. Place the Simulator in RUN.
- b. Insert Batch File Note: If this JPM is to be performed more than once, snap the Simulator into an IC after the panel set-up is complete.
Nebraska Public Power District SKL034-21-131 (41928)
Cooper Nuclear Station Page 9 of 12 Job Performance Measure for Operations Revision 03 Task No.: 200225A0501 ATTACHMENT 2 Directions to Trainee:
When I tell you to begin, you are to use the provided attachment to determine average Torus temperature and make expected recommendations to the Control Room Supervisor, in accordance with procedure 5.8.9, Average Suppression Pool Temperature Calculation.
Before you start, I will state the general plant conditions, the Initiating Cues, and answer any questions you may have.
During task performance, state the actions you are taking, e.g.: repositioning controls and observing instrumentation.
If being simulated in the Control Room:
When simulating, physically point to any meters, gauges, recorders and controls you would be using. State the position of controls as you would have manipulated them in order to complete the assigned task.
General Conditions:
- 1. RHR A Loop is in Torus cooling
- 2. Activities have been in progress that added significant heat to the torus.
- 3. PMIS/SPDS is unavailable.
Initiating Cue:
You are to determine average Torus temperature per ESP 5.8.9. Average Suppression Pool Temperature Calculation.
Return the completed Attachment 1 of 5.8.9 to the Control Room Supervisor when you have completed this task.
Nebraska Public Power District SKL034-21-131 (41928)
Cooper Nuclear Station Page 10 of 12 Job Performance Measure for Operations Revision 03 Task No.: 200225A0501 ATTACHMENT 3 SUPPR POOL TEMP RECORDER PC-TR-24
Nebraska Public Power District SKL034-21-131 (41928)
Cooper Nuclear Station Page 11 of 12 Job Performance Measure for Operations Revision 03 Task No.: 200225A0501 ATTACHMENT 3 SUPPR POOL TEMP RECORDER PC-TR-25
Nebraska Public Power District SKL034-21-131 (41928)
Cooper Nuclear Station Page 12 of 12 Job Performance Measure for Operations Revision 03 Task No.: 200225A0501 ATTACHMENT 3 RHR HEAT EXCHANGER TEMPERATURE RECORDER RHR-TR-131
Nebraska Public Power District SKL034-50-XX(xxxx)
Cooper Nuclear Station Page 1 of 7 Job Performance Measure for Operations Revision 00 Task No.: 200283A0501
Title:
Determine RHR Pump NPSH Flow Limit Trainee: Examiner:
Pass Fail Examiner Signature: Date:
Additional Program Information:
- 1. Appropriate Performance Locations: CR / SIM
- 3. Evaluation Method: Perform
- 4. Performance Time: 10 minutes
- 5. NRC K/A Rating G 2.1.25 (3.9/4.2)
Directions to Examiner:
- 1. This JPM evaluates the trainee's ability to determine RHR pump NPSH flow limit based on low suppression pool level and elevated suppression pool temperature.
- 2. If this JPM is performed on the Simulator, only the cues preceded by "#" should be given.
- 3. Observe the trainee during performance of the JPM for proper use of self-checking methods.
- 4. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes section below.
- 5. Give the trainee Attachment 2.
- 6. Brief the trainee, and tell the trainee to begin.
Notes: ______________________________________________________________________
Nebraska Public Power District SKL034-50-XX(xxxx)
Cooper Nuclear Station Page 2 of 7 Job Performance Measure for Operations Revision 00 Task No.: 200283A0501
Title:
Determine RHR Pump NPSH Flow Limit Directions to Trainee:
When I tell you to begin, you are to determine the RHR pump NPSH flow limit based upon plant status. Before you start, I will state the general plant conditions, the initiating cues and answer any questions you may have.
General Conditions:
- 1. RPV level is -100 inches corrected fuel zone.
- 2. One RHR pump is operating and RHR-FI-133A RHR-A FLOW is indicating 8000 gpm.
- 3. PCLRPR-1A, CNTMNT/TORUS PRESS & LVL RCDR, Channel 2, Torus LVL indicating 7.0 feet.
- 4. PCLRPR-1A, CNTMNT/TORUS PRESS & LVL RCDR, Channel 5, Torus Press indicating 3.7 psig.
- 5. Average Torus water temperature is 175°F General
References:
- 1. Procedure 5.8 General Tools and Equipment:
- 1. Scientific calculator.
- 2. Straight edge.
Special Conditions, References, Tools, Equipment:
- 1. Critical checks denoted in bold.
- 2. Simulator cues denoted by "#".
Task Standards:
- 2. 100% of critical elements successfully completed without error.
- 3. 100% of safety and radiological work practices.
Nebraska Public Power District SKL034-50-XX(xxxx)
Cooper Nuclear Station Page 3 of 7 Job Performance Measure for Operations Revision 00 Task No.: 200283A0501
Title:
Determine RHR Pump NPSH Flow Limit Initiating Cue(s):
An event has occurred and the CRS has asked you to determine the maximum allowable RHR flow based upon the NPSH limit for the running RHR pump. Turn in your determination to the examiner when complete.
NOTE: Tell the trainee to begin.
Nebraska Public Power District SKL034-50-XX(xxxx)
Cooper Nuclear Station Page 4 of 7 Job Performance Measure for Operations Revision 00 Start Time: ____________
Performance Checklist Standards Sat Unsat
- 1. Obtain Procedure Obtained EOP/SAG GRAPHS flowchart.
- 2. Calculate Torus Calculated Torus Overpressure.
Overpressure
- 3. Determined Determined Torus Overpressure line on overpressure line Graph 5 is the 5 psig line.
Note to Examiner: Acceptable flow rate range is 7400 to 7600 gpm.
- 4. Determined Determined maximum RHR flow allowed is maximum flow 7500 gpm.
Stop Time: __________ Total Time: ___________
Nebraska Public Power District SKL034-50-XX(xxxx)
Cooper Nuclear Station Page 5 of 7 Job Performance Measure for Operations Revision 00 ATTACHMENT 1 ANSWER KEY 3.7 7
1.29 3
4.99 175 degrees 5 psig Line 7500 gpm
Nebraska Public Power District SKL034-50-XX(xxxx)
Cooper Nuclear Station Page 6 of 7 Job Performance Measure for Operations Revision 00 ATTACHMENT 2 Directions to Trainee:
When I tell you to begin, you are to determine the RHR pump NPSH flow limit based upon plant status. Before you start, I will state the general plant conditions, the initiating cues and answer any questions you may have.
General Conditions:
- 1. RPV level is -100 inches corrected fuel zone.
- 2. One RHR pump is operating and RHR-FI-133A RHR-A FLOW is indicating 8000 gpm.
- 3. PCLRPR-1A, CNTMNT/TORUS PRESS & LVL RCDR, Channel 2, Torus LVL indicating 7.0 feet.
- 4. PCLRPR-1A, CNTMNT/TORUS PRESS & LVL RCDR, Channel 5, Torus Press indicating 3.7 psig.
- 5. Average Torus water temperature is 175°F Initiating Cues:
An event has occurred and the CRS has asked you to determine the maximum allowable RHR flow based upon the NPSH limit for the running RHR pump. Turn in your determination to the examiner when complete.
Nebraska Public Power District SKL034-50-XX(xxxx)
Cooper Nuclear Station Page 7 of 7 Job Performance Measure for Operations Revision 00 ATTCHMENT 2
Nebraska Public Power District SKL034-50-78(53501)
Cooper Nuclear Station Page 1 of 5 Job Performance Measure for Operations Revision 00 Task No.: 264029O0204
Title:
Perform Diesel Generator Fuel Oil Availability Trainee: Examiner:
Pass Fail Examiner Signature: Date:
Additional Program Information:
- 1. Appropriate Performance Locations: CR / SIM
- 3. Evaluation Method: Perform
- 4. Performance Time: 16 minutes
- 5. K/A: 2.2.37 3.6/4.6 Directions to Examiner:
- 1. This JPM evaluates the trainee's ability to determine Diesel Generator fuel oil availability.
- 2. If this JPM is performed on the Simulator, only the cues preceded by "#" should be given.
- 3. Observe the trainee during performance of the JPM for proper use of self-checking methods.
- 4. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes section below.
- 5. Give the trainee Attachment 2.
- 6. Brief the trainee, and tell the trainee to begin.
Notes: ______________________________________________________________________
Nebraska Public Power District SKL034-50-78(53501)
Cooper Nuclear Station Page 2 of 5 Job Performance Measure for Operations Revision 00 Task No.: 264029O0204
Title:
Perform Diesel Generator Fuel Oil Availability Directions to Trainee:
When I tell you to begin, you are to determine the availability of the Diesel Generator fuel oil storage tanks.
General Conditions:
- 1. A loss of off-site power event has occurred.
- 2. The crew has entered Procedure 5.3EMPWR.
- 3. Diesel Generator 1 is currently the only power source available and is powering 4160V Bus 1F.
- 4. NLO has reported sounding TANK A indicated 6 feet 0 inches.
- 5. NLO has reported sounding TANK B indicated 9 feet 7 inches.
General
References:
- 1. Procedure 5.3EMPWR General Tools and Equipment:
- 1. Calculator.
Special Conditions, References, Tools, Equipment:
- 1. Critical checks denoted in bold.
- 2. Simulator cues denoted by "#".
Task Standards:
- 1. Correctly calculated total DG fuel oil storage tank availability per Procedure 5.3EMPWR.
- 2. 100% of critical elements successfully completed without error.
- 3. 100% of safety and radiological work practices.
Initiating Cue(s):
The Control Room Supervisor has directed you to determine the total DG storage tank availability so he can determine if the single DG fuel oil requirement for Design Basis Accident requirements are met per 5.3 EMPWR. Inform the CRS of the total gallons available.
NOTE: Tell the trainee to begin.
Nebraska Public Power District SKL034-50-78(53501)
Cooper Nuclear Station Page 3 of 5 Job Performance Measure for Operations Revision 00 Task No.: 264029O0204
Title:
Perform Diesel Generator Fuel Oil Availability Start Time: ____________
Performance Checklist Standards Sat Unsat
- 1. Obtain Procedure Obtained Procedure 5.3EMPWR.
- 2. Calculate total Calculated total gallons using Attachment 4, gallons. Table 1 and Table 2.
- 3. Hand in work Signed and handed in completed Attachment 2.
Note to Examiner: Total gallons determined must be exact. There is no interpretation required for Attachment 4,Table 2 of 5.3EMPWR.
- 4. Total gallons agree with Answer Key The calculated Total Gallons was 42,111.
(Attachment 1)
Stop Time: __________ Total Time: ___________
Nebraska Public Power District SKL034-50-78(53501)
Cooper Nuclear Station Page 4 of 5 Job Performance Measure for Operations Revision 00 Task No.: 264029O0204
Title:
Perform Diesel Generator Fuel Oil Availability ATTACHMENT 1 ANSWER KEY TABLE 1 TANK A TANK B CORRECTED CORRECTED DATE/ LEVEL LEVEL VOLUME LEVEL LEVEL VOLUME TOTAL TIME (FT/IN) (FT/IN) (GAL) (FT/IN) (FT/IN) (GAL) (GAL)
Current 60 511 15,088 97 96 27,023 42,111
Nebraska Public Power District SKL034-50-78(53501)
Cooper Nuclear Station Page 5 of 5 Job Performance Measure for Operations Revision 00 ATTACHMENT 2 Directions to Trainee:
When I tell you to begin, you are to determine the availability of the Diesel Generator fuel oil storage tanks.
General Conditions:
- 1. A loss of off-site power event has occurred.
- 2. The crew has entered Procedure 5.3EMPWR.
- 3. Diesel Generator 1 is currently the only power source available and is powering 4160V Bus 1F.
- 4. NLO has reported sounding TANK A indicated 6 feet 0 inches.
- 5. NLO has reported sounding TANK B indicated 9 feet 7 inches.
Initiating Cues:
The Control Room Supervisor has directed you to determine the total DG storage tank availability so he can determine if the single DG fuel oil requirement for Design Basis Accident requirements are met per 5.3 EMPWR. Inform the CRS of the total gallons available.
______________Gallons Total Fuel Oil currently available.
Signature
Nebraska Public Power District SKL034-30-63 (44051)
Cooper Nuclear Station Page 1 of 5 Job Performance Measure for Operations Revision 00 Task No.:
Task
Title:
Radiation Protection Table Top Trainee: Examiner:
Pass Fail Examiner Signature: Date:
Additional Program Information:
- 1. Appropriate Performance Locations: CR, SIM, Classroom
- 3. Evaluation Method: Simulate Perform
- 4. Performance Time: 10 minutes
- 5. NRC K/A 2.3.13 (3.4/3.8)
Directions to Examiner:
- 1. This JPM evaluates the trainee's ability to determine if certain work can be performed within the confines of the Code of Federal Regulations and CNS procedures.
- 2. This JPM can be performed any place the operator can access appropriate procedures.
- 3. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes section below.
- 4. Give the trainee his copy of the Directions to the Trainee (Attachment 1) when ready to start the JPM.
- 5. Brief the trainee and tell the trainee to begin.
Notes: ______________________________________________________________________
Directions to Trainee:
When I tell you to begin, you are to determine whether John Doe can perform RHR valve work.
If you find he cannot perform the work state the reason why. If John Doe can perform the work, state what authorization, if any is required prior to performing the work. Before you start, I will state the general plant conditions, the Initiating Cues and answer any questions you may have.
Nebraska Public Power District SKL034-30-63 (44051)
Cooper Nuclear Station Page 2 of 5 Job Performance Measure for Operations Revision 00 Task No.:
Task
Title:
Radiation Protection Table Top General Conditions:
- 1. The plant is shutdown to perform RHR valve work.
- 2. John Doe has been selected to repair the valve.
General
References:
- 1. 10CFR20
- 2. 9.ALARA.1, PERSONNEL DOSIMETRY AND OCCUPATIONAL RADIATION EXPOSURE PROGRAM.
General Tools and Equipment:
- 1. None.
Special Conditions, References, Tools, Equipment:
- 1. Critical checks denoted in bold.
Task Standards:
- 1. The student determines the work can be performed and the department personnel that must approve the dose.
- 2. 100% of critical elements successfully completed without error.
Initiating Cue(s):
John Doe has been selected to perform work on an RHR valve. Performance of the work is expected to result in a whole body dose of 550 mRem. The Shift Manager directs you to determine based on John Doe's dose history, whether he is capable of performing this work.
When I tell you to begin, you are to determine whether John Doe can perform the valve work. If you find he cannot perform the work state the reason why. If John Doe can perform the work, state what authorization, if any is required prior to performing the work. Before you start, I will state the general plant conditions, the Initiating Cues and answer any questions you may have.
Nebraska Public Power District SKL034-30-63 (44051)
Cooper Nuclear Station Page 3 of 5 Job Performance Measure for Operations Revision 00 Task No.:
Task
Title:
Radiation Protection Table Top Time Start: _________
Performance Checklist Standards Sat Unsat
- 2. Pertinent personal Dose 9.ALARA.1 step 6.7.2.1 Dose History was history is reviewed. reviewed.
- 3. Pertinent job dose projections for the job are Dose projections were reviewed.
reviewed.
- 4. Compares the job requirements to the amount Job requirements were reviewed.
of dose that can be received.
9.ALARA.1 step 6.2.1.2.
- 5. Calculates expected Expected cumulative dose was cumulative dose. calculated at 2.050 Rem on-site and 3.250 Rem total.
9.ALARA.1 step 6.2.1.2.
- 6. Off-site dose verified Verified off-site dose did not exceed 1.5 within limit.
Rem (1500 mrem).
9.ALARA.1 step 6.2.1.2.
Informed Shift Manager the work could be done, but the Department Manager,
- 7. Informs the SM that he RP Technical Supervisor, Radiation can perform this job. Protection Manager, and the GMPO must authorize the dose extension above 2,000 mRem.
Time Stop: __________ Total Time: ___________
Nebraska Public Power District SKL034-30-63 (44051)
Cooper Nuclear Station Page 4 of 5 Job Performance Measure for Operations Revision 00 ATTACHMENT 1 Directions to Trainee:
When I tell you to begin, you are to determine whether John Doe can perform RHR valve work.
If you find he cannot perform the work state the reason why. If John Doe can perform the work, state what authorization, if any is required prior to performing the work. Before you start, I will state the general plant conditions, the Initiating Cues and answer any questions you may have.
General Conditions:
- 1. The plant is shutdown to perform RHR valve work.
- 2. John Doe has been selected to repair the valve.
Initiating Cue(s):
John Doe has been selected to perform work on an RHR valve. Performance of the work is expected to result in a whole body dose of 550 mRem. The Shift Manager directs you to determine based on John Doe's dose history, whether he is capable of performing this work.
When I tell you to begin, you are to determine whether John Doe can perform the valve work. If you find he cannot perform the work state the reason why. If John Doe can perform the work, state what authorization, if any is required prior to performing the work. Before you start, I will state the general plant conditions, the Initiating Cues and answer any questions you may have.
Nebraska Public Power District SKL034-30-63 (44051)
Cooper Nuclear Station Page 5 of 5 Job Performance Measure for Operations Revision 00 ATTACHMENT 1 Your Pertinent Statistics John Doe's Age: 35 years Lifetime TEDE: 32 Rem On-Site TEDE so far this year: 1.5 Rem Off-Site TEDE so far this year: 1.2 Rem Pertinent Job Dose Projections for the one individual performing this job Projected Whole Body Dose: 550 mRem Results:
Perform the Job: Yes No Circle one If allowed to perform the work, whos authority is needed first?
Signature
Nebraska Public Power District SKL0345080 Cooper Nuclear Station Page 1 of 6 Job Performance Measure for Operations Revision 0 Task No.: 344077S0403
Title:
Determine the Action for Plant Chemistry Out of Specification Trainee: Examiner:
Pass Fail Examiner Signature: Date:
Additional Program Information:
- 1. Appropriate Performance Locations: Classroom
- 2. Appropriate Trainee level: SRO
- 3. Evaluation Method: Simulate
- 4. Performance Time: 20 minutes
- 5. NRC K/A 2.1.34 (SRO 3.5)
Directions to Examiner:
- 1. This JPM evaluates the trainee's ability to review Reactor Coolant Chemistry parameters and take actions for plant chemistry out of specifications in accordance with Procedure 2.4CHEM.
- 2. If this JPM is performed on the Simulator, only the cues preceded by "#" should be given.
- 3. Observe the trainee during performance of the JPM for proper use of self-checking methods.
- 4. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes/comments section below.
- 5. Brief the trainee and tell the trainee to begin.
Notes/Comments: ____________________________________________________________
Nebraska Public Power District SKL0345080 Cooper Nuclear Station Page 2 of 6 Job Performance Measure for Operations Revision 0 Task No.: 344077S0403
Title:
Determine the Action for Plant Chemistry Out of Specification Directions to Trainee:
When I tell you to begin, you are to perform a review of Reactor Coolant Chemistry data and inform me when actions are complete. Before you start, I will state the general plant conditions, the initiating cues and answer any questions you may have.
General Conditions:
- 1. The Plant has been Operating at 100% power for the past 120 days.
General
References:
- 1. Procedure 2.4 CHEM, Chemistry Parameter Out of Limit
- 2. TRM Section 3.4.1, Reactor Coolant System
- 3. Chemistry Procedure 8.3, Control Parameters and Limits General Tools and Equipment:
- 1. None Special Conditions, References, Tools, Equipment:
Procedure 2.4 CHEM, Chemistry Parameter Out of Limit TRM Section 3.4.1, Reactor Coolant System Chemistry Procedure 8.3, Control Parameters and Limits Critical checks denoted in bold.
Simulator cues denoted by "#".
Task Standards:
- 1. The operator recognizes that plant chemistry is out of specification and determines that TLCO 3.4.1 has been exceeded and TRM entry is required. The operator records the actions to be taken per Procedure 2.4CHEM Attachment 2 for out of specification conductivity conditions.
- 2. 100% of critical elements successfully completed without error.
- 3. 100% of safety and radiological work practices.
Nebraska Public Power District SKL0345080 Cooper Nuclear Station Page 3 of 6 Job Performance Measure for Operations Revision 0 Task No.: 344077S0403
Title:
Determine the Action for Plant Chemistry Out of Specification Initiating Cue(s):
The Shift Manager directs you, as the CRS, to review Reactor Coolant Chemistry sample parameters below and record any action(s) taken, if required.
Chemistry has conducted a reactor coolant sample in accordance with Chemistry Procedure 8.3, Control Parameters and Limits, and notified you of the following results:
Boron Non Detectable Calcium 2.0 ppb Conductivity 10.0 umho/cm Chlorides 12.0 ppb pH 6.9 Silica 25 ppb Sodium 2.1 ppb Sulfates 0.77 ppb Tritium Non Detectable Zinc 2.6 ppb Record your findings on Attachment 1 and return the results in to the Proctor when complete.
Nebraska Public Power District SKL0345080 Cooper Nuclear Station Page 4 of 6 Job Performance Measure for Operations Revision 0 Start Time: ____________
Performance Checklist Standards Sat Unsat Recognized conductivity is out of
- 1. Reviews data.
specification and entered Procedure 2.4CHEM.
Obtained the current revision of Procedure
- 2. Obtain Procedure.
2.4CHEM. Selects Section 1.0.
1.1.1 Recognized Reactor power > 10% RTP and Reactor water conductivity > 1.0 µmho
- 3. Entry Condition met. limit was exceeded and continued to Section 4.0 Subsequent Operator Actions.
- 4. Date and Time 4.1 Recorded the current date and time.
entered.
4.2 Determined the TRM limit for TLCO 3.4.1 are exceeded and refers to TRM condition
- 5. TRM limit B and determines Action B.1 is required exceeded. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> from the time the limits were exceeded for required condition.
NOTE to Examiners: Step 4.2 states to ensure actions of TLCO are met if they become more restrictive than 2.4CHEM. The TRM allows 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> and 2.4CHEM is more restrictive.
4.3 Notified Chemistry that Conductivity is out-of-
- 6. Notify Chemistry.
limit.
- 7. Enter Attachment 2 Entered 2.4CHEM, Attachment 2 NOTE to Examiner: Examinee records actions below to be taken per Procedure 2.4CHEM, Attachment 2.
1.1.1 Lower power per Procedure 2.1.10 until
- 8. Lower power conductivity stabilized 1.0 µmho.
- 9. Ensure F/Ds in 1.1.2 Ensure both RWCU F/Ds in service.
service.
Nebraska Public Power District SKL0345080 Cooper Nuclear Station Page 5 of 6 Job Performance Measure for Operations Revision 0 Performance Checklist Standards Sat Unsat 1.1.3 If limit not restored in 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> then go
- 10. If not<1.0 in 24 hrs to Step 1.5 and immediately shutdown shut down. per Procedure 2.1.4.1 to establish Mode 4.
1.4.1 If Conductivity not restores to < 5.0
- 11. If not < 5.0 in 6 µmho within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> go to Step 1.6 and hours, shut down. immediately shut down per Procedure 2.1.2.1 to establish Mode 4.
Handed in Attachment 1 to proctor and the recorded actions agree with the critical steps 4 Handed in Att 1.
listed in the Standards. (Verbatim recording not required).
Stop Time: __________ Total Time: ___________
Nebraska Public Power District SKL0345080 Cooper Nuclear Station Page 6 of 6 Job Performance Measure for Operations Revision 0 ATTACHMENT 1 Directions to Trainee:
When I tell you to begin, you are to perform a review of Reactor Coolant Chemistry data and inform me when actions are complete. Before you start, I will state the general plant conditions, the initiating cues and answer any questions you may have.
General Conditions:
The Plant has been Operating at 100% power for the past 120 days.
Initiating Cue(s):
The Shift Manager directs you, as the CRS, to review Reactor Coolant Chemistry sample parameters below and record any action(s) taken, if required.
Chemistry has conducted a reactor coolant sample in accordance with Chemistry Procedure 8.3, Control Parameters and Limits, and notified you of the following results:
Boron Non Detectable Calcium 2.0 ppb Conductivity 10.0 umho/cm Chlorides 12.0 ppb pH 6.9 Silica 25 ppb Sodium 2.1 ppb Sulfates 0.77 ppb Tritium Non Detectable Zinc 2.6 ppb Record your findings on Attachment 1 and return the results in to the Proctor when complete.
Record your actions/findings below:
Signature
Nebraska Public Power District SKL034-20-114 (29981)
Cooper Nuclear Station Page 1 of 6 Job Performance Measure for Operations Revision 04 Task No.: 341033W0303
Title:
Determine Shift Staffing Requirements for Mode Change Trainee: Examiner:
Pass Fail Examiner Signature: Date:
Additional Program Information:
- 1. Appropriate Performance Locations: CR / SIM / Classroom
- 3. Evaluation Method: Perform
- 4. Performance Time: 10 minutes
- 5. K/A 2.1.4 (3.4)
Directions to Examiner:
- 1. This JPM evaluates the trainee's ability to determine shift staffing requirements for a mode change.
- 2. Observe the trainee during performance of the JPM for proper use of self-checking methods.
- 3. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes section below.
- 4. Give the examinee Attachment 1.
- 5. Brief the trainee, and tell the trainee to begin.
Notes: ______________________________________________________________________
Nebraska Public Power District SKL034-20-114 (29981)
Cooper Nuclear Station Page 2 of 6 Job Performance Measure for Operations Revision 04 Task No.: 341033W0303
Title:
Determine Shift Staffing Requirements for Mode Change Directions to Trainee:
When I tell you to begin, you are to evaluate the staff available and determine if a change in Modes is allowed. Before you start, I will state the general plant conditions, the Initiating Cues, and answer any questions you may have.
General Conditions:
- 1. The plant conditions are as follows:
- Reactor Pressure is 0 psig and steady.
- Coolant temperature is 200°F and steady.
- All reactor vessel head closure bolts are fully tensioned.
- Mode Switch is in Shutdown
- 2. Your Shift complement is comprised of:
- One SRO (you)
- Two ROs
- Three Non-Licensed Nuclear Plant Operators
- One RP/Chem Tech General
References:
- 1. Conduct of Operations Procedure 2.0.3 General Tools and Equipment:
- 1. None Special Conditions, References, Tools, Equipment:
- 1. Critical checks denoted in bold.
Task Standards:
- 1. Determines current staffing is inadequate, and additional staffing will be required plus more staffing is required when the mode change is made per Procedure 2.0.3.
- 2. 100% of critical elements successfully completed without error.
- 3. 100% of safety and radiological work practices.
Nebraska Public Power District SKL034-20-114 (29981)
Cooper Nuclear Station Page 3 of 6 Job Performance Measure for Operations Revision 04 Task No.: 341033W0303
Title:
Determine Shift Staffing Requirements for Mode Change Initiating Cue(s):
During your shift Reactor Coolant temperature is expected to rise to 215°F as a result of Shutdown Cooling being removed from service. As the Senior Licensed person on your shift, you are to determine two things;
- 1. Per administrative requirements, do you have sufficient staff now? If not determine how many additional staff types are needed and document your findings on Attachment 1.
- 2. Per administrative requirements, will you have sufficient staff to allow you to raise Coolant Temperature to 215°F during your shift? If not determine how many additional staff types are needed and document your findings on Attachment 1.
NOTE: Tell the trainee to begin.
Nebraska Public Power District SKL034-20-114 (29981)
Cooper Nuclear Station Page 4 of 6 Job Performance Measure for Operations Revision 04 Task No.: 341033W0303
Title:
Determine Shift Staffing Requirements for Mode Change Start Time: ____________
Performance Checklist Standards Sat Unsat
- 1. Obtain Procedure Current revision of 2.0.3 obtained.
2.0.3.
- 2. Determines the The SRO may use Tech Specs to confirm that the current mode. Unit is in MODE 4.
- 3. Determines the mode to be entered The SRO may use Tech Specs to confirm that the when temperature Unit will be entering Mode 3 within the shift.
rises to 215ºF.
Your Shift complement is comprised of:
- One SRO (you)
- 4. Determines that the
- Two ROs current shift staff is
- Three Non-Licensed Nuclear Plant Operators inadequate.
- One RP/Chem Tech
- Dose Assessor SRO records the additional needed staff on Attachment 1.
- 5. Records the
Attachment 1.
- One person trained and qualified Dose Assessor.
For Mode 3 the SRO determines the following staff types are needed:
- 6. Determines which
- Three Non-Licensed Nuclear Plant Operators required.
- One STE
- One RP/Chem Tech
- One person trained and qualified Dose Assessor.
Nebraska Public Power District SKL034-20-114 (29981)
Cooper Nuclear Station Page 5 of 6 Job Performance Measure for Operations Revision 04 Task No.: 341033W0303
Title:
Determine Shift Staffing Requirements for Mode Change Performance Checklist Standards Sat Unsat SRO records the additional needed staff on Attachment 1.
- 7. Records the needed Staff on
- One STE Attachment 1.
- One SRO
- One person qualified as Dose Assessor.
- 8. Turns in completed Returns completed Attachment 1 to evaluator.
paperwork.
Stop Time: __________ Total Time: ___________
Nebraska Public Power District SKL034-20-114 (29981)
Cooper Nuclear Station Page 6 of 6 Job Performance Measure for Operations Revision 04 ATTACHMENT 1 Directions to Trainee:
When I tell you to begin, you are to evaluate the staff available and determine if a change in Modes is allowed. Before you start, I will state the general plant conditions, the Initiating Cues, and answer any questions you may have.
General Conditions:
- 1. The plant conditions are as follows:
- Reactor Pressure is 0 psig and steady.
- Coolant temperature is 200°F and steady.
- All reactor vessel head closure bolts are fully tensioned.
- Mode Switch is in Shutdown
- 3. Your Shift complement is comprised of:
- One SRO (you)
- Two ROs
- Three Non-Licensed Nuclear Plant Operators
- One RP/Chem Tech Initiating Cue(s):
During your shift Reactor Coolant temperature is expected to rise to 215°F as a result of Shutdown Cooling being removed from service. As the Senior Licensed person on your shift, you are to determine two things;
- 1. Per administrative requirements, do you have sufficient staff now? If not determine how many additional staff types are needed and document your findings on Attachment 1.
- 2. Per administrative requirements, will you have sufficient staff to allow you to raise Coolant Temperature to 215°F during your shift? If not determine how many additional staff types are needed and document your findings on Attachment 1.
Current Staff:
(Check one) Adequate in current mode Inadequate in current mode Additional needed staff:_________________________________________________________
Staff required at 215ºF:
(Check one) Current staff adequate Additional staff needed.
Additional needed staff: ________________________________________________________
Nebraska Public Power District SKL034-50-18 (8783)
Cooper Nuclear Station Page 1 of 4 Job Performance Measure for Operations Revision: 01 Task No.: 200302G0203
Title:
Determine Post-Maintenance Testing Requirements Trainee: Examiner:
Pass: Fail: Examiner Signature: Date:
Additional Program Information:
- 1. Appropriate Performance Locations: Classroom
- 3. Evaluation Method: Perform Simulate
- 4. Performance Time: 10 minutes
- 5. NRC K/A 2.2.7 (2.0/3.2)
Directions to Examiner:
- 1. This JPM evaluates the examinees ability to determine the post maintenance testing for HPCI-V-282, DOWNSTREAM TEST LINE DRAIN ROOT following valve repair per Maintenance Procedure 7.0.5, Post-maintenance Testing.
- 2. Observe the trainee during performance of the JPM for proper use of self-checking methods.
- 3. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes/comments section below.
- 4. Give the trainee his copy of the Directions to the Trainee (Attachment 1) when ready to start the JPM.
- 5. If examinee requests Burns and Roe P&ID Drawing 2044, provide a copy to him/her.
- 6. Brief the trainee and tell the trainee to begin.
Directions to Trainee:
When I tell you to begin, you are to determine the post maintenance testing for HPCI-V-282, DOWNSTREAM TEST LINE DRAIN ROOT following valve repair. Before you start, I will state the general plant conditions, the Initiating Cues, and answer any questions you may have.
General Conditions:
- 1. The Reactor is shutdown with an outage in progress.
Nebraska Public Power District SKL034-50-18 (8783)
Cooper Nuclear Station Page 2 of 4 Job Performance Measure for Operations Revision: 01 Task No.: 200302G0203
Title:
Determine Post-Maintenance Testing Requirements General
References:
- 1. Procedure 7.0.5, POST MAINTENANCE TESTING General Tools and Equipment:
- 1. None Special Conditions, References, Tools, Equipment:
- 1. Critical steps denoted in bold text.
Task Standards:
- 1. Determine the correct post maintenance test requirements include stroke test, leak test, and open/close flow test per Procedure 7.0.5 for HPCI manual valve HPCI-V-282.
- 2. 100% of critical elements successfully completed without error.
- 3. 100% of safety and radiological work practices.
Initiating Cue(s):
The Shift Manager directs you to determine the post maintenance testing requirements to assign to HPCI-V-282 following valve repair. Record your findings on Attachment 1 and hand in to proctor when complete.
Nebraska Public Power District SKL034-50-18 (8783)
Cooper Nuclear Station Page 3 of 4 Job Performance Measure for Operations Revision: 01 Task No.: 200302G0203
Title:
Determine Post-Maintenance Testing Requirements Start Time: ____________
Performance Standard SAT Unsat Checklist
- 1. Obtains Procedure 7.0.5, Post The Operator obtained the current revision of 7.0.5.
Maintenance Testing.
- 2. Identify component Determines that HPCI-282 is a manual valve.
type for HPCI valve.
- 3. Locate the general Candidate locates the Component Test Matrices for component from Manual Valves.
Procedure 7.0.5 Attachment 1 index.
- 4. Identify, on the Candidate Identifies repair/replace on the Matrices.
matrices, the type of corrective maintenance performed on HPCI-282.
From attachment 1, the candidate assigns Stroke
- 5. Determine the test Test.
activities.
From attachment 1, the candidate assigns Leak Test.
- 6. Determine the test activities.
From attachment 1, the candidate assigns Flow Test
- 7. Determine the test Open/Closed.
activities.
NOTE to Examiner: The Position Verification Test is not required because there is no remote indication of HPCI-V-282.
Informs the Shift Manager of the post maintenance
- 8. Shift manager testing requirements to assign to the work package informed.
Stop Time: __________ Total Time: ___________
Nebraska Public Power District SKL034-50-18 (8783)
Cooper Nuclear Station Page 4 of 4 Job Performance Measure for Operations Revision: 01 ATTACHMENT 1 Directions to Trainee:
When I tell you to begin, you are to determine the post maintenance testing for HPCI-V-282, DOWNSTREAM TEST LINE DRAIN ROOT following valve repair. Before you start, I will state the general plant conditions, the Initiating Cues, and answer any questions you may have.
General Conditions:
- 1. The Reactor is shutdown with an outage in progress.
Initiating Cue(s):
The Shift Manager directs you to determine the post maintenance testing requirements to assign to HPCI-V-282 following valve repair. Record your findings on Attachment 1 and hand in to proctor when complete.
Signature
Nebraska Public Power District SKL034-30-63 (44051)
Cooper Nuclear Station Page 1 of 5 Job Performance Measure for Operations Revision 00 Task No.:
Task
Title:
Radiation Protection Table Top Trainee: Examiner:
Pass Fail Examiner Signature: Date:
Additional Program Information:
- 1. Appropriate Performance Locations: CR, SIM, Classroom
- 3. Evaluation Method: Simulate Perform
- 4. Performance Time: 10 minutes
- 5. NRC K/A 2.3.13 (3.4/3.8)
Directions to Examiner:
- 1. This JPM evaluates the trainee's ability to determine if certain work can be performed within the confines of the Code of Federal Regulations and CNS procedures.
- 2. This JPM can be performed any place the operator can access appropriate procedures.
- 3. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes section below.
- 4. Give the trainee his copy of the Directions to the Trainee (Attachment 1) when ready to start the JPM.
- 5. Brief the trainee and tell the trainee to begin.
Notes: ______________________________________________________________________
Directions to Trainee:
When I tell you to begin, you are to determine whether John Doe can perform RHR valve work.
If you find he cannot perform the work state the reason why. If John Doe can perform the work, state what authorization, if any is required prior to performing the work. Before you start, I will state the general plant conditions, the Initiating Cues and answer any questions you may have.
Nebraska Public Power District SKL034-30-63 (44051)
Cooper Nuclear Station Page 2 of 5 Job Performance Measure for Operations Revision 00 Task No.:
Task
Title:
Radiation Protection Table Top General Conditions:
- 1. The plant is shutdown to perform RHR valve work.
- 2. John Doe has been selected to repair the valve.
General
References:
- 1. 10CFR20
- 2. 9.ALARA.1, PERSONNEL DOSIMETRY AND OCCUPATIONAL RADIATION EXPOSURE PROGRAM.
General Tools and Equipment:
- 1. None.
Special Conditions, References, Tools, Equipment:
- 1. Critical checks denoted in bold.
Task Standards:
- 1. The student determines the work can be performed and the department personnel that must approve the dose.
- 2. 100% of critical elements successfully completed without error.
Initiating Cue(s):
John Doe has been selected to perform work on an RHR valve. Performance of the work is expected to result in a whole body dose of 550 mRem. The Shift Manager directs you to determine based on John Doe's dose history, whether he is capable of performing this work.
When I tell you to begin, you are to determine whether John Doe can perform the valve work. If you find he cannot perform the work state the reason why. If John Doe can perform the work, state what authorization, if any is required prior to performing the work. Before you start, I will state the general plant conditions, the Initiating Cues and answer any questions you may have.
Nebraska Public Power District SKL034-30-63 (44051)
Cooper Nuclear Station Page 3 of 5 Job Performance Measure for Operations Revision 00 Task No.:
Task
Title:
Radiation Protection Table Top Time Start: _________
Performance Checklist Standards Sat Unsat
- 2. Pertinent personal Dose 9.ALARA.1 step 6.7.2.1 Dose History was history is reviewed. reviewed.
- 3. Pertinent job dose projections for the job are Dose projections were reviewed.
reviewed.
- 4. Compares the job requirements to the amount Job requirements were reviewed.
of dose that can be received.
9.ALARA.1 step 6.2.1.2.
- 5. Calculates expected Expected cumulative dose was cumulative dose. calculated at 2.050 Rem on-site and 3.250 Rem total.
9.ALARA.1 step 6.2.1.2.
- 6. Off-site dose verified Verified off-site dose did not exceed 1.5 within limit.
Rem (1500 mrem).
9.ALARA.1 step 6.2.1.2.
Informed Shift Manager the work could be done, but the Department Manager,
- 7. Informs the SM that he RP Technical Supervisor, Radiation can perform this job. Protection Manager, and the GMPO must authorize the dose extension above 2,000 mRem.
Time Stop: __________ Total Time: ___________
Nebraska Public Power District SKL034-30-63 (44051)
Cooper Nuclear Station Page 4 of 5 Job Performance Measure for Operations Revision 00 ATTACHMENT 1 Directions to Trainee:
When I tell you to begin, you are to determine whether John Doe can perform RHR valve work.
If you find he cannot perform the work state the reason why. If John Doe can perform the work, state what authorization, if any is required prior to performing the work. Before you start, I will state the general plant conditions, the Initiating Cues and answer any questions you may have.
General Conditions:
- 1. The plant is shutdown to perform RHR valve work.
- 2. John Doe has been selected to repair the valve.
Initiating Cue(s):
John Doe has been selected to perform work on an RHR valve. Performance of the work is expected to result in a whole body dose of 550 mRem. The Shift Manager directs you to determine based on John Doe's dose history, whether he is capable of performing this work.
When I tell you to begin, you are to determine whether John Doe can perform the valve work. If you find he cannot perform the work state the reason why. If John Doe can perform the work, state what authorization, if any is required prior to performing the work. Before you start, I will state the general plant conditions, the Initiating Cues and answer any questions you may have.
Nebraska Public Power District SKL034-30-63 (44051)
Cooper Nuclear Station Page 5 of 5 Job Performance Measure for Operations Revision 00 ATTACHMENT 1 Your Pertinent Statistics John Doe's Age: 35 years Lifetime TEDE: 32 Rem On-Site TEDE so far this year: 1.5 Rem Off-Site TEDE so far this year: 1.2 Rem Pertinent Job Dose Projections for the one individual performing this job Projected Whole Body Dose: 550 mRem Results:
Perform the Job: Yes No Circle one If allowed to perform the work, whos authority is needed first?
Signature
Nebraska Public Power District SKL034-30-61(29980)
Cooper Nuclear Station Page 1 of 6 Job Performance Measure for Operations Revision 01 Task No.: 200335G0503
Title:
PAR Table Top X Trainee: Examiner:
Pass Fail Examiner Signature: Date:
This is a Time Critical JPM the trainee must determine the correct PARs within 15 minutes of reviewing plant status as stated on Attachment 2.
Additional Program Information:
- 1. Appropriate Performance Locations: Classroom / SIM
- 3. Evaluation Method: Perform
- 4. Performance Time: 10 minutes
- 5. K/A: 2.4.44 (2.1 / 4.0)
Directions to Examiner:
- 2. Observe the trainee during performance of the JPM for proper use of self-checking methods.
- 3. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes section below.
- 4. Brief the trainee, and tell the trainee to begin.
Notes: ______________________________________________________________________
Nebraska Public Power District SKL034-30-61(29980)
Cooper Nuclear Station Page 2 of 6 Job Performance Measure for Operations Revision 01 Task No.: 200335G0503
Title:
PAR Table Top X Directions to Trainee:
When I tell you to begin, you are to determine Protective Action Recommendations for the provided conditions. Before you start, I will state the general plant conditions, the Initiating Cues, and answer any questions you may have.
This is a time critical JPM. The PARs must be determined within a pre-determined time limit after plant status is reviewed.
During task performance, it is recommended that you limit your discussion/demonstration to the minimum required. The examiner may ask questions of you if necessary to understand your actions.
General Conditions:
- 2. There IS a radioactive release in excess of ODAM limits at this time.
- 3. ERP release rate is 1.33E9 Ci/sec
- 4. A steam leak from HPCI is occurring.
- 5. CNS-DOSE is NOT available due to software error.
- 6. The core is degraded.
- 7. The stability class is F.
- 8. The wind is at 5 mph.
- 9. The wind is from 270°
- 10. There is NO precipitation 11 The below information has been determined a using hand calculation from EPIP 5.7.17 DOSE Projection Data Distance From Projected Integrated Dose (Rem) Projected Dose Rate (Rem/hr)
Plant TEDE CDE (Thyroid) TEDE CDE (Thyroid)
Site Boundary 1.63E-05 4.39E-05 4.08E-6 1.10E-05 2 Miles 5.64E-02 1.52E-01 1.41E-02 3.80E-02 5 Miles 7.57E-01 2.04E-00 1.89E-01 5.10E-01 10 Miles 1.25E-00 2.69E-00 205E-01 6.73E-01
Nebraska Public Power District SKL034-30-61(29980)
Cooper Nuclear Station Page 3 of 6 Job Performance Measure for Operations Revision 01 Task No.: 200335G0503
Title:
PAR Table Top X General
References:
- 1. Procedure 5.7.1, EAL Matrix
- 2. Procedure 5.7.6, Attachment 3
- 3. Procedure 5.7.20 General Tools and Equipment:
- 1. None Special Conditions, References, Tools, Equipment:
- 1. Critical checks denoted in bold.
Task Standards:
- 1. The trainee correctly determines affected Sectors and determines evacuation and sheltering Sectors.
- 2. 100% of critical elements successfully completed without error.
- 3. 100% of safety and radiological work practices.
Initiating Cue(s):
You are to determine the appropriate Protective Action Recommendations (PARs) for the provided conditions. Complete the PAR table and return it to the examiner when you have completed this task.
NOTE: Tell the trainee to begin.
Nebraska Public Power District SKL034-30-61(29980)
Cooper Nuclear Station Page 4 of 6 Job Performance Measure for Operations Revision 01 Task No.: 200335G0503
Title:
PAR Table Top X Start Time (Plant Status of Attachment 1 reviewed): ____________
Performance Checklist Standards Sat Unsat
- 1. Refer to Procedure The operator may refer to Procedure 5.7.2.
5.7.2. Determines 5.7.20 must be used for PARs.
- 2. Refer to Procedure The operator refers to Procedure 5.7.20.
5.7.20.
- 3. Determines The operator determines the affected sectors affected sectors. for wind direction of 270°.
Sectors D, E, F EVACUATE
- 4. Determine Sectors 0-2 miles ALL that must be 2-5 miles Sectors D,E,F evacuated.
5-10 miles Sectors D,E,F The Operator determines the following GO INDOORS sectors:
- 5. Determines Sectors that must GO INDOORS Go Indoors and 2 - 5 miles All Remaining Sectors monitor EAS/EBS.
5-10 miles All Remaining Sectors
- 6. PAR from CR so Add remarks/notes to recommend evacuation must evacuate out in Sectors D, E, F out to 15 miles.
to 15 miles.
- 7. Turns in completed Returns completed Attachment 1 to evaluator paperwork. within 15 minute time limit.
Stop Time: __________ Total Time: ___________
Nebraska Public Power District SKL034-30-61(29980)
Cooper Nuclear Station Page 5 of 6 Job Performance Measure for Operations Revision 01 ATTACHMENT 1 (Page 1 of 2)
Directions to Trainee:
When I tell you to begin, you are to determine Protective Action Recommendations for the provided conditions. Before you start, I will state the general plant conditions, the Initiating Cues, and answer any questions you may have.
This is a time critical JPM. The PARs must be determined within a pre-determined time limit after plant status is reviewed.
During task performance, it is recommended that you limit your discussion/demonstration to the minimum required. The examiner may ask questions of you if necessary to understand your actions.
General Conditions:
- 2. There IS a radioactive release in excess of ODAM limits at this time.
- 3. ERP release rate is 1.33E9 Ci/sec
- 4. A steam leak from HPCI is occurring.
- 5. CNS-DOSE is NOT available due to software error.
- 6. The core is degraded.
- 7. The stability class is F.
- 8. The wind is at 5 mph.
- 9. The wind is from 270°
- 10. There is NO precipitation 11 The below information has been determined a using hand calculation from EPIP 5.7.17 DOSE Projection Data Distance From Projected Integrated Dose (Rem) Projected Dose Rate (Rem/hr)
Plant TEDE CDE (Thyroid) TEDE CDE (Thyroid)
Site Boundary 1.63E-05 4.39E-05 4.08E-6 1.10E-05 2 Miles 5.64E-02 1.52E-01 1.41E-02 3.80E-02 5 Miles 7.57E-01 2.04E-00 1.89E-01 5.10E-01 10 Miles 1.25E-00 2.69E-00 2.05E-01 6.73E-01
Nebraska Public Power District SKL034-30-61(29980)
Cooper Nuclear Station Page 6 of 6 Job Performance Measure for Operations Revision 01 Initiating Cue(s):
You are to determine the appropriate Protective Action Recommendations (PARs) for the provided conditions. Complete the PAR table and return it to the examiner when you have completed this task.
ATTACHMENT 1 (Page 2 of 2)
Protective Action Recommendations (PARS)
None Evacuate Sectors Go indoors and monitor EAS/EBS in Sectors 0-2 Miles 2-5 Miles 5-10 Miles REMARKS for 5.7.6 Attachment 3:
Signature
Nebraska Public Power District SKL034-21-77(44532)
Cooper Nuclear Station Page 1 of 8 Job Performance Measure for Operations Revision 02 Task No.: None
Title:
Placing SDG In Service From Control Room Trainee: Examiner:
Pass Fail Examiner Signature: Date:
Additional Program Information:
- 1. Appropriate Performance Locations: CR / SIM
- 3. Evaluation Method: Simulate Perform
- 4. Performance Time: 20 minutes
- 5. NRC K/A 262001.K4.06 (3.6 / 3.9) and 264000.A4.04 (3.7/3.7)
Directions to Examiner:
- 1. This JPM evaluates the trainee's ability to start and place in service the Supplemental Diesel Generator from the Control Room in accordance with Procedure 2.2.99.
- 2. If this JPM is performed on the Simulator, only the cues preceded by "#" should be given.
- 3. Observe the trainee during performance of the JPM for proper use of self-checking methods.
- 4. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes/comments section below.
- 5. Brief the trainee, place the simulator in run, and tell the trainee to begin.
Notes/Comments: ____________________________________________________________
Nebraska Public Power District SKL034-21-77(44532)
Cooper Nuclear Station Page 2 of 8 Job Performance Measure for Operations Revision 02 Task No.: None
Title:
Placing SDG In Service From Control Room Directions to Trainee:
When I tell you to begin, you are to place the Supplemental Diesel Generator in service from the Control Room. Before you start, I will state the general plant conditions, the initiating cues and answer any questions you may have.
During task performance, state the actions you are taking, e.g.: repositioning controls and observing instrumentation.
If being simulated in the Control Room:
When simulating, physically point to any meters, gauges, recorders and controls you would be using. State the position of controls as you would have manipulated them in order to complete the assigned task.
General Conditions:
- 1. The Plant is Shutdown.
- 2. Critical 4160 Bus 1F is de-energized
- 3. Emergency Diesel Generator #1 is Inoperable and cannot be placed in service.
- 4. The Emergency Transformer is Unavailable.
General
References:
- 1. Procedure 2.2.99 Supplemental Diesel Generator System General Tools and Equipment:
- 1. None Special Conditions, References, Tools, Equipment:
- 1. Simulator Setup: See Attachment 1.
- 2. Critical checks denoted by bold steps.
- 3. Simulator cues denoted by "#".
Task Standards:
- 1. The operator starts the Supplemental Diesel Generator and ties it to Critical Bus 1F and re-energizes the bus per Procedure 2.2.99.
- 2. 100% of critical elements successfully completed without error.
- 3. 100% of safety and radiological work practices.
Nebraska Public Power District SKL034-21-77(44532)
Cooper Nuclear Station Page 3 of 8 Job Performance Measure for Operations Revision 02 Task No.: None
Title:
Placing SDG In Service From Control Room Initiating Cue(s):
The Control Room Supervisor directs you to place the Supplemental Diesel Generator in service from the Control Room in accordance with Procedure 2.2.99 Supplemental Diesel Generator System and supply Critical Bus 1F.
Notify the CRS when the SDG is running and has energized the Bus.
NOTE: Ensure the Simulator is in RUN and tell the trainee to begin.
Nebraska Public Power District SKL034-21-77(44532)
Cooper Nuclear Station Page 4 of 8 Job Performance Measure for Operations Revision 02 Task No.: None
Title:
Placing SDG In Service From Control Room Start Time: ____________
Performance Checklist Standards Sat Unsat Obtained the current revision of Procedure 2.2.99
- 1. Obtain Procedure Supplemental Diesel Generator System. Selects Section 5.
- 2. Place the SDG 5.1 Placed the SUPPLEMENTAL DIESEL switch to Start GENERATOR control switch to START.
5.2 After GENERATOR ENERGIZED light was lit, closed SDG OUTPUT BKR SG1 and checked following.
- 3. Close the SDG 5.2.1 Switch spring returns to NORMAL Output breaker AFTER CLOSE (red flagged).
5.2.2 4160V BUS 1S BUS ENERGIZED light is lit.
5.3 On Switchgear Display Screen, transferred
- 4. Open Breaker Bus 480S to the SDG 480S(12.5) 5.3.1 Opened Breaker 480S (12.5).
5.3.1 Closed Breaker 480S-(4160S).
5.4 Record data on Attachment 1 twice per shift while engine is running.
- 5. Record data
- CUE: Another operator will record data.
Note to Examiner: The student will transfer to Section 8 to energize the 4160F Bus.
Ensured following Annunciators clear:
- 6. Checks 8.2.1 C-1/C-6, 4160V BUS 1F BKR 1FA annunciators in 8.2.2 C-1/C-7, 4160V BUS 1F BKR 1FS section 8 8.2.3 C-1/E-7, 4160V BUS 1F BKR 1FE LOCKOUTs.
Nebraska Public Power District SKL034-21-77(44532)
Cooper Nuclear Station Page 5 of 8 Job Performance Measure for Operations Revision 02 Task No.: None
Title:
Placing SDG In Service From Control Room Performance Checklist Standards Sat Unsat 8.3 At Panel 9-3, placed the following switches to PULL-TO-LOCK:
- 7. Pulls to lock the
- RHR PUMP A.
pumps on 9-3.
- CS PUMP A.
- RHR PUMP B.
8.4 At Panel A, placed the following switches to PULL-TO-LOCK:
- SERVICE WATER PUMP A.
- 8. Pulls to lock the
- Ensured SERVICE WATER PUMP A MODE pumps on Panel A SELECTOR switch in MANUAL.
- SERVICE WATER PUMP C.
- Ensured SERVICE WATER PUMP C MODE SELECTOR switch in MANUAL.
8.5 At Panel C, placed the following breaker switches to PULL-TO-LOCK:
- 9. Pulls to lock the
- BUS 1A TIE BKR 1FA.
breakers on Panel
- EMERGENCY XFMR BKR 1FS.
C
- DIESEL GEN 1 BKR EG1.
- EMERGENCY XFMR BKR 1GS.
8.6.1 At SUPPLEMENTAL DIESEL GENERATOR
- 10. Places MODS PANEL placed the MODS POWER switch to Power to ON ON.
- 11. Places XFMR 8.6.2 Placed EMERGENCY XFMR MODS switch MODS switch to to OPEN.
Open
- 12. Places SDG MODS 8.6.3 Placed SDG MODS switch to CLOSE.
switch to Close
Nebraska Public Power District SKL034-21-77(44532)
Cooper Nuclear Station Page 6 of 8 Job Performance Measure for Operations Revision 02 Task No.: None
Title:
Placing SDG In Service From Control Room Performance Checklist Standards Sat Unsat
- 13. Places MOD 8.6.4 Placed MODS POWER switch to OFF.
POWER to OFF 8.6.5 Closed BUS 1S TIE BKR 1SS and check
- 14. Close Breaker 1SS switch spring returns to NORMAL AFTER CLOSE (red flagged).
8.7 At Panel C; placed EMERGENCY XFMR BKR
- 15. Closes Emergency 1FS to CLOSE, then released and checked XFRM BKR 1FS switch spring returns to NORMAL AFTER CLOSE (red flagged).
The Operator informed the CRS that the Supplemental Diesel Generator has been started
- 16. Notifies the CRS and is aligned to the bus.
- CUE: As the CRS, acknowledge the report.
Stop Time: __________ Total Time: ___________
Nebraska Public Power District SKL034-21-77(44532)
Cooper Nuclear Station Page 7 of 8 Job Performance Measure for Operations Revision 02 Task No.: None
Title:
Placing SDG In Service From Control Room ATTACHMENT 1 SIMULATOR SET-UP A. Materials Required None B. Initialize the Simulator in IC IC 1 (IC-240)
C. Run Batch File D. Change the simulator conditions as follows:
- 1. Triggers Number File Name Description
- 2. Malfunctions Number Title Trigger TD Severity Ramp Initial DG02A Diesel Generator #1Trip N/A 0 N/A 0 N/A Loss of Emergency ED06 N/A 0 N/A 0 N/A Transformer
- 3. Remotes Number Title Trigger TD Value Ramp 0 N/A
- 4. Overrides Instrument Tag Trigger TD Value Ramp None
- 5. Panel Setup Ensure Breaker 1FA is open.
Note: If this JPM is to be performed more than once, take a SNAPSHOT after the panel setup is complete.
Nebraska Public Power District SKL034-21-77(44532)
Cooper Nuclear Station Page 8 of 8 Job Performance Measure for Operations Revision 02 ATTACHMENT 2 Directions to Trainee:
When I tell you to begin, you are to place the Supplemental Diesel Generator in service from the Control Room. Before you start, I will state the general plant conditions, the initiating cues and answer any questions you may have.
During task performance, state the actions you are taking, e.g.: repositioning controls and observing instrumentation.
If being simulated in the Control Room:
When simulating, physically point to any meters, gauges, recorders and controls you would be using. State the position of controls as you would have manipulated them in order to complete the assigned task.
General Conditions:
- 1. The Plant is Shutdown.
- 2. Critical 4160 Bus 1F is de-energized
- 3. Emergency Diesel Generator #1 is Inoperable and cannot be placed in service.
- 4. The Emergency Transformer is Unavailable.
Initiating Cue(s):
The Control Room Supervisor directs you to place the Supplemental Diesel Generator in service from the Control Room in accordance with Procedure 2.2.99 Supplemental Diesel Generator System and supply Critical Bus 1F.
Notify the CRS when the SDG is running and has energized the Bus.
Nebraska Public Power District SKL034-20-123 (33001)
Cooper Nuclear Station Page 1 of 8 Job Performance Measure for Operations Revision 02 Task No: 259042P0101 SHIFTING FROM SINGLE ELEMENT TO AUTO (3 ELEMENT) CONTROL (Alternate Path) #1 Trainee: Examiner:
Pass Fail Examiner Signature: Date:
THIS IS AN ALTERNATE PATH JPM Additional Program Information:
- 1. Appropriate Performance Locations: CR / SIM
- 3. Evaluation Method: Simulate Perform
- 4. Performance Time: 15 minutes
- 5. NRC K/A 259002 A4.06 (3.1/3.2)
Directions to Examiner:
Note: This JPM is an Alternate Path JPM. This JPM requires restoring 3 steam flow signals to RVLC.
- 1. This JPM evaluates the trainee's ability to SHIFT FROM SINGLE ELEMENT TO AUTO (3 ELEMENT) CONTROL in accordance with Procedure 4.4.1, Reactor Level Control System. (Alternate Path)
- 2. If this JPM is performed on the Simulator, only the cues preceded by "#" should be given.
- 3. Observe the trainee during performance of the JPM for proper use of self-checking methods.
- 4. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes comments section below.
- 5. Brief the trainee, place the simulator in run, and tell the trainee to begin.
Notes/Comments: ____________________________________________________________
Nebraska Public Power District SKL034-20-123 (33001)
Cooper Nuclear Station Page 2 of 8 Job Performance Measure for Operations Revision 02 Task No: 259042P0101 SHIFTING FROM SINGLE ELEMENT TO AUTO (3 ELEMENT) CONTROL (Alternate Path) #1 Directions to Trainee:
When I tell you to begin, you are to SHIFT FROM SINGLE ELEMENT TO AUTO (3 ELEMENT)
CONTROL on the RVLC System. Before you start, I will state the general plant conditions, the Initiating Cues and answer any questions you may have.
If being simulated In-Plant or Control Room:
When simulating, physically point to any meters, gauges, recorders and controls you would be using. State the position of controls as you would have manipulated them in order to complete the assigned task.
General Conditions:
- 1. The plant is stable at 100% Power.
- 2. Single Element Control due to RVLC Maintenance that is complete.
General
References:
- 1. Procedure 4.4.1 Reactor Vessel Level Control System, Rev. 06 General Tools and Equipment:
- 1. None Special Conditions, References, Tools, Equipment:
- 1. Simulator Setup: See Attachment 1.
- 2. Critical checks denoted by BOLD text.
- 3. Simulator cues denoted by "#".
- 4. Alternate path denoted by.
Task Standards:
- 1. The operator attempts to shift Reactor Water Level Control from one element to three element control but must first clear the bypass on at least one steam flow input signal to the RVLCS (expectation is all three since cue is that maintenance is complete but not required by procedure) and then shift from one element to three element control per procedure 4.4.1, Reactor Water Level Control System.
- 2. 100% of critical elements successfully completed without error.
- 3. 100% of safety and radiological work practices.
Nebraska Public Power District SKL034-20-123 (33001)
Cooper Nuclear Station Page 3 of 8 Job Performance Measure for Operations Revision 02 Task No: 259042P0101 SHIFTING FROM SINGLE ELEMENT TO AUTO (3 ELEMENT) CONTROL (Alternate Path) #1 Initiating Cue(s):
The CRS Orders you to SHIFT RVLC FROM SINGLE ELEMENT TO AUTO (3 ELEMENT)
CONTROL per procedure 4.4.1, Reactor Vessel Level Control System.
Notify the CRS when Reactor Water Level Control is in three element control.
NOTE: Ensure the Simulator is in RUN and tell the trainee to begin.
Nebraska Public Power District SKL034-20-123 (33001)
Cooper Nuclear Station Page 4 of 8 Job Performance Measure for Operations Revision 02 Task No: 259042P0101 SHIFTING FROM SINGLE ELEMENT TO AUTO (3 ELEMENT) CONTROL (Alternate Path) #1 Start Time: ____________
Performance Checklist Standards SAT UNSAT 12.1 At RVLC/RFPT HMI, selected RVLC system.
- 1. Select RVLC system
- CUE: RVLC Selected 12.2 Select CONTROL screen and verify on Master Controller that the PERMISSIVE
- 2. Select CONTROL ball is yellow.
screen CUE: The PERMISSIVE ball is NOT yellow.
NOTE to Examiner: Examinee must return at least one Steam Flow element to service to have the PERMISSIVE ball turn yellow.
12.3 If PERMISSIVE ball is not YELLOW, ensured the following conditions are met:
12.3.1 Master Level Controller is in AUTO.
12.3.2 Wide range FW flow transmitter is valid when associated RFP is in AUTO.
12.3.3 At least two steam flow elements are valid.
Note: This step will NOT be met and will require contacting system engineer.
- 3. Check Conditions 12.3.4 Turbine 1st stage flow is valid if less than four steam flow elements are valid 12.3.5 At least one individual RFP controller is in AUTO 12.3.6 Total steam flow greater than 1 Mlbm.
12.3.7 At least one Reactor Vessel Level indicator is valid.
CUE: Three steam flow elements are invalid
- 4. Contact System 12.4 If PERMISSIVE ball is still not YELLOW,
Nebraska Public Power District SKL034-20-123 (33001)
Cooper Nuclear Station Page 5 of 8 Job Performance Measure for Operations Revision 02 Task No: 259042P0101 SHIFTING FROM SINGLE ELEMENT TO AUTO (3 ELEMENT) CONTROL (Alternate Path) #1 Performance Checklist Standards SAT UNSAT Engineer or CRS contacted System Engineer.
- CUE: When asked by the applicant, the examiner (role playing as System Engineer/CRS) should ask What do you recommend so that we can get the system back to three element control?
- CUE: As System Engineer, agree with applicant to restore bypassed steam flow elements.
Referred to section 9 Restoring RVLC Input To
- 5. Restoring Input Service 9.1 At a RVLC/RFPT HMI, selected RVLC system
- 6. Select RVLC system CUE: RVLC system selected 9.2 Selected MIMIC screen and verified affected parameters are ready to be returned to service
- 7. Select MIMIC screen CUE: All four Steam flows are reading ~ the same 9.3 Selected MAINT screen
- 8. Select MAINT Screen CUE: MAINT screen selected.
9.4 On MAINT. screen, selected desired parameter
- 9. Select Steam Flow parameter. CUE: One Steam flow selected 9.5 On pop-up menu, pressed RESET button
- 10. Press RESET button.
CUE: Reset button depressed
Nebraska Public Power District SKL034-20-123 (33001)
Cooper Nuclear Station Page 6 of 8 Job Performance Measure for Operations Revision 02 Task No: 259042P0101 SHIFTING FROM SINGLE ELEMENT TO AUTO (3 ELEMENT) CONTROL (Alternate Path) #1 Performance Checklist Standards SAT UNSAT 9.6 Verified steam flow parameter tile turned green.
- 11. Verify affected parameter tile green CUE: Selected steam flow parameter turned GREEN.
Repeats Steps 9.5 and 9.6 for the other 2 Steam
- 12. Repeat Steps 9.5 and Flows 9.6 for the other 2 Steam Flows CUE: The Other two Steam flows are reset
- 13. Returns to section 12 of Returned to section 12.5 of procedure to complete procedure actions.
12.5 Placed RFC-SW-S2, 1 OR AUTO ELEMENT LEVEL CONTROL SWITCH in "1" position (Panel
- 14. Check RFC-SW-S2 9-5).
Position CUE: In 1 position 12.6 Placed RFC-SW-S2, 1 OR AUTO ELEMENT LEVEL CONTROL SWITCH to AUTO position.
- 15. Place RFC-SW-S2 in Auto. CUE: In Auto Position 12.7 At CONTROL screen, verified THREE ELEMENT ball is yellow
- 16. Check Control Screen CUE: THREE ELEMENT ball is yellow
- CUE: If asked, state the desired RPV level is 35 inches.
Informed CRS The RVLC system is in AUTO (3
- 17. Informs CRS ELEMENT) CONTROL.
Stop Time: __________ Total Time: ___________
Nebraska Public Power District SKL034-20-123 (33001)
Cooper Nuclear Station Page 7 of 8 Job Performance Measure for Operations Revision 02 Task No: 259042P0101 SHIFTING FROM SINGLE ELEMENT TO AUTO (3 ELEMENT) CONTROL (Alternate Path) #1 ATTACHMENT 1 SIMULATOR SET-UP A. Materials Required None B. Initialize the Simulator in IC IC-234 C. Run Batch File None D. Change the simulator Number Title TRG TD Sev Ramp Initial conditions as follows:
- 1. Triggers None
- 2. Malfunctions None N/A N/A N/A N/A N/A N/A N/A N/A
- 3. Remotes None N/A N/A
- 4. Overrides None N/A N/A Place simulator in Run and Bypass 3 of 4 Steam Flows from the
- 5. Panel Setup Maintenance Screen Note: If this JPM is to be performed more than once, take a SNAPSHOT after the panel setup is complete.
Nebraska Public Power District SKL034-20-123(33001)
Cooper Nuclear Station Page 8 of 8 Job Performance Measure for Operations Revision 01 Task No.: 259042P0101 ATTACHMENT 2 Directions to Trainee:
When I tell you to begin, you are to SHIFT FROM SINGLE ELEMENT TO AUTO (3 ELEMENT)
CONTROL on the RVLC System. Before you start, I will state the general plant conditions, the Initiating Cues and answer any questions you may have.
If being simulated In-Plant or Control Room:
When simulating, physically point to any meters, gauges, recorders and controls you would be using. State the position of controls as you would have manipulated them in order to complete the assigned task.
General Conditions:
- 1. The plant is stable at 100% Power.
- 2. Single Element Control due to RVLC Maintenance that is complete.
Initiating Cue(s):
The CRS Orders you to SHIFT RVLC FROM SINGLE ELEMENT TO AUTO (3 ELEMENT)
CONTROL per procedure 4.4.1, Reactor Vessel Level Control System.
Notify the CRS when Reactor Water Level Control is in three element control.
Nebraska Public Power District SKL034-20-116 (29983)
Cooper Nuclear Station Page 1 of 6 Job Performance Measure for Operations Revision 00 Task No. 200182A0501:
Recover From Manual Scoop Tube Operations Trainee: Examiner:
Pass Fail Examiner Signature: Date:
Additional Program Information:
- 1. Appropriate Performance Locations: CR / SIM
- 3. Evaluation Method: Simulate Perform
- 4. Performance Time: 10 minutes
- 5. NRC K/A 202002 A2.05 (3.1/3.1)
Directions to Examiner:
- 1. This JPM evaluates the trainee's ability to recover from manual scoop tube operations in accordance with 2.2.68.1, Reactor Recirculation System.
- 2. If this JPM is performed on the Simulator, only the cues preceded by "#" should be given.
- 3. Observe the trainee during performance of the JPM for proper use of self-checking methods.
- 4. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes/comments section below.
- 5. Brief the trainee, place the simulator in run, and tell the trainee to begin.
Notes/Comments: ____________________________________________________________
Nebraska Public Power District SKL034-20-116 (29983)
Cooper Nuclear Station Page 2 of 6 Job Performance Measure for Operations Revision 00 Task No. 200182A0501:
Recover From Manual Scoop Tube Operations Directions to Trainee:
When I tell you to begin, you are to RESET the SCOOP TUBE LOCKOUT in accordance with 2.2.68.1, Reactor Recirculation System Operations from the Control Room. Before you start, I will state the general plant conditions, the initiating cues and answer any questions you may have.
During task performance, state the actions you are taking, e.g.: repositioning controls and observing instrumentation.
General Conditions:
- 1. The plant is operating at 100% power.
- 2. The A Reactor Recirc Pump is being controlled locally.
- 3. All repairs are completed and the Scoop Tube is available.
General
References:
- 1. Procedure 2.2.68.1, Rev. 74, Reactor Recirculation System Operations General Tools and Equipment:
- 1. None Special Conditions, References, Tools, Equipment:
- 1. Simulator Setup: See Attachment 1.
- 2. Critical checks denoted by BOLD text.
- 3. Simulator cues denoted by "#".
Nebraska Public Power District SKL034-20-116 (29983)
Cooper Nuclear Station Page 3 of 6 Job Performance Measure for Operations Revision 00 Task No. 200182A0501:
Recover From Manual Scoop Tube Operations Task Standards:
- 1. The operator adjusts the manual control knob until L and S signals are within 2 and then resets the SCOOP TUBE LOCKOUT in accordance with 2.2.68.1, Reactor Recirculation System Operations from the control room per procedure.
- 2. 100% of critical elements successfully completed without error.
- 2. 100% of safety and radiological work practices.
Initiating Cue(s):
The Control Room Supervisor directs you to recover from manual scoop tube operations on the A Reactor Recirc Pump controller. Inform the CRS when the MG Set control has been restored the A Reactor Recirculation Pump.
Nebraska Public Power District SKL034-20-116 (29983)
Cooper Nuclear Station Page 4 of 6 Job Performance Measure for Operations Revision 00 Task No. 200182A0501:
Recover From Manual Scoop Tube Operations Start Time: ____________
Performance Checklist Standards SAT UNSAT
- 1. Obtain procedure The Operator obtained a copy of 2.2.68.1 Section 16. procedure 2.2.68.1 Section 16.
16.1 Selected Parameter S on RRFC-
- 2. Ensures S is SIC-16A.
selected.
Cue: S is displayed in the window.
16.2 Adjusted RRFC-SIC-16A manual control knob (Parameter S), as
- 3. Adjust S to make S necessary, until S and L lights are and L lights are off. off.
Cue: Both S and L lights are off.
16.3 Verified that Parameter V and P are within 2.0 of each other, by selecting each
- 4. Verify Parameter V parameter one at a time.
value is within 2.0 of Parameter P.
Cue: The values are within 2.0 of each other.
16.4 Pressed RRMG Set A Scoop Tube
- 5. Press Scoop Tube Lockout Reset button.
Lock Reset.
Cue: The lockout light and alarms clear.
Notified the CRS that the A RR Pump Scoop Tube Lockout has been reset.
- 6. Notifies the CRS.
- Cue: Respond as the CRS.
Stop Time: __________ Total Time: ___________
Nebraska Public Power District SKL034-20-116 (29983)
Cooper Nuclear Station Page 5 of 6 Job Performance Measure for Operations Revision 00 Task No. 200182A0501:
Recover From Manual Scoop Tube Operations ATTACHMENT 1 SIMULATOR SET-UP A. Materials Required None B. Initialize the Simulator in IC IC-234 C. Run Batch File None D. Change the simulator Number Title Tgr TD Sev Ramp Initial conditions as follows:
- 1. Triggers None Recirc Pump A
- 2. Malfunctions RR17A 1 0 78 0 84 Runback N/A N/A
- 3. Remotes None N/A N/A
- 4. Overrides None N/A N/A
- a. Place the simulator to RUN.
- 5. Panel Setup
- d. Rotate the controller for the RR Pump a few rotations to ensure a mismatch between parameters.
Note: If this JPM is to be performed more than once, take a SNAPSHOT after the panel setup is complete.
Nebraska Public Power District SKL034-20-116 (29983)
Cooper Nuclear Station Page 6 of 6 Job Performance Measure for Operations Revision 00 Task No.: 200182A0501 ATTACHMENT 2 Directions to Trainee:
When I tell you to begin, you are to RESET the SCOOP TUBE LOCKOUT in accordance with 2.2.68.1, Reactor Recirculation System Operations from the Control Room. Before you start, I will state the general plant conditions, the initiating cues and answer any questions you may have.
During task performance, state the actions you are taking, e.g.: repositioning controls and observing instrumentation.
General Conditions:
- 1. The plant is operating at 100% power.
- 2. The A Reactor Recirc Pump is being controlled locally.
- 3. All repairs are completed and the Scoop Tube is available.
Initiating Cue(s):
The Control Room Supervisor directs you to recover from manual scoop tube operations on the A Reactor Recirc Pump controller. Inform the CRS when the MG Set control has been restored the A Reactor Recirculation Pump.
Nebraska Public Power District SKL034-21-145(57055)
Cooper Nuclear Station Page 1 of 11 Job Performance Measure for Operations Revision 00 Task No.: 262072P0101
Title:
Transfer RPSPP1B from RPS MG Set B to CDP-1A FerTrainee: Examiner:
Pass Fail Examiner Signature: Date:
Additional Program Information:
- 1. Appropriate Performance Locations: CR / SIM
- 3. Evaluation Method: Simulate Perform
- 4. Performance Time: 25 minutes
- 5. NRC K/A 212000 A1.11 (3.4 / 3.3) and 212000.A2.02 (3.7/3.9)
Directions to Examiner:
- 1. This JPM evaluates the trainee's ability to Transfer RPSPP1B from RPS MG Set B to CDP-1A in accordance with Procedure 2.2.22, Vital Instrument Power System.
- 2. If this JPM is performed on the Simulator, only the cues preceded by "#" should be given.
- 3. Observe the trainee during performance of the JPM for proper use of self-checking methods.
- 4. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes/comments section below.
- 5. Brief the trainee, place the simulator in run, and tell the trainee to begin.
Notes/Comments: ____________________________________________________________
Nebraska Public Power District SKL034-21-145(57055)
Cooper Nuclear Station Page 2 of 11 Job Performance Measure for Operations Revision 00 Task No.: 262072P0101
Title:
Transfer RPSPP1B from RPS MG Set B to CDP-1A Directions to Trainee:
When I tell you to begin, you are to Transfer RPSPP1B from RPS MG Set B to CDP-1A in accordance with Procedure 2.2.22, Vital Instrument Power System. Before you start, I will state the general plant conditions, the initiating cues and answer any questions you may have.
During task performance, state the actions you are taking, e.g.: repositioning controls and observing instrumentation.
If being simulated in the Control Room:
When simulating, physically point to any meters, gauges, recorders and controls you would be using. State the position of controls as you would have manipulated them in order to complete the assigned task.
General Conditions:
- 1. The Plant is operating at 100% steady state power.
- 3. RWCU has been removed from service.
General
References:
- 1. Procedure 2.2.22, Vital Instrument Power System.
- 2. Procedure 2.2.47, HVAC Reactor Building.
General Tools and Equipment:
- 1. None Special Conditions, References, Tools, Equipment:
- 1. Simulator Setup: See Attachment 1.
- 2. Critical checks denoted by bold steps.
- 3. Simulator cues denoted by "#".
Nebraska Public Power District SKL034-21-145(57055)
Cooper Nuclear Station Page 3 of 11 Job Performance Measure for Operations Revision 00 Task No.: 262072P0101
Title:
Transfer RPSPP1B from RPS MG Set B to CDP-1A Task Standards:
- 1. The operator transfers RPSPP1B from RPS MG Set B to CDP-1A in accordance with Procedure 2.2.22, Vital Instrument Power System.
- 2. 100% of critical elements successfully completed without error.
- 3. 100% of safety and radiological work practices.
Initiating Cue(s):
The Control Room Supervisor directs you to Transfer RPSPP1B from RPS MG Set B to CDP-1A in accordance with Procedure 2.2.22, Vital Instrument Power System.
Notify the CRS when RPSPP1B has been transferred from RPS MG Set B to CDP-1A in accordance with Procedure 2.2.22, Vital Instrument Power System NOTE: Ensure the Simulator is in RUN and tell the trainee to begin.
Nebraska Public Power District SKL034-21-145(57055)
Cooper Nuclear Station Page 4 of 11 Job Performance Measure for Operations Revision 00 Task No.: 262072P0101
Title:
Transfer RPSPP1B from RPS MG Set B to CDP-1A Start Time: ____________
Performance Checklist Standards Sat Unsat The Operator obtained the current revision of
- 1. Obtain Procedure. Procedure 2.2.22, Vital Instrument Power System.
Selected Section 7.
- 2. Determines the task 7.6 Operator determined that step 7.6 is the begins at step 7.6. beginning step for this task.
7.6.1 At Panel 9-16 (Control Room), checked white ALT SOURCE AVAIL light above RPS
- 3. Determine alt power BUS B POWER TRANSFER switch is on source is available.
CUE: The white light is on.
7.6.1.1 Operator determined that this step is not
- 4. Step 7.6.1.1 is N/A.
applicable due to white light being lit.
7.6.2 In Panel 9-42 (Auxiliary Relay Room), for
- 5. Verify MSIV DC each open MSIV, checked MSIV DC Solenoids are solenoid ammeters are in green band.
energized.
- CUE: All solenoids are in green band.
Operator determined this step is not applicable due to RWCU being removed from service. (initial
- 6. Step 7.6.3 is N/A. conditions)
Nebraska Public Power District SKL034-21-145(57055)
Cooper Nuclear Station Page 5 of 11 Job Performance Measure for Operations Revision 00 Task No.: 262072P0101
Title:
Transfer RPSPP1B from RPS MG Set B to CDP-1A Performance Checklist Standards Sat Unsat
- 7. Secure Rx. Bldg. 7.6.4 Operator Obtained procedure 2.2.47 to secure Ventilation. Reactor Building Ventilation.
9.3 Operator notified the RP Dept. that ventilation was being secured.
- 8. Notify RP Dept. #CUE: RP acknowledges Rx Bldg. Ventilation is being secured and will perform necessary controls.
9.4 Operator notified the Safety Dept. that ventilation was being secured.
- 9. Notify Safety Dept. #CUE: Safety representative acknowledges Rx Bldg.
Ventilation is being secured and will perform necessary monitoring and controls.
9.5 - 9.7 Operator dispatched an operator to secure local Hood Exhaust Fans HF-R-1A, HF-R-1B, and HF-R-1C.
- 10. Secure Exhaust Fume Hoods.
- CUE: Operator has been dispatched and secured the local Hood Exhaust Fans.
- 11. N/A step Determined Step 9.8 is N/A.
NOTE to Examiner: Next Steps are from Procedure 2.2.47.
9.9 Start SGT System per Procedure 2.2.73 to
- 12. Start SGT per maintain Reactor Building pressure negative.
procedure 2.2.73.
Nebraska Public Power District SKL034-21-145(57055)
Cooper Nuclear Station Page 6 of 11 Job Performance Measure for Operations Revision 00 Task No.: 262072P0101
Title:
Transfer RPSPP1B from RPS MG Set B to CDP-1A Performance Checklist Standards Sat Unsat
6.1 At VBD-R, placed SGT-DPIC-546, RX BLDG/SGT DP, in AUTO with setpoint adjusted to maintain -0.25" wg.
- 14. Select control setting.
CUE: SGT-DPIC-546 is in AUTO and setpoint is adjusted.
6.2 At VBD-K, placed SGT in service:
6.2.1 SGT A
- a. Started EF-R-1E, SGT A EXHAUST FAN
- c. Checked SGT-AO-251, SGT A DISCHARGE, opened.
- 16. Remove RX Bldg 6.3 At VBD-R, removed Reactor Building H&V H&V from service. System from service per Procedure 2.2.47.
NOTE to Examiner: Next Steps are from Procedure 2.2.47.
9.10 Placed control switches for the following fans to OFF in order listed:
- a. EXHAUST FAN selected to STBY, EF-R-1A or EF-R-1B
- 17. Continue in 2.2.47 b. EXH BSTR FAN selected to STBY, BF-R-1A or to secure Rx. Bldg. BF-R-1B Ventilation. c. SUPPLY FAN selected to STBY, SF-R-1A-A or SF-R-1A-B CUE: Fans are OFF
Nebraska Public Power District SKL034-21-145(57055)
Cooper Nuclear Station Page 7 of 11 Job Performance Measure for Operations Revision 00 Task No.: 262072P0101
Title:
Transfer RPSPP1B from RPS MG Set B to CDP-1A Performance Checklist Standards Sat Unsat 9.11Performed the following in rapid succession:
- a. Place control switch for operating EXH BSTR FAN to OFF
- b. B. Place control switch for operating SUPPLY FAN to OFF
- c. C. Place control switch for operating
- 18. Secure Rx Bldg EXHAUST FAN to OFF Fans.
- d. Close AO-257, HV-R-1A DISCH VLV
9.12 Closed the following Secondary Containment Isolation Valves:
- a. MO-272, HV-R-1A DISCH VLV
- 19. Close Secondary c. MO-260, EXH FANS DISCH VLV Containment Isolation Valves. CUE: Valves are CLOSED
- CUE: Another operator will perform the remaining steps in Procedure 2.2.73 NOTE to Examiner: Next Steps are from Procedure 2.2.22.
7.6.5 If AOG in service, then prevent AOG isolation by performing following:
7.6.5.1 Notified SM that RHR-MO-921 will be inoperable.
- 20. Returned to 2.2.22
- CUE: SM acknowledges RHR-MO-921 will be Prevent AOG from INOP.
Isolating.
7.6.5.2 At Panel BB3, open breaker 7 for RHR-MO-921.
- CUE: Another operator will open breaker 7 at BB3, and the action is complete.
Nebraska Public Power District SKL034-21-145(57055)
Cooper Nuclear Station Page 8 of 11 Job Performance Measure for Operations Revision 00 Task No.: 262072P0101
Title:
Transfer RPSPP1B from RPS MG Set B to CDP-1A Performance Checklist Standards Sat Unsat 7.6.6. Notified SM that Drywell Vent Monitor and Reactor water conductivity monitoring will be
- 21. Notify SM of INOP due to group isolations.
systems INOP due to group isolations. #CUE: SM acknowledges Drywell Vent Monitor and Rx. Water conductivity monitoring are INOP.
7.6.7 Determined this step is not applicable due to RWCU being removed from service. (initial
- 22. Step 7.6.7 is N/A. conditions)
- CUE: RWCU has been removed from service.
7.6.8 Requested another operator be stationed at
RPS MG Set B Room. #CUE: Another operator is stationed at the RPS MG Set B Room.
7.6.9 At panel 9-16, placed RPS BUS B POWER TRANSFER switch to ALT FEED, and verified:
7.6.9.1 Checked Red ALT SOURCE ON light is on.
7.9.6.2 Checked Red GEN B ON light is off 7.6.9.3 Checked with operator at RPS MG SET ROOM B that Red LOAD CONNECTED TO
- 24. Transfer power to EMERGENCY light is on, and Red LOAD alternate source.
CONNECTED TO NORMAL light is off.
- CUE: Red LOAD CONNECTED TO EMERGENCY light is on, and Red LOAD CONNECTED TO NORMAL light is off.
- 25. Release Transfer 7.6.10 Released RPS BUS B POWER TRANSFER Switch. switch.
Nebraska Public Power District SKL034-21-145(57055)
Cooper Nuclear Station Page 9 of 11 Job Performance Measure for Operations Revision 00 Task No.: 262072P0101
Title:
Transfer RPSPP1B from RPS MG Set B to CDP-1A Performance Checklist Standards Sat Unsat Informed the CRS the RPSPP1B has been transferred from RPS MG Set B to CDP-1A in accordance with Procedure 2.2.22, Vital
- 26. Notifies the CRS. Instrument Power System.
- CUE: Respond as CRS.
Stop Time: __________ Total Time: ___________
Nebraska Public Power District SKL034-21-145(57055)
Cooper Nuclear Station Page 10 of 11 Job Performance Measure for Operations Revision 00 Task No.: 262072P0101
Title:
Transfer RPSPP1B from RPS MG Set B to CDP-1A ATTACHMENT 1 SIMULATOR SET-UP A. Materials Required None B. Initialize the Simulator in IC IC 234 C. Run Batch File D. Change the simulator conditions as follows:
- 1. Triggers Number File Name Description
- 2. Malfunctions Number Title Trigger TD Severity Ramp Initial None N/A 0 N/A 0 N/A
- 3. Remotes Number Title Trigger TD Value Ramp None 0 N/A
- 4. Overrides Instrument Tag Trigger TD Value Ramp None
- 1. Place simulator in RUN.
- 5. Panel Setup 2. Remove RWCU from service
- 3. Ensure SGT A, is PREFERRED.
Note: If this JPM is to be performed more than once, take a SNAPSHOT after the panel setup is complete.
Nebraska Public Power District SKL034-21-145(57055)
Cooper Nuclear Station Page 11 of 11 Job Performance Measure for Operations Revision 00 ATTACHMENT 2 Directions to Trainee:
When I tell you to begin, you are to Transfer RPSPP1B from RPS MG Set B to CDP-1A in accordance with Procedure 2.2.22, Vital Instrument Power System. Before you start, I will state the general plant conditions, the initiating cues and answer any questions you may have.
During task performance, state the actions you are taking, e.g.: repositioning controls and observing instrumentation.
If being simulated in the Control Room:
When simulating, physically point to any meters, gauges, recorders and controls you would be using. State the position of controls as you would have manipulated them in order to complete the assigned task.
General Conditions:
- 1. The Plant is operating at 100% steady state power.
- 3. RWCU has been removed from service Initiating Cue(s):
The Control Room Supervisor directs you to Transfer RPSPP1B from RPS MG Set B to CDP-1A in accordance with Procedure 2.2.22, Vital Instrument Power System.
Notify the CRS when RPSPP1B has been transferred from RPS MG Set B to CDP-1A in accordance with Procedure 2.2.22, Vital Instrument Power System.
Nebraska Public Power District SKL034-21-146 (57056)
Cooper Nuclear Station Page 1 of 9 Job Performance Measure for Operations Revision 00 Task No.: 200185A0501
Title:
RPV Depressurization with RWCU (Alternate Path)
Trainee: Examiner:
Pass Fail Examiner Signature: Date:
ALTERNATE PATH Additional Program Information:
- 1. Appropriate Performance Locations: CR / SIM
- 3. Evaluation Method: Simulate Perform
- 4. Performance Time: 20 minutes
- 5. NRC K/A 204000 A4.03 (3.2 / 316) and 204000 A1.04 (2.8/2.8)
Directions to Examiner:
Note: This JPM is an Alternate Path JPM. The valve will not operate when aligning blowdown to the condenser and blowdown to Radwaste must be used.
- 1. This JPM evaluates the trainee's ability to perform RPV Depressurization with RWCU from the Control Room in accordance with Procedure 5.8.2.
- 2. If this JPM is performed on the Simulator, only the cues preceded by "#" should be given.
- 3. Observe the trainee during performance of the JPM for proper use of self-checking methods.
- 4. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes/comments section below.
- 5. Brief the trainee, place the simulator in run, and tell the trainee to begin.
Notes/Comments: ____________________________________________________________
Nebraska Public Power District SKL034-21-146 (57056)
Cooper Nuclear Station Page 2 of 9 Job Performance Measure for Operations Revision 00 Task No.: 200185A0501
Title:
RPV Depressurization with RWCU (Alternate Path)
Directions to Trainee:
When I tell you to begin, you are to perform RPV Depressurization with RWCU to the main condenser from the Control Room in accordance with Procedure 5.8.2., RPV Depressurization Systems (Table 2) from the Control Room. Before you start, I will state the general plant conditions, the initiating cues and answer any questions you may have.
During task performance, state the actions you are taking, e.g.: repositioning controls and observing instrumentation.
If being simulated in the Control Room:
When simulating, physically point to any meters, gauges, recorders and controls you would be using. State the position of controls as you would have manipulated them in order to complete the assigned task.
General Conditions:
- 1. The Plant has scrammed.
- 2. EOPs have been entered.
- 3. Reactor Depressurization is required per the EOPs.
General
References:
Procedure RPV Depressurization with RWCU from the Control Room in accordance with Procedure 5.8.2., RPV Depressurization Systems (Table 2).
General Tools and Equipment:
- 1. None Special Conditions, References, Tools, Equipment:
- 1. Simulator Setup: See Attachment 1.
- 2. Critical checks denoted by bold text.
- 3. Simulator cues denoted by "#".
- 4. Alternate path denoted by.
Nebraska Public Power District SKL034-21-146 (57056)
Cooper Nuclear Station Page 3 of 9 Job Performance Measure for Operations Revision 00 Task No.: 200185A0501
Title:
RPV Depressurization with RWCU (Alternate Path)
Task Standards:
- 1. The operator performs RPV depressurization with RWCU by attempting to blow down to the main condenser and transition to blowing down to Radwaste in accordance with Procedure 5.8.2., RPV Depressurization Systems (Table 2) from the control room.
- 2. 100% of critical elements successfully completed without error.
- 3. 100% of safety and radiological work practices.
Initiating Cue(s):
The Control Room Supervisor directs you to depressurize the RPV with RWCU to the main condenser from the control room in accordance with procedure 5.8.2, RPV Depressurization Systems (Table 2).
Notify the CRS when you are depressurizing the RPV with RWCU.
NOTE: Ensure the Simulator is in RUN and tell the trainee to begin.
Nebraska Public Power District SKL034-21-146 (57056)
Cooper Nuclear Station Page 4 of 9 Job Performance Measure for Operations Revision 00 Task No.: 200185A0501
Title:
RPV Depressurization with RWCU (Alternate Path)
Start Time: ____________
Performance Checklist Standards Sat Unsat The Operator obtained the current revision of
- 1. Obtain Procedure Procedure 5.8.2, RPV Depressurization Systems.
Selected Section 15.
- 2. Refer to Section 3 15.1 Operator referred to Section 3 for for dispatching dispatching personnel when actions outside personnel the Control are required.
15.2 Operator determined that Step 15.2 can be N/Ad since it is not required by plant conditions.
- 3. N/A Steps CUE: If Operator chooses to install PTMs, respond that another operator will install the PTMs and they are complete.
15.3 Operator verified Group 3 Isolation was present per procedure 2.1.22. (Hard Card)
CUE: Group 3 Channel A and B lights are out on Panel 9-5.
RWCU-MO-18, OUTBD ISOL VLV indicates CLOSED on Panel 9-4.
Nebraska Public Power District SKL034-21-146 (57056)
Cooper Nuclear Station Page 5 of 9 Job Performance Measure for Operations Revision 00 Task No.: 200185A0501
Title:
RPV Depressurization with RWCU (Alternate Path)
Performance Checklist Standards Sat Unsat 15.3.1-3 Operator reset Group 3 Isolation signal by
- a. turning GROUP ISOL RESET CHANNEL A and CHANNEL B, switches to the right RESET position and then releasing to NOR at panel 9-5.
CUE: Group 3 Channel A and B lights are ON at Panel 9-5.
RWCU-MO-15, INBD ISOL VLV, indicates OPEN at panel 9-4.
RWCU-MO-18, OTBD ISOL VLV, indicates OPEN at panel 9-4.
15.4 Placed running RWCU PUMP switch to
- 6. Stop Running STOP, if running.
RWCU Pump CUE: RWCU pumps are not running.
15.5 Closed RWCU-MO-68, RETURN LINE TO
- 7. Closes return to RX VLV.
RPV CUE: RWCU-MO-68 is CLOSED.
15.6 Verified RWCU F/Ds are in hold by having operator at local F/D panel 12-4-98A/B place the F/D in Hold.
- 8. Verify RWCU F/Ds in Hold
- CUE As local operator acknowledge the direction to place F/Ds in Hold until the action is complete. If asked, steps 15.6.1.1 through 15.6.2.4 are complete.
Nebraska Public Power District SKL034-21-146 (57056)
Cooper Nuclear Station Page 6 of 9 Job Performance Measure for Operations Revision 00 Task No.: 200185A0501
Title:
RPV Depressurization with RWCU (Alternate Path)
Performance Checklist Standards Sat Unsat 15.7 Operator ensured the following:
- a. RWCU-RMC-143, BD VLV 55 FLOW CONTROL, was adjusted to zero.
- b. RWCU-MO-74, DEMIN SUCTION BYPASS VLV, was open.
- c. RWCU-MO-53, BLOWDOWN ORIFICE BYPASS VLV was open.
- 9. Verify Flowpath CUE:
- a. RWCU-RMC-143, BD VLV 55 FLOW CONTROL, is set to zero.
- b. RWCU-MO-74, DEMIN SUCTION BYPASS VLV, is open.
- c. RWCU-MO-53, BLOWDOWN ORIFICE BYPASS VLV is open.
15.8 Operator aligned blowdown to the Main
- 10. Align Blowdown Condenser by opening RWCU-MO-56.
Flowpath to Main Condenser CUE: RWCU-MO-56 will NOT OPEN.
Note to Examiner: Operator may choose to continue and redirect blowdown to Radwaste without CRS approval but will inform CRS afterward.
Operator reports failure of MO-56 to open to the CRS.
CUE: CRS acknowledges.
- 11. Report failure of #CUE: If asked what to do, the examiner should MO-56 to open. ask the applicant what he/she recommends. The operator should recommend to blowdown to Radwaste. If the applicant doesnt have a recommendation, the examiner should role play as the CRS and inform the applicant that we need to blowdown.
Nebraska Public Power District SKL034-21-146 (57056)
Cooper Nuclear Station Page 7 of 9 Job Performance Measure for Operations Revision 00 Task No.: 200185A0501
Title:
RPV Depressurization with RWCU (Alternate Path)
Performance Checklist Standards Sat Unsat 15.8 Operator aligns blowdown to Radwaste
- 12. Align Blowdown by opening RWCU-MO-57.
Flowpath to Radwaste CUE: RWCU-MO-57 is OPEN.
NOTE to Examiner: If asked, tell the examinee two handed operation is permitted for the next step. The operator will be required to hold the start switch for the pump while throttling flow to approximately 70 gpm, then they can let go of the pump start switch.
15.9 Placed and held RWCU Pump A(B) switch to START at panel 9-4.
15.12 Throttled RWCU-FCV-55, BLOWDOWN FLOW CONTROL VLV, using RWCU-RMC-143, BD VLV 55 FLOW CONTROL to achieve desired cooldown rate and did not exceed 70 GPM, and maintain
>200 psig above RPV pressure by
- 14. Set Blow down throttling RWCU-MO-68, RETURN LINE Flow rate TO RX VLV.
CUE: Pressure on RWCU-PI-131 indicates approximately 220 psi above reactor pressure.
Blowdown flow is less than 70 gpm.
15.13 Inform CRS that RWCU is being utilized to
Stop Time: __________ Total Time: ___________
Nebraska Public Power District SKL034-21-146 (57056)
Cooper Nuclear Station Page 8 of 9 Job Performance Measure for Operations Revision 00 Task No.: 200185A0501
Title:
RPV Depressurization with RWCU (Alternate Path)
ATTACHMENT 1 SIMULATOR SET-UP A. Materials Required None B. Initialize the Simulator in IC IC-237 C. Run Batch File None D. Change the simulator conditions as follows:
- 1. Triggers Number File Name Description
- 2. Malfunctions Number Title Trigger TD Severity Ramp Initial None N/A 0 N/A 0 N/A N/A 0 N/A 0 N/A
- 3. Remotes Number Title Trigger TD Value Ramp CU16 PTM 44 &45 N/A 0 N/A
- 4. Overrides Override RWCU-MO-56 in the CLOSED position.
Instrument Tag Trigger TD Value Ramp None
- 1. Ensure reactor is scrammed and a Group 3 is present
- 5. Panel Setup 2. Throttle open RWCU-MO-74
- 3. Ensure the simulator is in RUN and PTMs are active.
Note: If this JPM is to be performed more than once, take a SNAPSHOT after the panel setup is complete.
Nebraska Public Power District SKL034-21-146 (57056)
Cooper Nuclear Station Page 9 of 9 Job Performance Measure for Operations Revision 00 ATTACHMENT 2 Directions to Trainee:
When I tell you to begin, you are to perform RPV Depressurization with RWCU to the main condenser from the Control Room in accordance with Procedure 5.8.2., RPV Depressurization Systems (Table 2) from the Control Room. Before you start, I will state the general plant conditions, the initiating cues and answer any questions you may have.
During task performance, state the actions you are taking, e.g.: repositioning controls and observing instrumentation.
If being simulated in the Control Room:
When simulating, physically point to any meters, gauges, recorders and controls you would be using. State the position of controls as you would have manipulated them in order to complete the assigned task.
General Conditions:
- 1. The Plant has scrammed.
- 2. EOPs have been entered.
- 3. Reactor Depressurization is required per the EOPs.
Initiating Cue(s):
The Control Room Supervisor directs you to depressurize the RPV with RWCU to the main condenser from the control room in accordance with procedure 5.8.2, RPV Depressurization Systems (Table 2).
Notify the CRS when you are depressurizing the RPV with RWCU.
Nebraska Public Power District SKL034-20-56 (2139)
Cooper Nuclear Station Page 1 of 9 Job Performance Measure for Operations Revision 10 Task No.: 206033P0201 Task
Title:
START HPCI FROM THE ASD ROOM Trainee: Examiner:
Pass Fail Examiner Signature: Date:
Additional Program Information:
- 1. Appropriate Performance Locations: Plant/SIM
- 3. Evaluation Method Simulate Perform
- 4. Performance Time: 20 minutes
- 5. NRC K/As: 295016 AK2.01 4.4/4.5 Directions to Examiner:
- 2. If this JPM is performed on the Simulator, only the cues preceded by "#" should be given.
- 3. Observe the trainee during performance of the JPM for proper use of self-checking methods.
- 4. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes section below.
- 5. Give the trainee Attachment 2.
- 6. Brief the trainee, place the simulator in run, and tell the trainee to begin.
Notes:
Nebraska Public Power District SKL034-20-56 (2139)
Cooper Nuclear Station Page 2 of 9 Job Performance Measure for Operations Revision 10 Task No.: 206033P0201 Task
Title:
START HPCI FROM THE ASD ROOM Directions to Trainee:
When I tell you to begin, you are to start HPCI from the ASD room. Before you start, I will state the general plant conditions, the initiating cues, and answer any questions you may have.
When simulating, physically point to any meters, gauges, recorders, and controls you would be using. State the position of controls as you would have manipulated them to start HPCI from the ASD room. During performance, state the actions you are taking, e.g.:
repositioning controls and observing instrumentation.
General Conditions:
- 1. 0% Reactor Power, Reactor Scrammed
- 2. Main turbine tripped.
- 3. Control Room is filled with toxic gas, non-fire source.
- 4. CSCS systems are all in standby status.
- 5. The RCIC system is INOPERABLE for a maintenance outage.
- 6. The Control Room has been evacuated.
General
References:
- 1. Emergency Procedure 5.1ASD.
General Tools and Equipment:
- 1. Key for ASD Room
- 2. Emergency Procedure 5.1ASD, Attachment 1 Special Conditions, References, Tools, Equipment:
- 1. Simulator Setup: See Attachment 1.
- 2. Critical checks denoted by "*".
- 3. Simulator cues denoted by "#".
Nebraska Public Power District SKL034-20-56 (2139)
Cooper Nuclear Station Page 3 of 9 Job Performance Measure for Operations Revision 10 Task No.: 206033P0201 Task
Title:
START HPCI FROM THE ASD ROOM Task Standards:
- 1. Accurately locate, identify, operate and/or manipulate all component controls required to be utilized to perform control level and pressure with HPCI from the ASD room per Procedure 5.1ASD.
- 2. 100% of critical elements successfully completed without error.
- 3. 100% of safety and radiological work practices.
Initiating Cue(s):
You are the ASD Operator and the Shift Manager has directed you to start the HPCI System from the ASD Panel per 5.1ASD, Att.1. Steps 1 through 6 of Attachment 1 have been completed. The Shift Manager is in the TSC; inform him when HPCI is running and available to be lined up for injection.
Note: Place the simulator in RUN and tell the trainee to begin.
Nebraska Public Power District SKL034-20-56 (2139)
Cooper Nuclear Station Page 4 of 9 Job Performance Measure for Operations Revision 10 Task No.: 206033P0201 Task
Title:
START HPCI FROM THE ASD ROOM Start Time: _____________
Performance Checklist Standard Sat Unsat 7.2 Observed 0 speed on HPCI-SI-2793,
- 1. Determine HPCI not running. TURBINE SPEED.
AOP MO-20 MO-24 MO-25 MO-21 MO-14 MO-19 FCU GSCB/P MO-58 MO-17 CUE: (As operated) each switch is in ISOLATE.
- 3. Ensure HPCI 14, 7.3.2 Ensured CLOSED the following valves:
19, 25, & 58 are CLOSED: HPCI-MO-14, STEAM TO TURBINE HPCI-MO-19, INJECTION HPCI-MO-25, MINIMUM FLOW BYPASS HPCI-MO-58, TORUS PUMP SUCTION CUE (As checked): GREEN light ON. RED light OFF.
Nebraska Public Power District SKL034-20-56 (2139)
Cooper Nuclear Station Page 5 of 9 Job Performance Measure for Operations Revision 10 Task No.: 206033P0201 Task
Title:
START HPCI FROM THE ASD ROOM Performance Checklist Standard Sat Unsat
- 4. Ensure HPCI 17, 20, 7.3.3 Opened the following valves:
24, and 21 are OPEN: HPCI-MO-24, ECST Test Line Shutoff HPCI-MO-21, Test Bypass to ECST CUE (As checked): RED light ON. GREEN light OFF.
CUE: RED light ON. GREEN light OFF.
- 6. Place GSCB in 7.3.5 Placed GLAND SEAL CNDSR BLOWER AUTO control switch in AUTO.
CUE: Switch is in mid-position.
- 7. Place GSCCP in 7.3.6 Placed GLAND SEAL CNDSR COND AUTO PUMP control switch in AUTO.
CUE: Switch is in mid-position.
- 8. Set HPCI Flow 7.3.7 Set HPCI-FIC-1108, HPCI FLOW Controller and place CONTROLLER to 4250 gpm and placed in in MANUAL MANUAL.
CUE: The red line on the FIC is on 4250 gpm and tab is to the left.
Nebraska Public Power District SKL034-20-56 (2139)
Cooper Nuclear Station Page 6 of 9 Job Performance Measure for Operations Revision 10 Task No.: 206033P0201 Task
Title:
START HPCI FROM THE ASD ROOM Performance Checklist Standard Sat Unsat
- 9. OPEN HPCI-MO-14, 7.3.8 Placed control switch for HPCI-MO-14 Steam to Turbine to OPEN.
CUE: RED light ON, GREEN light OFF.
- 10. Start the Auxiliary 7.3.9 Placed control switch for the auxiliary Oil Pump oil pump to START.
CUE: RED light ON, GREEN light OFF.
- 11. Ensure the Turbine 7.3.10 Ensured the speed of the HPCI pump is Speed is >2050 >2050 RPM by adjusting Flow rpm Controller HPCI-FIC-1108 OPEN and CLOSE pushbuttons.
CUE: Speed (and therefore flow) is dependent on RCS pressure at the time the JPM is being performed and may not be critical if no adjustment is needed. RCS pressure is varying slightly in the IC snap because of the plant conditions given in the stem.
- 12. Inform the Shift Informed Shift Manager the HPCI pump is running Manager the task is and available to be lined up for injection.
complete.
- CUE: The Shift Manager acknowledges the report.
Stop Time: _____________ Stop Time: _____________
Nebraska Public Power District SKL034-20-56 (2139)
Cooper Nuclear Station Page 7 of 9 Job Performance Measure for Operations Revision 10 Task No.: 206033P0201 Task
Title:
START HPCI FROM THE ASD ROOM ATTACHMENT 1 SIMULATOR SET-UP A. Materials Required None B. Initialize the Simulator in IC-18 or LOR equivalent. (IC-237)
Batch File Name - JPM/342056.
C. Change the simulator conditions as follows:
- 1. Triggers - None
- 2. Malfunctions Number Title Trigger TD Severity Ramp Initial RC01 RCIC System Failure to N/A N/A N/A N/A N/A Auto Start RP02 Rx Scram N/A N/A N/A N/A N/A FW01a RFP A Trip N/A N/A N/A N/A N/A FW01b RFP B Trip N/A N/A N/A N/A N/A TC01 Main Turbine Trip N/A N/A N/A N/A N/A HP01 HPCI System Failure to N/A N/A N/A N/A N/A Start RP08a Spurious Group 1 Isol. N/A N/A N/A N/A N/A Signal Channel A-1 RP08c Spurious Group 1 Isol. N/A N/A N/A N/A N/A Signal Channel B-1
- 3. Remotes - None
Nebraska Public Power District SKL034-20-56 (2139)
Cooper Nuclear Station Page 8 of 9 Job Performance Measure for Operations Revision 10 Task No.: 206033P0201 Task
Title:
- 4. Overrides - None
- 5. Panel Setup
- a. Insert Batch File jpm/342056.
- b. Place Simulator in RUN.
- c. Trip all but one Condensate and Condensate booster pump.
- d. Place following HPCI Isolation switches to ISOL.
LEVEL INDICATORS HPCI CONTROL AND INDICATION MO-15 MO-16
- e. Place Simulator in FREEZE.
Note: If this JPM is to be performed more than once, snap the simulator into IC-0 after the Panel setup is complete.
Nebraska Public Power District SKL034-20-56 (2139)
Cooper Nuclear Station Page 9 of 9 Job Performance Measure for Operations Revision 10 ATTACHMENT 2 Directions to Trainee:
When I tell you to begin, you are to start HPCI from the ASD room. Before you start, I will state the general plant conditions, the initiating cues, and answer any questions you may have.
When simulating, physically point to any meters, gauges, recorders, and controls you would be using. State the position of controls as you would have manipulated them to start HPCI from the ASD room. During performance, state the actions you are taking, e.g.:
repositioning controls and observing instrumentation.
General Conditions:
- 1. 0% Reactor Power, Reactor Scrammed
- 2. Main turbine tripped.
- 3. Control Room is filled with toxic gas, non-fire source.
- 4. CSCS systems are all in standby status.
- 5. The RCIC system is INOPERABLE for a maintenance outage.
- 6. The Control Room has been evacuated.
Initiating Cue(s):
You are the ASD Operator and the Shift Manager has directed you to start the HPCI System from the ASD Panel per 5.1ASD, Att.1. Steps 1 through 6 of Attachment 1 have been completed. The Shift Manager is in the TSC; inform him when HPCI is running and available to be lined up for injection.
Nebraska Public Power District SKL034-20-24(34969)
Cooper Nuclear Station Page 1 of 8 Job Performance Measure for Operations Revision 09 Task No.: 219001O0101 Task
Title:
Startup the Suppression Pool Cooling Mode of RHR (Alternate Path)
Trainee: Examiner:
Pass Fail Examiner Signature: Date:
ALTERNATE PATH JPM Additional Program Information:
- 1. Appropriate Performance Locations: Simulator
- 2. Appropriate Trainee level: RO/SRO
- 3. Evaluation Method: Perform
- 4. Performance Time: 23 minutes
- 5. NRC K/A 219000 A4.01 (3.8/3.7)
Directions to Examiner:
NOTE: THIS IS AN ALTERNATE PATH JPM. The first RHR Pump will TRIP when it is started.
- 2. If this JPM is performed on the Simulator, only the cues preceded by "#" should be given.
- 3. Observe the trainee during performance of the JPM for proper use of self-checking methods.
- 4. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes section below.
- 5. Give the trainee Attachment 2.
- 6. Brief the trainee, place the simulator in run, and tell the trainee to begin.
Notes:
Nebraska Public Power District SKL034-20-24(34969)
Cooper Nuclear Station Page 2 of 8 Job Performance Measure for Operations Revision 09 Task No.: 219001O0101 Task
Title:
Startup the Suppression Pool Cooling Mode of RHR (Alternate Path)
Directions to Trainee:
When I tell you to begin, you are to startup the suppression pool cooling mode of RHR.
Before you start, I will state the general plant conditions, the Initiating Cues and answer any questions you may have.
When simulating, physically point to any meters, gauges, recorders and controls you would be using. State the position of controls as you would have manipulated them to startup the suppression pool cooling mode of RHR. During performance, state the actions you are taking, e.g.: repositioning controls and observing instrumentation.
General Conditions:
- 2. The RHRSW system is in standby status per procedure 2.2.70.
- 4. Suppression Pool cooling is NOT required by the EOPs.
- 5. All procedure prerequisites have been met for placing RHR Loop A in suppression pool cooling.
- 6. The NLO has completed venting loop A (2.2.69.3 through Step 4.13).
- 7. ALARA has determined the suction drain flush is not required.
- 8. The RPs have been notified of the system start.
- 9. Another operator is to perform 2.2.69.3 Section 3.
General
References:
- 1. Procedure 2.2.69.3
- 2. Procedure 2.2.70 General Tools and Equipment:
- 1. Key 2235 Special Conditions, References, Tools, Equipment:
- 1. Simulator Setup: See Attachment 1.
- 2. Critical steps denoted in bold.
- 3. Simulator cues denoted by "#".
- 4. Alternate path denoted by.
Nebraska Public Power District SKL034-20-24(34969)
Cooper Nuclear Station Page 3 of 8 Job Performance Measure for Operations Revision 09 Task No.: 219001O0101 Task
Title:
Startup the Suppression Pool Cooling Mode of RHR (Alternate Path)
Task Standards:
- 1. The operator begins placing RHR Loop A in SPC and after the pump trips, starts another pump and completes placing the loop into service per Procedure 2.2.69.3.
- 2. 100% of critical elements successfully completed without error.
- 3. 100% of safety and radiological work practices.
Initiating Cue(s):
The Control Room Supervisor directs you to startup RHR Loop A in suppression pool cooling and establish maximum cooldown rate using the A RHR pump per procedure 2.2.69.3. The hard card is NOT to be used. Inform the CRS when the A loop of RHR is in suppression Pool Cooling at maximum cooldown rate.
Any plant announcements will be simulated.
NOTE: Place the Simulator in RUN and tell the trainee to begin.
Nebraska Public Power District SKL034-20-24(34969)
Cooper Nuclear Station Page 4 of 8 Job Performance Measure for Operations Revision 09 Task No.: 219001O0101 Task
Title:
Startup the Suppression Pool Cooling Mode of RHR (Alternate Path)
Start Time _________
Performance Checklist Standards Sat Unsat
- 1. Obtained Procedure Obtained Procedure 2.2.70.
NOTE to Examiners: Candidate may place A or C SWBP in service.
5.1.1 Held SWBP A (C) switch to
- 2. Place SWBP in START until pump starts. (Panel service 9-3)
- 3. Check AMPS 5.1.2 Checked AMPS normal. (Panel 9-3)
- 5. Adjust flow. 5.1.4 Adjusted SW-SW-MO89A to maintain close to 4000gpm.
- 6. Check AMPS 5.1.4.2 Ensured AMPS 136.
5.1.5 Ensured d/p on SW-DPI-359A 17.0 psid. (HX Room)
- 7. Check HX d/p.
- CUE: When contacted as NLO report SW-DPI-359A indicates 4 psid.
NOTE to Examiners: Tell candidate another operator will record HX d/p in narrative logs.
4.15 Informed SM LPCI Mode of RHR
- 8. Inform SM LPCI A Subsystem A is inoperable.
- CUE: SM acknowledges.
NOTE to Examiners: Steps 4.16 through 4.18 are N/A.
4.19 Obtained Key and opened
- 9. Open MO-39A RHR-MO-39A, SUPPR POOL COOLING/TORUS SPRAY VLV.
- 10. 4.20 Step is N/A.
4.21 Placed control switch for RHR
- 11. Start Pump A Pump A to START. (Panel 9-3)
Nebraska Public Power District SKL034-20-24(34969)
Cooper Nuclear Station Page 5 of 8 Job Performance Measure for Operations Revision 09 Task No.: 219001O0101 Task
Title:
Startup the Suppression Pool Cooling Mode of RHR (Alternate Path)
Performance Checklist Standards Sat Unsat
- 12. Notices pump did Observed the RHR Pump A did not start.
not start.
Notified CRS or SM RHR Pump A did not start.
Referred to alarm cards 9-3-1/B-4, RHR Pump A Trip and 9-3-1/C4, RHR Pump A
- 13. Notifies SM or Ovld/Ground.
CRS.
Start Pump C 4.21 Placed control switch for RHR Pump C to START. (Panel 9-3)
- CUE: If asked about starting RHR Pump C, ask the examinee what he/she recommends.
- CUE: (If asked) CRS states someone
- 14. Initiate a CR. else will write a CR on RHR Pump A.
4.22 Placed control switch for RHR-MO-34A, SUPPR POOL
- 15. Throttle OPEN COOLING INBD THROTTLE VLV, RHR-MO-34A . to OPEN to obtain desired flow on RHR-FI-133A or RHR-FR-143.
- 16. Ensure RHR-MO-16A 4.23 Ensured RHR-MO-16A, LOOP A CLOSES. MIN Flow BYP VLV, CLOSES as flow increases >2500 gpm.
NOTE to Examiners: Candidate may perform ONE of following steps.
4.24.1Directed the Reactor Building NLO to CLOSE CM-296, LOOP A INJECTION LINE PRESSURE
- 17. CLOSE CM-296.
MAINTENANCE SHUTOFF.
- CUE: The Station Operator reports CM-296 is CLOSED.
Nebraska Public Power District SKL034-20-24(34969)
Cooper Nuclear Station Page 6 of 8 Job Performance Measure for Operations Revision 09 Task No.: 219001O0101 Task
Title:
Startup the Suppression Pool Cooling Mode of RHR (Alternate Path)
Performance Checklist Standards Sat Unsat
- 18. Maintain system 4.24.2Maintained RHR Subsystem A pressure >
pressure > Condensate Transfer Condensate Transfer System pressure.
System pressure .
4.25 Held in the CLOSE position the
4.26 If PCIS Group 6 lights lit on Panel
- 20. Open cooling water 9-5, at VBD-M ensure REC-MO-711 valve to room cooler OR REC-MO-714, CRITICAL LOOP and pump. SUPPLY (associated with in service REC HX) open.
Informed CRS RHR Loop A is in Suppression Pool Cooling with maximum
- 21. Inform the CRS that cooldown rate established.
the task is Complete.
- CUE: The CRS acknowledges the report.
Stop Time __________ Total Time __________
Nebraska Public Power District SKL034-20-24(34969)
Cooper Nuclear Station Page 7 of 8 Job Performance Measure for Operations Revision 09 Task No.: 219001O0101 Task
Title:
Startup the Suppression Pool Cooling Mode of RHR (Alternate Path)
ATTACHMENT 1 SIMULATOR SET-UP A. Materials Required None B. Initialize the Simulator in any IC with Torus Temperature below 95°F. (IC-234)
Batch File Name - none.
C. Change the simulator conditions as follows:
- 1. Triggers None
- 2. Malfunctions RH01A, RHR Pump A Trip None
- 3. Remotes None
- 4. Overrides None
- 5. Panel Setup
- a. Initialize the Simulator and place in FREEZE.
- b. Insert IMF RH01A.
- c. Place Simulator in RUN.
Note: If this JPM is to be performed more than once, snap the simulator into an IC after the panel is complete.
Nebraska Public Power District SKL034-20-24(34969)
Cooper Nuclear Station Page 8 of 8 Job Performance Measure for Operations Revision 09 ATTACHMENT 2 Directions to Trainee:
When I tell you to begin, you are to startup the suppression pool cooling mode of RHR.
Before you start, I will state the general plant conditions, the Initiating Cues and answer any questions you may have.
When simulating, physically point to any meters, gauges, recorders and controls you would be using. State the position of controls as you would have manipulated them to startup the suppression pool cooling mode of RHR. During performance, state the actions you are taking, e.g.: repositioning controls and observing instrumentation.
General Conditions:
- 2. The RHRSW system is in standby status per procedure 2.2.70.
- 4. Suppression Pool cooling is NOT required by the EOPs.
- 5. All procedure prerequisites have been met for placing RHR Loop A in suppression pool cooling.
- 6. The NLO has completed venting loop A (2.2.69.3 through Step 4.13).
- 7. ALARA has determined the suction drain flush is not required.
- 8. The RPs have been notified of the system start.
- 9. Another operator is to perform 2.2.69.3 Section 3.
Initiating Cues:
The Control Room Supervisor directs you to startup RHR Loop A in suppression pool cooling and establish maximum cooldown rate using RHR Pump A per procedure 2.2.69.3. The hard card is NOT to be used. Inform the CRS when RHR Loop A is in suppression Pool Cooling at maximum cooldown rate.
Any plant announcements will be simulated.
Nebraska Public Power District SKL034-21-44(6354)
Cooper Nuclear Station Page 1 of 9 Job Performance Measure for Operations Revision 02 Task No.: 208028P0101
Title:
Separation of REC Critical Loops Trainee: Examiner:
Pass Fail Examiner Signature: Date:
Additional Program Information:
- 1. Appropriate Performance Locations: CR / SIM
- 3. Evaluation Method: Simulate Perform
- 4. Performance Time: 5 minutes
- 5. K/A 295018; AA1.03 (3.3/3.4), AK3.07 (3.1/3.2)
Directions to Examiner:
- 2. If this JPM is performed on the Simulator, only the cues preceded by "#" should be given.
- 3. Observe the trainee during performance of the JPM for proper use of self-checking methods.
- 4. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes section below.
- 5. Give the trainee Attachment 2.
- 6. Brief the trainee, place the simulator in run, and tell the trainee to begin.
Notes: ______________________________________________________________________
Nebraska Public Power District SKL034-21-44(6354)
Cooper Nuclear Station Page 2 of 9 Job Performance Measure for Operations Revision 02 Task No.: 208028P0101
Title:
Separation of REC Critical Loops Directions to Trainee:
When I tell you to begin, you are to separate the REC Critical Loops. Before you start, I will state the general plant conditions, the Initiating Cues and answer any questions you may have.
When simulating, physically point to any meters, gauges, recorders, and controls you would be using. State the position of controls as you would have manipulated them in order to complete the assigned task.
During task performance, state the actions you are taking, e.g.: repositioning controls and observing instrumentation.
General Conditions:
- 1. A large leak has developed in the REC system.
- 2. Emergency Procedure 5.2REC, Loss of REC, has been entered and actions taken up to separating the REC Critical Loops.
General
References:
- 1. Procedure 5.2REC
- 2. Procedure 2.2.65.1 General Tools and Equipment:
- 1. None Special Conditions, References, Tools, Equipment:
- 1. Simulator Setup: See Attachment 1.
- 2. Critical checks denoted in bold.
- 3. Simulator cues denoted by "#".
Task Standards:
- 1. Separates the REC critical loops per Procedure 5.2REC.
- 2. 100% of critical elements successfully completed without error.
- 3. 100% of safety and radiological work practices.
Nebraska Public Power District SKL034-21-44(6354)
Cooper Nuclear Station Page 3 of 9 Job Performance Measure for Operations Revision 02 Task No.: 208028P0101
Title:
Separation of REC Critical Loops Initiating Cue(s):
The Control Room Supervisor directs you to separate the REC Critical Loops per 5.2REC, using the NORTH Critical Loop. RMP-RM-351A, SW A EFFLUENT RAD MON, is operable.
Inform the CRS when you have separated the REC Critical Loops.
NOTE: Ensure the Simulator is in RUN and tell the trainee to begin. (Delete malfunction SW12B)
Nebraska Public Power District SKL034-21-44(6354)
Cooper Nuclear Station Page 4 of 9 Job Performance Measure for Operations Revision 02 Task No.: 208028P0101
Title:
Separation of REC Critical Loops Start Time: ____________
Performance Checklist Standards Sat Unsat 1.1 Closed REC-MO-695, CRITICAL LOOP SUPPLY CROSSTIE.
- 1. Close REC-MO-695.
CUE: GREEN light ON, RED light OFF.
1.2 Closed REC-MO-694, CRITICAL LOOP SUPPLY CROSSTIE.
- 2. Close REC-MO-694.
CUE: GREEN light ON, RED light OFF.
1.3 Closed REC-MO-721, NON CRITICAL HEADER RETURN.
- 3. Close REC-MO-721.
CUE: GREEN light ON, RED light OFF.
1.4 Closed REC-MO-722, NON CRITICAL
- 4. Close REC-MO- HEADER RETURN.
722.
CUE: GREEN light ON, RED light OFF.
NOTE to Examiner: Allow the examinee to contact the building operator to perform the following four steps. The booth operator will read the CUEs to the examinee.
1.5 Directed NLO to ensure REC-19 is open.
REC HX B INLET (R-931-N REC Hx area).
- 5. Ensure REC-19 is open.
- CUE: As the NLO report REC-19 is open.
1.6 Directed NLO to ensure REC-21 is open.
REC HX A INLET (R-931-N REC Hx area).
- 6. Ensure REC-21 is open.
- CUE: As the NLO report REC-21 is open.
NOTE to Examiner: Booth operator must insert TRIGGER 2 to close the valves in next two steps.
1.7 Directed NLO to Close REC-18, REC HX A
- 7. Remove seal and INLET (R-931-N REC Hx area).
close REC-18.
- CUE: As NLO, report REC-18 is closed.
Nebraska Public Power District SKL034-21-44(6354)
Cooper Nuclear Station Page 5 of 9 Job Performance Measure for Operations Revision 02 Task No.: 208028P0101
Title:
Separation of REC Critical Loops Performance Checklist Standards Sat Unsat 1.8 Directed NLO to Close REC-20, REC HX B
- 8. Remove seal and INLET (R-931-N REC Hx area).
close REC-20.
- CUE: As NLO, report REC-20 is closed.
- 9. Select a critical 1.9 Selects a critical subsystem to align. (North is subsystem. assumed).
1.10.1 Ensured REC-TCV-451A, REC HX A SW
- 10. Ensure REC-TCV- OUTLET TEMPERATURE CONTROL, 451A switch is in switch is in OPEN.
open.
CUE: Point to switch indicating it is pointing to OPEN.
1.10.2 Throttled open SW-MO-650 to obtain 400 to 1200 gpm flow on SW-FI-387A, REC HX A SW OUTLET.
- 11. Throttle open SW-MO-650.
CUE: Point indicating SW-FI-387A indicates 600 gpm.
1.10.3 Ensured REC-MO-712, HX A OUTLET
- 12. Ensure REC-MO- VLV, is closed.
712 is closed.
CUE: GREEN light On, RED light OFF.
1.10.4 Ensured REC-MO-711, NORTH CRITICAL LOOP SUPPLY is open.
- 13. Ensure REC-MO-711 is open. CUE: GREEN light OFF. RED light ON.
CUE: If asked as the NLO report no visible leaks exist on the system.
1.10.5 If REC Surge Tank is available, opened REC-MO-722.
- 14. Open REC-MO-722. CUE: IF student chooses to open REC-MO-722, the red light is ON and green light is OFF.
Nebraska Public Power District SKL034-21-44(6354)
Cooper Nuclear Station Page 6 of 9 Job Performance Measure for Operations Revision 02 Task No.: 208028P0101
Title:
Separation of REC Critical Loops Performance Checklist Standards Sat Unsat 1.10.6 Started REC PUMP:
______ C
______D CUE: REC PUMP C (D) red light came ON.
Inform the CRS the REC Critical loops are
- 16. Inform CRS the task separated.
is complete.
- CUE: CRS acknowledges the report.
Stop Time: __________ Total Time: ___________
Nebraska Public Power District SKL034-21-44(6354)
Cooper Nuclear Station Page 7 of 9 Job Performance Measure for Operations Revision 02 Task No.: 208028P0101
Title:
Separation of REC Critical Loops ATTACHMENT 1 SIMULATOR SET-UP A. Materials Required None B. Initialize the Simulator in IC Any power IC. (IC-235)
DO NOT LOAD BATCH FILE UNTIL DIRECTED BY SETUP!!
C. Run Batch File Jpm/342144 D. Change the simulator conditions as follows:
- 1. Triggers Number File Name Description None
- 2. Malfunctions Number Title Trigger TD Severity Ramp Initial SW12B REC HX 1B Tube Leak A N/A 60% N/A N/A Rp05 Group 2 isolation failure A N/A N/A N/A N/A RP14 CREFS Auto Initiation failure A N/A N/A N/A N/A RP15 Group 6 isolation failure A N/A N/A N/A N/A
- 3. Remotes Number Title Trigger TD Value Ramp SW02 REC HX1B Inlet Isol Vlv (REC-V-18) 2 N/A CLOSE N/A SW04 REC HXA Inlet Isol Vlv (REC-V-20) 2 N/A CLOSE N/A RR03 RRMG A DC Oil Pump STOP N/A RR04 RRMG B DC Oil Pump STOP N/A
- 4. Overrides Instrument Tag Trigger TD Value Ramp None
Nebraska Public Power District SKL034-21-44(6354)
Cooper Nuclear Station Page 8 of 9 Job Performance Measure for Operations Revision 02 Task No.: 208028P0101
Title:
Separation of REC Critical Loops
- a. Place the Simulator in RUN.
- b. Insert batch file (JPM/342144).
- c. Run the simulator long enough for the surge tank level to drop.
- d. Perform actions of EP 5.2REC up to the point of splitting the REC Critical Loops (all REC pumps off). These actions include scramming the reactor, tripping the RR pumps, stopping the RRMG
- 5. Panel Setup oil pumps, and stopping the running CRD pump.
- e. DELETE SW11c and SW11d, REC pump C and D trips.
- f. FREEZE the simulator.
- g. When JPM begins and simulator is taken to RUN, DELETE the malfunction SW12b.
Note: If this JPM is to be performed more than once, take a SNAPSHOT after the panel setup is complete.
Nebraska Public Power District SKL034-21-44(6354)
Cooper Nuclear Station Page 9 of 9 Job Performance Measure for Operations Revision 02 ATTACHMENT 2 Directions to Trainee:
When I tell you to begin, you are to separate the REC Critical Loops. Before you start, I will state the general plant conditions, the Initiating Cues and answer any questions you may have.
When simulating, physically point to any meters, gauges, recorders, and controls you would be using. State the position of controls as you would have manipulated them in order to complete the assigned task.
During task performance, state the actions you are taking, e.g.: repositioning controls and observing instrumentation.
General Conditions:
- 1. A large leak has developed in the REC system.
- 2. Emergency Procedure 5.2REC, Loss of REC, has been entered and actions taken up to separating the REC Critical Loops.
Initiating Cue(s):
The Control Room Supervisor directs you to separate the REC Critical Loops per 5.2REC, using the NORTH Critical Loop. RMP-RM-351A, SW A EFFLUENT RAD MON, is operable.
Inform the CRS when you have separated the REC Critical Loops.
Nebraska Public Power District SKL034-10-94 (7415)
Cooper Nuclear Station Page 1 of 5 Job Performance Measure for Operations Revision 02 Task No.: 286005I0102 Task
Title:
Operate the Diesel Fire Pump Manually (Alternate Path)
Trainee: Examiner:
Pass Fail Examiner Signature: Date:
THIS IS AN ALTERNATE PATH JPM Additional Program Information:
- 1. Appropriate Performance Locations: Plant
- 3. Evaluation Method: Simulate Perform
- 4. Performance Time: 12 minutes
- 5. NRC K/A 286000 A4.06(3.4/3.4)
Directions to Examiner:
THIS IS AN ALTERNATE PATH JPM. The First Method Of Starting The Diesel Will Be Unsuccessful.
- 1. This JPM evaluates the trainee's ability operate the diesel fire pump manually.
- 2. Observe the trainee during performance of the JPM for proper use of self-checking methods.
- 3. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes/comments section below.
- 4. Brief the trainee, place the simulator in run, and tell the trainee to begin.
Notes/Comments:
Nebraska Public Power District SKL034-10-94 (7415)
Cooper Nuclear Station Page 2 of 5 Job Performance Measure for Operations Revision 02 Task No.: 286005I0102 Task
Title:
Operate the Diesel Fire Pump Manually (Alternate Path)
Directions to Trainee:
When I tell you to begin, you are to operate the diesel fire pump manually. Before you start, I will state the general plant conditions, the Initiating Cues and answer any questions you may have.
When simulating, physically point to any meters, gauges, recorders and controls you would be using. State the position of controls as you would have manipulated them in order to complete the assigned task.
General Conditions:
- 1. The plant has experienced a fire.
- 2. The "C" fire pump is out of service.
- 3. The electric fire pump is unable to maintain system pressure.
- 4. The Diesel Fire Pump has failed to auto start.
General
References:
- 1. Procedure 2.2.30 General Tools and Equipment:
- 1. Master key for building access Special Conditions, References, Tools, Equipment:
- 1. Critical checks denoted by bold text.
- 2. Alternate path denoted by.
Task Standards:
- 1. The operator attempts to start the diesel fire pump normally but must start it by selecting emergency run and closing contactor A per Procedure 2.2.30.
- 2. 100% of critical elements successfully completed without error.
- 3. 100% of safety and radiological work practices.
Initiating Cue(s):
The Control Room Supervisor directs you to start the diesel fire pump at FP-PNL-F2 in the diesel fire house AND check engine parameters per procedure 2.2.30. Notify the CRS when the task is complete.
Nebraska Public Power District SKL034-10-94 (7415)
Cooper Nuclear Station Page 3 of 5 Job Performance Measure for Operations Revision 02 Task No.: 286005I0102 Task
Title:
Operate the Diesel Fire Pump Manually (Alternate Path)
Performance Checklist Standards Sat UNSAT
- 1. Check the engine oil level. 9.1 Checked the engine oil level is normal.
CUE: Engine oil level is at normal.
- 2. Check the engine cooling reservoir 9.2 Checked the engine cooling water reservoir is full.
NOTE: The reservoir is above the control panel. CUE: The water level is at the top of the reservoir.
- 3. Start Exhaust Fan 9.3 If room exhaust fans are not running (above small damper in Fire Pump D Room ceiling),
adjust Fire Pump D Room thermostat (west wall) to start fans.
CUE: Exhaust Fan is running.
- 5. Select Switch to 9.4.2.1 Placed selector switch to MANUAL 1 or Manual 1 MANUAL 2.
CUE: Use pen and point to MAN 1.
- 6. Press START button 9.4.2.2 Pressed START button.
CUE: Engine cranking is sluggish and noise in room remains low.
- 7. Select Switch to a. Placed selector switch to MANUAL 2 and Manual 2 and press pressed START button.
START button CUE: Use pen and point to MAN 2 CUE: Engine cranking is sluggish and noise in room remains low.
- 7. Select Emergency Run 9.5.1 Rotated Governor Manual Lever counter-clockwise to EMERGENCY RUN (located on top of engine).
CUE: Manual level fully CCW and Lever pointing to EMERGENCY RUN.
Nebraska Public Power District SKL034-10-94 (7415)
Cooper Nuclear Station Page 4 of 5 Job Performance Measure for Operations Revision 02 Task No.: 286005I0102 Task
Title:
Operate the Diesel Fire Pump Manually (Alternate Path)
- 8. Close CONTACTOR A 9.5.2 Pulled operating lever on either CONTACTOR A or CONTACTOR B (located on north side of engine below block heater) to start engine.
CUE: Sound of engine cranking briskly.
CUE: Sound of engine running.
CUE: Hand wheel rotates fully counter-clockwise until aligned with pipe.
CUE: Hand wheel rotates fully counter-clockwise until aligned with pipe.
- 11. Check flapper FP-FG-10. 9.5.3.3 Ensured flow flapper in FP-FG-10 (North side above diesel) is in horizontal position.
CUE: Use pen to indicate flapper is in horizontal position.
- 12. Check Engine 9.6.1 Check: Circulation water temperature, Parameters. Lube Oil Pressure, Engine RPM.
CUE: With pen point at temperature gauge to indicate 180°F.
CUE: With a pen point at oil pressure gauge to indicate 45 psig.
CUE: With a pen point at tachometer to indicate 1800 RPM.
- 13. Contacts the Control The operator calls the Control Room and reports Room Operator. Diesel Fire Pump D: is running normal CUE: Respond as Control Room Operator.
Nebraska Public Power District SKL034-10-94 (7415)
Cooper Nuclear Station Page 5 of 5 Job Performance Measure for Operations Revision 02 Task No.: 286005I0102 ATTACHMENT 1 When I tell you to begin, you are to operate the diesel fire pump manually. Before you start, I will state the general plant conditions, the Initiating Cues and answer any questions you may have.
When simulating, physically point to any meters, gauges, recorders and controls you would be using. State the position of controls as you would have manipulated them in order to complete the assigned task.
General Conditions:
- 1. The plant has experienced a fire.
- 2. The "C" fire pump is out of service.
- 3. The electric fire pump is unable to maintain system pressure.
- 4. The Diesel Fire Pump has failed to auto start.
- 5. The Diesel Fire Pump cannot be started at panel FA.
Initiating Cues:
The Control Room Supervisor directs you to start the diesel fire pump at FP-PNL-F2 in the diesel fire house AND check engine parameters per procedure 2.2.30. Notify the CRS when the task is complete.
Nebraska Public Power District SKL034-40-14 Cooper Nuclear Station Page 1 of 7 Job Performance Measure for Operations Revision: 2 Task No.: 263030P0104 PLACE 24 VDC BATTERIES AND ASSOCIATED CHARGERS IN SERVICE Trainee: Examiner:
Pass: Fail: Examiner Signature: Date:
Additional Program Information:
- 1. Appropriate Performance Locations: Plant
- 3. Evaluation Method: Perform Simulate
- 4. Performance Time: 15 minutes
- 5. Importance Factor: 2.75
- 6. NRC K/A: 263000 SG9(3.4/3.5)
Directions to Examiner:
- 1. This JPM evaluates the trainee's ability to place 24 VDC batteries and associated chargers in service in accordance with Procedure 2.2.26, 24 VDC Electrical System.
- 2. If this JPM is performed on the Simulator, only the cues preceded by "#" should be given.
- 3. Observe the trainee during performance of the JPM for proper use of self-checking methods.
- 4. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes/comments section below.
- 5. Brief the trainee, place the simulator in run, and tell the trainee to begin.
Notes/Comments: ____________________________________________________________
Nebraska Public Power District SKL034-40-14 Cooper Nuclear Station Page 2 of 7 Job Performance Measure for Operations Revision: 2 Task No.: 263030P0104 PLACE 24 VDC BATTERIES AND ASSOCIATED CHARGERS IN SERVICE Directions to Trainee:
When I tell you to begin, you are to place 24 VDC batteries and associated chargers in service in accordance with Procedure 2.2.26, 24 VDC Electrical System. Before you start, I will state the general plant conditions, the initiating cues and answer any questions you may have.
During task performance, state the actions you are taking, e.g.: repositioning controls and observing instrumentation.
If being simulated in the Control Room:
When simulating, physically point to any meters, gauges, recorders and controls you would be using. State the position of controls as you would have manipulated them in order to complete the assigned task.
General Conditions:
- 1. A refuel outage is in progress.
- 2. 1A1 and 1A2 24 VDC batteries have been replaced.
General
References:
- 1. Procedure 2.2.26, 24 VDC Electrical System General Tools and Equipment:
- 1. None Special Conditions, References, Tools, Equipment:
- 1. Critical checks denoted by bold steps.
- 2. Simulator cues denoted by "#".
Task Standards:
- 1. Accurately locate, identify, operate and/or manipulate all component controls required to be utilized to place 24 VDC batteries and associated chargers in service per Procedure 2.2.26.
- 2. 100% of critical elements successfully completed without error.
- 3. 100% of safety and radiological work practices.
Nebraska Public Power District SKL034-40-14 Cooper Nuclear Station Page 3 of 7 Job Performance Measure for Operations Revision: 2 Task No.: 263030P0104 PLACE 24 VDC BATTERIES AND ASSOCIATED CHARGERS IN SERVICE Initiating Cue(s):
The BOP operator has directed you to return the 1A1 and 1A2 battery chargers and associated 24 VDC batteries to service in accordance with Procedure 2.2.26, 24 VDC Electrical System. .
All prerequisites have been completed or verified.
Notify the Control Room Supervisor when the 1A1 and 1A2 battery chargers and 24 VDC batteries have been returned to service.
NOTE: Tell the trainee to begin.
Nebraska Public Power District SKL034-40-14 Cooper Nuclear Station Page 4 of 7 Job Performance Measure for Operations Revision: 2 Task No.: 263030P0104 PLACE 24 VDC BATTERIES AND ASSOCIATED CHARGERS IN SERVICE Start Time: _________________
Performance Checklist Standards Sat Unsat
- 1. Obtain the procedure The operator obtained 2.2.26 at section 6, Placing 24V Batteries 1A1 and 1A2 in service.
- 2. Verify the 24 VDC 6.1 Verified the batteries 1A1 and 1A2 free Batteries 1A1 and 1A2 of foreign materials.
are free of foreign materials. CUE: No foreign materials present.
- 3. CLOSE the 24 VDC 6.2 CLOSED the 24 VDC BATTERY A1/A2 BATTERY A1/A2 DISCONNECT switch.
DISCONNECT switch.
CUE: DISCONNECT switch is up.
- 4. Verify OPEN the AC 8.2/3 Verified OPEN the AC INPUT INPUT BREAKERS on BREAKERS on 24 VDC CHARGERS 24 VDC CHARGERS 1A1 and 1A2.
1A1 AND 1A2.
CUE: The breaker handles are down.
- 5. Verify OPEN the DC 8.4/5 Verified OPEN the DC OUTPUT OUTPUT DISCONNECTS on 24 VDC DISCONNECT on 24 CHARGER 1A1 and 1A2.
VDC CHARGERS 1A1 and 1A2. CUE: The breaker handles are down.
- 6. Verify EQUALIZING 8.6/7 Verified the EQUALIZING timers on 24 timer on 24 VDC VDC CHARGERS 1A1 and 1A2 was CHARGERS 1A1 and set at zero.
1A2 set at zero CUE: Using a pen, indicate the timers are at zero (full CCW).
- 7. CLOSE the DC 8.8/9 CLOSED the DC OUTPUT OUTPUT BREAKERS BREAKERS on 24 VDC CHARGER on 24 VDC CHARGER 1A1 and 1A2.
1A1 and 1A2 CUE: The breaker handles are up.
- 8. Verify CLOSED Bkr 5 8.10 Verified CLOSED Bkr 5 on CDP-1A.
on CDP-1A, Feeder to 24 VDC Battery CUE: The breaker handle is pointing to ON.
Chargers 1A1 and 1A2
- 9. CLOSE the AC INPUT 8.11 CLOSED the AC INPUT BREAKERS BREAKERS on 24 on 24 VDC CHARGER 1A1 and 1A2.
VDC CHARGER 1A1 and 1A2 CUE: The breaker handles are up.
Nebraska Public Power District SKL034-40-14 Cooper Nuclear Station Page 5 of 7 Job Performance Measure for Operations Revision: 2 Task No.: 263030P0104 PLACE 24 VDC BATTERIES AND ASSOCIATED CHARGERS IN SERVICE Performance Checklist Standards Sat Unsat
- 10. Verify the GREEN AC 8.11.1.1 Verified the AC ON INDICATING ON INDICATING LIGHT LIGHTS were illuminated.
on 24 VDC CHARGER 1A1 and 1A2 is CUE: The GREEN lights are illuminated.
illuminated
- 11. Verify that the 8.11.1.2 Verified the voltmeters to be voltmeters on 24 VDC reading ~26.5 VDC.
CHARGER 1A1 and 1A2 are reading ~26.5 CUE: With a pen and the respective VDC. Voltmeters, point to ~ 27 VDC.
- 12. Verify amps 8.11.1.3 Verified Ammeter on Charger 1A1 reading < 27.5 amps.
CUE: With a pen and the respective Ammeter point to 22 amps.
- 12. Verify annunciators. 8.11.1.4 Verified with the Control Room that Annunciators C-2/A-7 and C-2/B-7 are clear.
CUE: The annunciators are clear.
- 13. Test GROUND 10.1.1 Placed GND. DETECTION toggle DETECTION indicating switch on 24V Charger 1A1 to LAMP lights TEST and checked that the red GND DET indicating lights turned on.
CUE: The Red GND DET indicating lights turn on.
- 14. Test for grounds on 24 10.1.2 Placed GND. DETECTION toggle VDC CHARGER 1A1 switch on 24V Charger 1A1 to GND.
DET and checked left red GND DET indicating light turned on and right red GND DET indicating light remained off.
CUE: Left light ON, right light OFF.
- 15. Test GROUND 10.2.1 Placed GND. DETECTION toggle DETECTION indicating switch on 24V Charger 1A2 to LAMP lights TEST and checked red GND DET indicating lights turned on.
CUE: The Red GND DET indicating lights turn on.
Nebraska Public Power District SKL034-40-14 Cooper Nuclear Station Page 6 of 7 Job Performance Measure for Operations Revision: 2 Task No.: 263030P0104 PLACE 24 VDC BATTERIES AND ASSOCIATED CHARGERS IN SERVICE Performance Checklist Standards Sat Unsat
- 16. Test for grounds on 24 10.2.2 Placed GND. DETECTION toggle VDC CHARGER 1A2 switch on 24V Charger 1A2 to GND.
DET and checked right red GND DET indicating light turned on and left red GND DET indicating light remained off.
CUE: Right light ON, left light OFF.
NOTE to Examiner: Next step is performed in Cable Spreading Room (one floor up).
- 17. Verify voltage 8.15 Verified voltages on Panel DC-A to be ~
indications on 24 VDC 26.5 VDC Power Panel DC-A to be
~26.5 VDC CUE: With a pen and the respective Voltmeter, point to ~ 26.7 VDC.
- 18. Notify the CRS that task The operator contacted the CRS and is completed. informed him that 1A1 and 1A2 24 VDC Battery Chargers and Batteries have been returned to service.
CUE: The BOP operator acknowledges the report.
Stop Time: _________________ Total Time: _________________
Nebraska Public Power District SKL034-40-14 Cooper Nuclear Station Page 7 of 7 Job Performance Measure for Operations Revision: 2 Task No.: 263030P0104 ATTACHMENT 1 Directions to Trainee:
When I tell you to begin, you are to place 24 VDC batteries and associated chargers in service in accordance with Procedure 2.2.26, 24 VDC Electrical System. Before you start, I will state the general plant conditions, the initiating cues and answer any questions you may have.
During task performance, state the actions you are taking, e.g.: repositioning controls and observing instrumentation.
If being simulated in the Control Room:
When simulating, physically point to any meters, gauges, recorders and controls you would be using. State the position of controls as you would have manipulated them in order to complete the assigned task.
General Conditions:
- 1. A refuel outage is in progress.
- 2. 1A1 and 1A2 24 VDC batteries have been replaced.
Initiating Cue(s):
The BOP operator has directed you to return the 1A1 and 1A2 battery chargers and associated 24 VDC batteries to service in accordance with Procedure 2.2.26, 24 VDC Electrical System. .
All prerequisites have been completed or verified.
Notify the Control Room Supervisor when the 1A1 and 1A2 battery chargers and 24 VDC batteries have been returned to service.
Nebraska Public Power District SKL034-10-65(xxxxxxx)
Cooper Nuclear Station Page 1 of 7 Job Performance Measure for Operations Revision 01 Task No.: 200076A0504
Title:
Conduct Alternate Rod Insertion (Vent Scram Air Header)
Trainee: Examiner:
Pass Fail Examiner Signature: Date:
Additional Program Information:
- 1. Appropriate Performance Locations: PLANT
- 3. Evaluation Method: Simulate
- 4. Performance Time: 15 minutes
- 5. NRC K/A 2.1.30 (3.9/3.4); 295037 EA1.05 (3.9/4.0)
Directions to Examiner:
- 1. The candidate causes all the control rods to insert from outside the control room by depressurizing the scram air header.
- 2. Observe the trainee during performance of the JPM for proper use of self-checking methods.
- 3. Check off either satisfactory or unsatisfactory performance. If Unsat state why in the notes section below.
- 4. Give the trainee Attachment 1.
- 5. Brief the trainee, and tell the trainee to begin.
Notes: ______________________________________________________________________
Nebraska Public Power District SKL034-10-65(xxxxxxx)
Cooper Nuclear Station Page 2 of 7 Job Performance Measure for Operations Revision 01 Task No.: 200076A0504
Title:
Conduct Alternate Rod Insertion (Vent Scram Air Header)
Directions to Trainee:
When I tell you to begin, you are to conduct alternate rod insertion by venting the scram air header. Before you start, I will state the general plant conditions, the Initiating Cues, and answer any questions you may have.
When simulating, physically point to any meters, gauges, recorders and controls you would be using. State the position of controls as you would have manipulated them in order to complete the assigned task.
During task performance, state the actions you are taking, e.g.: repositioning controls and observing instrumentation.
General Conditions:
- 1. A failure of RPS and ARI to insert the control rods has occurred.
- 2. The Control Room operator has placed all keylock RPS test trip switches to TRIP.
- 4. The TSC is not yet operational.
- 5. No ARMs are alarming.
- 6. The In-Containment Rad Monitors are reading 100 REM/HR.
General
References:
- 1. Emergency Operating Procedure 5.8.3 General Tools and Equipment:
- 1. Crescent wrench (attached by wire lanyard at IA-1601).
Special Conditions, References, Tools, Equipment:
- 1. Critical checks denoted in bold.
Task Standards:
- 1. The candidate isolates the air supply to the scram air header, removes a pipe plug with a wrench and then opens a manual valve which depressurizes the scram air header.
- 2. 100% of critical elements successfully completed without error.
- 3. 100% of safety and radiological work practices.
Nebraska Public Power District SKL034-10-65(xxxxxxx)
Cooper Nuclear Station Page 3 of 7 Job Performance Measure for Operations Revision 01 Task No.: 200076A0504
Title:
Conduct Alternate Rod Insertion (Vent Scram Air Header)
Initiating Cue(s):
You have been assigned to conduct alternate rod insertion per Emergency Operating Procedure 5.8.3. The Control Room Supervisor directs you to manually vent the scram air header and to restore the scram air header when specifically directed to do so. Notify the CRS when the task is complete.
NOTE: Tell the trainee to begin.
Nebraska Public Power District SKL034-10-65(xxxxxxx)
Cooper Nuclear Station Page 4 of 7 Job Performance Measure for Operations Revision 01 Task No.: 200076A0504
Title:
Conduct Alternate Rod Insertion (Vent Scram Air Header)
Start Time: ____________
Performance Checklist Standards Sat Unsat Closed IA-985, SCRAM DISCHARGE VOLUME and SCRAM PILOT AIR SUPPLY ROOT (R-903-
- 1. Close IA-985 SE).
CUE: The handwheel is fully clockwise and the valve stem is down.
Ensured IA-244 open.
- 2. Ensure IA-244 open CUE: The handwheel is fully counter clockwise.
Removed 3/4" swagelok female connector with 1/4" plug from IA-1601, PI-229 and PS-230 DRAIN line, utilizing the wrench attached by lanyard to IA-1601.
- 3. Remove 3/4 CUE: The 3/4" swagelok female connector with swagelock 1/4" plug is turning.
connector CUE: The 3/4" swagelok female connector with 1/4" plug is removed.
Opened IA-1601, PI-229 and PS-230 DRAIN.
CUE: Valve handwheel is turning counter-clockwise. There is the sound of rushing
- 4. Open IA-1601 air.
CUE: The valve handwheel is fully counter clockwise.
Nebraska Public Power District SKL034-10-65(xxxxxxx)
Cooper Nuclear Station Page 5 of 7 Job Performance Measure for Operations Revision 01 Task No.: 200076A0504
Title:
Conduct Alternate Rod Insertion (Vent Scram Air Header)
Performance Checklist Standards Sat Unsat Notified Control Room venting is in progress.
CUE: When notified:
- 5. Inform Control
- Acknowledge venting is in progress and Room venting is in DIRECT operator to stay on the line.
progress.
- (After ~1 minute) report that all control rods are inserted and DIRECT restoration of the scram air header.
Closed IA-1601, PI-229 & PS-230 DRAIN.
- 6. Close IA-1601 CUE: The valve handwheel is fully clockwise.
Installed and tightened the 3/4" swagelok female connector with 1/4" plug on IA-1601, PI-229 & PS-230 DRAIN.
- 7. Install 3/4" swagelok female CUE: The 3/4" swagelok female connector with connector with 1/4" plug is in place and turning.
1/4" plug on IA-1601 CUE: The 3/4" swagelok female connector with 1/4" plug is tight.
Opened IA-985, CRD SCRAM DISCHARGE VOLUME & SCRAM PILOT AIR SUPPLY.
- 8. Open IA-985 CUE: The handwheel is fully counter clockwise and the valve stem is up
Nebraska Public Power District SKL034-10-65(xxxxxxx)
Cooper Nuclear Station Page 6 of 7 Job Performance Measure for Operations Revision 01 Task No.: 200076A0504
Title:
Conduct Alternate Rod Insertion (Vent Scram Air Header)
Performance Checklist Standards Sat Unsat Informed CRS the scram air header has been manually vented and the scram air header is
- 9. Inform CRS the task restored.
is complete CUE: The CRS acknowledges the report.
Stop Time: __________ Total Time: ___________
Nebraska Public Power District SKL034-10-65 (xxxxxxx)
Cooper Nuclear Station Page 7 of 7 Job Performance Measure for Operations Revision 01 ATTACHMENT 1 Directions to Trainee:
When I tell you to begin, you are to conduct alternate rod insertion by venting the scram air header. Before you start, I will state the general plant conditions, the Initiating Cues, and answer any questions you may have.
When simulating, physically point to any meters, gauges, recorders and controls you would be using. State the position of controls as you would have manipulated them in order to complete the assigned task.
During task performance, state the actions you are taking, e.g.: repositioning controls and observing instrumentation.
General Conditions:
- 1. A failure of RPS and ARI to insert the control rods has occurred.
- 2. The Control Room operator has placed all keylock RPS test trip switches to TRIP.
- 4. The TSC is not yet operational.
- 5. No ARMs are alarming.
- 6. The In-Containment Rad Monitors are reading 100 REM/HR.
Initiating Cue(s):
You have been assigned to conduct alternate rod insertion per Emergency Operating Procedure 5.8.3. The Control Room Supervisor directs you to manually vent the scram air header and to restore the scram air header when specifically directed to do so. Notify the CRS when the task is complete.
Note for Adams Package:
For scenario 2 only there is a final scenario file in the final approved Op test file and an as-given scenario 2 file which is in Adams as its own file. The other scenario ran was scenario 3 and scenario 1 was the spare for this exam.
Two crews (crew 1 and crew 3) failed to diagnose the dryer event properly and therefore created new critical tasks and different paths than expected by the licensee or NRC examiners during validation week and so the ES-D1 and ES-D2 forms are marked up accordingly (electronically) with two paths. Crew 2 took path one and crews 1 and 3 took path 2 with the new write-in critical tasks.
Appendix D Scenario Outline Form ES-D-1 Facility: Cooper Nuclear Station Scenario No.: 1 (Spare) Op-Test No.: ___1____
Examiners: ____________________________ Operators: _____________________________
Initial Conditions: Plant operating at 85% power (BCL).
Turnover: Continue startup to 100% power. .
Event Malf. Event Event No. No. Type* Description 1 N/A N (BOP Place Circulating Water Pump D in service (2.2.3) 2 N/A R (ATC) Raise Reactor Power using reactor recirculation (2.1.10) 3 RR17a I (ATC) RR Pump A runs back in speed on the power rise and must be locked out to halt to speed drop. (Abnormal Procedure 2.4RR).
Enters TS LCO 3.4.1 because pump speeds vary by more than TS (SRO 5%.
4 RC08 I (BOP) PCIS instrument causes RCIC-MO-16 to isolate.
TS LCO 3.5.3, Condition A.
5 ED19c C (BOP) 125V DC power panel AA-3 loses power. (Emergency Procedure 5.3DC125) 6 EG03 C (BOP) H2 Gas leak in Generator (Abnormal Procedure 2.4 Gen)
R (ATC) Reduce power using Recirculation Pump Flow (2.1.10) 7 N/A M (Crew) Unit SCRAM due to Generator hydrogen leak (EOP 1A, 6A,7A)
RP15 I (BOP) PCIS Group 6 failure. Required manual group isolation using radiation monitor switches out of operate.
8 RD15 C , (©) ATWS (6 rods) Manually insert control rods with RMCS (EOP (ATC) 5.8.3) 9 FW18b C , (©) FW Line B Break inside DW (transition to ECCS for RPV Level (ATC) Control) 2.4MC-RF and 2.4PC.
MS02b
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor, (T)echnical Specifications, (©) CT Page 1 of 26
Appendix D Scenario Outline Form ES-D-1 Initial Conditions: 85% power (BCL), D CWP out of service, Turnover:
The D CWP is returned to service, 2.2.3 completed to step 5.5, and backwash completed.
Raise power to 90% using reactor recirculation system.
==
Description:==
BOP Operator places the 4th Circulating Water Pump in service per procedure 2.2.3 Circulating Water System Operation.
The ATC raises reactor power using Reactor Recirculation flow at least 5% power using procedure 2.1.10, Station Power Changes. During the power rise, RR Pump A runs back in speed requiring the ATC to stop the speed reduction by locking out the pump's scoop tube.
Abnormal Procedure 2.4RR is entered. The CRS enters TS LCO 3.4.1, Condition B when RR pump speeds differ by more than 5%.
RCIC PCIS instrument failure causes RCIC-MO-16 steam supply valve to isolate. The instrument is repaired and the valve is reopened. RCIC is declared inoperable per TS 3.5.3.
The 125V DC Panel AA-3 loses power. Reactor Recirculation Pump A trips and the crew enters Procedures 2.4RR and 5.3DC125. Single loop operations are entered and effected loss of DC loads are shifted as needed.
The BOP operator responds to a H2 Gas leak on the main generator. Abnormal procedure 2.4GEN-H2 will be entered requiring the operator to remove the generator from service due to excessive leakage.
The ATC is directed to scram the reactor as hydrogen pressure lowers to 30 psig. When the reactor is SCRAMMED 6 control rods fail to fully insert (ATWS). The SRO enters EOPs 6A and 7A. The ATC manually inserts control rods per EOP 5.8.3 using the reactor manual control system. Post scram the PCIS Group 6 isolation fails to actuate requiring the BOP to manually insert the isolation signal per operating procedures.
A small Feedwater line break occurs inside the drywell requiring the BOP operator to utilize ECCS systems to maintain reactor water level, and both the ATC and BOP operators take actions to restore RPV water level and containment parameters. The drywell requires containment sprays to maintain pressure within acceptable limits.
The scenario ends when Drywell pressure is being controlled and Reactor Water Level is restored to the normal band and all control rods are inserted.
Page 2 of 26
Appendix D Scenario Outline Form ES-D-1 Critical Task List During failure to scram conditions, insert control rods using one or more Critical methods contained within Procedure 5.8.3 before addressing other tasks Task that detract from inserting control rods in an expeditious manner.
Basis:
Achieving reactor shutdown is one of the primary goals of EOP 6A.
Critical Event 11- (BOP) Initiate Drywell spray when torus pressure exceeds 10 Task psig and before Pressure Suppression Pressure (PSP) Graph is exceeded.
Basis:
Regarding drywell temperature, if operation of all available drywell cooling is unable to terminate increasing drywell temperature before the structural design temperature limit of 280°F is reached, drywell sprays are initiated to affect the required drywell temperature reduction status of the DSIL and adequate core cooling permitting. Spray operation effects a drywell pressure and temperature reduction through the combined effects of evaporative cooling and convective cooling.
Regarding drywell pressure, operation of drywell sprays reduces primary containment pressure by condensing any steam that may be present and by absorbing heat from the containment atmosphere through the combined effects of evaporative and convective cooling. Drywell sprays are initiated when torus pressure exceeds the Torus Spray Initiation Pressure (10# torus pressure) to preclude chugging the cyclic condensation of steam at the downcomer openings of the drywell vents. When a steam bubble collapses at the exit of the downcomers, the rush of water drawn into the downcomers to fill the void induces stresses at the junction of the downcomers and the vent header in Mark I containments and at the junction of the downcomers. Repeated application of such stresses could cause fatigue failure of these joints; thereby, creating a direct path between the drywell and torus. When drywell sprays are initiated, the resulting pressure reduction opens the vacuum breakers, drawing non-condensable from the torus back into the drywell.
This condition defines the Torus Spray Initiation Pressure. As the drywell atmosphere is purged to the torus and replaced by steam, torus pressure increases. The SCSIP is the lowest torus pressure which can occur when 95% of the non-condensable in the drywell have been transferred to the torus. Since the failure mode is based on fatigue failure, a precise time limit or pressure cannot be provided. Therefore, prompt initiation of drywell sprays is required based on existing EOP priorities.
Page 3 of 26
Appendix D Scenario Outline Form ES-D-1 Procedures used 2.2.3 Circulating Water System Operation (Normal) 2.1.10, Station Power Changes (Normal)
Annunciator 9-4-3/C-2 for scoop tube lockup (ARP) 2.4RR Abnormal for scoop tube lockup (AOP)
Annunciator 9-4-1/G-2, RCIC Steam line valve closure (ARP)
Annunciator 9-5-2/E-3 for loss of DC panel (ARP)
Annunciator 9-4-3/A-2 for loss of DC panel and RR pump trip (ARP) 5.3DC125 for DC 125 issues (EOP)
Annunciator B-2/B-4 for H2 leakage (ARP) 2.4GEN-H2 Abnormal for H2 leakage (AOP) 2.1.5 Scram (EOP)
EOP-1A EOP 6A EOP 7A 5.8.3 Alternate Rod Insertion (EOP) 2.4MC-RF, Condensate or Feedwater Abnormal (AOP) 2.4 PC (AOP)
EOP-3A Manually insert PCIS per procedure 2.1.22.
Page 4 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 1 Event
Description:
Place Circulating Water Pump D in service Time Position Applicants Action or Behavior Perform operator action of procedure 2.2.3, Circulating Water System, (Section 5.5) 5.5 Verifies pump has been backwashed per Section 9, (See turnover sheet).
5.6 Place and hold control switch for CIRC WATER PUMP to be started to START until pump starts and check following:
5.6.1 Discharge valve is opening and pump starts after valve has partially opened.
5.6.2 Pump motor current is < 218 amps.
BOP 5.6.3 Pump discharge pressure is within acceptable operating limits per Attachment 1.
5.7 Restore valves operated in Step 5.3.6 to full open.
5.8 Ensure 7 gpm bearing water flow being maintained as indicated on CW-FIS-351.
5.8.1 Annunciator A-4/C-3, CIRC WATER PUMP BRG WTR LOW FLOW, not alarming for pump started.
5.8.2 Verify sufficient gland water leakoff.
ROLE PLAY: If requested as NLO to check CWP D gland water leakoff and bearing water report flow is normal.
Booth If River level is requested report 880 MSL.
Operator If CW Pump D discharge pressure is requested report 4 psig.
BOP Informs CRS that D Circulating Water Pump is in service.
CRS Acknowledges D Circulating Water Pump in service.
END OF EVENT Page 5 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 1 Event
Description:
Place Circulating Water Pump D in service Time Position Applicants Action or Behavior Notes Proceed to the next event when CRS directs power rise.
Page 6 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 2 Event
Description:
Raise Reactor Power using Reactor Recirculation Time Position Applicants Action or Behavior CRS Directs the ATC to raise reactor power to 90% using procedure 2.1.10, Station Power Changes (Section 6)
NOTE to Examiners: RR pump speed is changed by turning small knob CW on RRFC-SIC16A and RRFC-SIC-16B controllers on Panel 9-4-3.
Raise reactor power using procedure 2.1.10, Station Power Changes (Section 6) 6.1 Step is N/A 6.2 Step is N/A 6.3 Step is N/A.
6.4 Raise power by raising RR pump flow as follows:
ATC 6.4.1 IF thermal power 2413 (or 2375 if power limited to 2381 MWt), THEN raise power by raising RR pump flow.
6.4.1.1 Maintain rate of power change consistent with system capabilities as determined by Load Dispatcher and TG limits.
6.4.2 Step is N/A.
NOTE to Lead Examiner: When power change is underway direct Booth Operator to commence with malfunction in next event.
END OF EVENT Proceed to the next event at direction of the lead examiner.
Notes Page 7 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 3 Event
Description:
RR Pump A controller causes RR Pump A to run down in speed.
Time Position Applicants Action or Behavior When directed by the Lead Examiner Insert Trigger 2 (RR 17a)
RR Pump A run back towards 55% speed.
Booth Operator (Note FW16b goes active on this trigger but it takes several minutes for hotwell level to lower appreciably for the next event.)
Recognize RR Pump A lowering in speed.
Respond to alarm 9-4-3/C-2, RRMG A SCOOP TUBE LOCKOUT.
CRS Enter Procedure 2.4RR, and assign actions to ATC.
Enter 2.4RR, Attachment 4 1.1 Operate scoop tube locally per Procedure 2.2.68.1; or 1.1.1 Trip affected RRMG; or ATC 1.1.2 Enter Procedure 2.1.5.
- 2. If RR pump tripped, THEN enter Attachment 1
- 3. Ensure requirements of SR 3.4.1.1 are met as soon as practical.
If greater than 5% speed mismatch, Enter LCO 3.4.1 CRS Condition B-Satisfy requirement of the LCO.
Completion Time 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
NOTE to Examiners: If RR pump speeds vary more than 5%, the CRS may direct RR B speed lowered to match RR Speed A.
If directed to adjust RR A flow locally, use Remote Function Booth Operator RR05.
END OF EVENT Proceed to the next event at direction of the lead examiner.
Page 8 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 3 Event
Description:
RR Pump A controller causes RR Pump A to run down in speed.
Time Position Applicants Action or Behavior Notes Page 9 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 4 Event
Description:
RCIC PCIS inadvertent isolation Time Position Applicants Action or Behavior Booth When directed by the Lead Examiner, Trigger 4, RC08 (Inadvertent Operator Group 5 isolation)
Respond to alarm BOP 9-4-1/G-2 RCIC-MO-15/16 NOT FULL OPEN Report RCIC-MO-16 has closed.
ATC Report Panel 9-5 PCIS lights out for PCIS Group 5.
Refer to TS LCO 3.5.3, Condition A CRS Verify HPCI operable in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.
Restore RCIC to operable status within 14 days.
ROLE PLAY: When contacted as Work Control, report you will put a team together to look into the RCIC isolation.
Booth Operator In 5 minutes call the CRS and report the RCIC steam line supply high flow instrument RCIC- DPIS 83 has failed.
Refer to TS 3.3.6.1 Function 4a for Steam line high flow instrument failure.
CRS Enter Condition A, place in trip condition within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
END OF EVENT Proceed to the next event at direction of the lead examiner.
Notes Page 10 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 5 Event
Description:
Loss of 125V DC Panel AA-3 Time Position Applicants Action or Behavior Booth ROLE PLAY: When directed by the Lead Examiner insert Trigger 3 (Loss of 125V DC AA-3).
Operator Respond to alarms 9-4-3/A-2, RRMG A BKR 1CN TRIP ATC 9-5-2/E-3, ARI & ATWS RPT LOGIC POWER FAILURE.
Determine loss of Panel AA-3.
Enter 2.4 RR,REACTOR RECIRCULAITON ABNORMAL, and 5.3DC125, LOSS OF 125 VDC.
CRS Assign 2.4RR actions to the ATC.
Assign 5.3DC125 actions to the BOP.
Per 2.4RR 1.1 Step is N/A.
1.2 For tripped RR pump, ensure RRMG Set A(B) GEN FIELD BKR open.
1.2.1 Step is N/A.
1.3 For tripped RR pump, close RR-MO-53A(B), PUMP DISCHARGE ATC VLV.
1.4 Continue with remaining steps in this attachment while waiting to open RR-MO-53A(B).
1.5 AFTER RR-MO-53A(B) has been closed for 5 minutes, THEN open valve.
Enter 2.2.68.1 single loop operations as directed by 2.4RR.
- 1. SINGLE LOOP OPERATION ATC NOTE - Core flow > 29.5x106 lbs/hr ensures backflow through inactive loop is maintained.
Page 11 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 5 Event
Description:
Loss of 125V DC Panel AA-3 Time Position Applicants Action or Behavior 1.1 Raise core flow to > 29.5x106 lbs/hr, if possible.
1.2 Ensure reactor power and core flow have stabilized outside Stability Exclusion Region.
1.2.1 IF reactor power and core flow are operating in Stability Exclusion Region, THEN enter Procedure 2.4RR immediately.
1.3 Steps are N/A.
1.4 Determine if reverse flow summer is functioning as follows:
1.4.1 IF Annunciator 9-4-3/E-3 (9-4-3/E-7), RECIRC LOOP A (B)
OUT OF SERVICE, is alarming, THEN summer is functioning properly.
1.4.2 IF indicated core flow is approximately equal to difference between NBI-FI-92A and NBI-FI-92B, JP LOOP FLOW, THEN summer is functioning properly.
1.5 Steps are N/A.
1.6 Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of entry into single loop operations, perform following in sequential order:
NOTE - Adjusting AGAFs for single loop operation before adjusting the APRM Downscale trip setpoints to 13.5% makes the APRM downscale trip function inoperable.
1.6.1 Ensure APRM Downscale trip setpoints have been adjusted to 13.5% per Procedure 6.APRM.306.
1.6.2 Notify SM to reset allowable limit for APRM Flow Biased scram setpoint (LCO 3.3.1.1 Table 3.3.1.1-1 Function 2b) to single loop operating limit per LCO 3.4.1.c.
1.6.3 Trigger a Periodic Case.
1.6.4 Adjust AGAFs per Procedure 10.1 for single loop operation.
1.6.5 Complete thermal limits checks attachment of Procedure Page 12 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 5 Event
Description:
Loss of 125V DC Panel AA-3 Time Position Applicants Action or Behavior 6.LOG.601.
CRS Enter TS LCO 3.4.1, Condition B for tripped RR pump.
Per 5.3DC125 1.1 Ensure RR Pump A drive motor breaker has tripped.
BOP 1.3 Secure SAC 1A 1.4 If CRD Pump A running direct building operator to trip 480V breaker.
If directed to trip SAC 1A, insert RF IA14 to STOP.
Booth If directed to open breaker for SAC 1A, insert RF IA07 to OPEN.
Operator If directed to start SAC 1B insert RF IA15 to START.
END OF EVENT Proceed to the next event at direction of the lead examiner.
Notes Page 13 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 6 Event
Description:
H2 Gas leak in Generator Time Position Applicants Action or Behavior Booth At the direction of the lead examiner, insert Trigger 1 (EG03)
Operator Generator Hydrogen leak.
Respond to annunciators:
Inform the CRS that Hydrogen Pressure in the Main Generator is lowering and entry into 2.4GEN-H2 is required.
Enters ABNORMAL PROCEDURE 2.4GEN-H2 GENERATOR OR HYDROGEN ABNORMAL 4.1 Record current time and date.
4.2 Concurrently refer to Attachment 4, ABNORMAL H2 GAS PRESSURE OR H2 LEAKAGE 4.3 Obtain Control Room Supervisor review/concurrence.
Perform Attachment 4 as follows:
- 1. Make announcement for personnel to stay clear of Turbine Building due to potential hydrogen leak.
- 2. IF H2 is leaking into Turbine Building, THEN direct a Non Licensed Operator to perform steps 2.1 through 2.3
3.1 IF Annunciator 9-5-2/C-4 is clear, THEN SCRAM and enter Procedure 2.1.5.
3.2 Trip Main Turbine.
3.3 IF reactor was not scrammed, THEN enter Procedure 2.2.77.
Page 14 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 6 Event
Description:
H2 Gas leak in Generator Time Position Applicants Action or Behavior
- 4. Step is N/A.
ATC Update crew of ownership of Scram action parameter of 2.4GEN-H2.
Direct the Actions of 2.4 GEN-H2, per attachment 4 as follows:
Direct BOP Operator to
- Update Crew at 5 psig increments as pressure lowers.
- 45 psig - Generator capability limit shifts to 30 psig curve.
Inform the Crew that:
SCRAM is required when Generator H2 pressure reaches < 30 psig.
- Prepare to reduce power per Procedure 2.1.10 - rapid power reduction may be required.
- Brief Procedure 2.1.5.
- Assign Operator to continue Procedure 2.4GEN-H2 action post-Scram.
- Discuss shutdown resources without Fire Brigade.
- Request Operations support from Training or WCC.
- Contact RP for H2 monitoring in Turbine Building.
- Make announcement for personnel to stay clear of Turbine Building.
- Assign Operator to standby for isolating H2.
- Review Flammable and Other Hazard EALs for applicability.
ROLE PLAY-If sent to check H2-PI-13 locally, report pressure is 135 psig.
Booth If sent to check H2-PI-14 (near vacuum priming tank) report Operator hydrogen pressure as 50 psig.
If directed to close H2-106 and H2-108 in the Hydrogen House, wait 3 minutes and report the valves are closed.
END OF EVENT Crew will transition to the next event (SCRAM) as hydrogen pressure approaches 30 psig as listed above.
Notes Page 15 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 7 Event
Description:
Unit SCRAM due to low Generator Hydrogen pressure.
Time Position Applicants Action or Behavior CRS Directs ATC to perform actions 2.1.5 and enters EOP1A Perform Attachment 1 mitigating task scram actions of 2.1.5 as follows:
4.2 Place REACTOR MODE switch to REFUEL.
ATC 4.3 Step is N/A.
4.3.1 Step is N/A.
4.3.2 Step is N/A.
Perform Attachment 2 Reactor Power Control of 2.1.5 as follows:
1 REACTOR POWER CONTROL 1.1 Ensure REACTOR MODE switch is in SHUTDOWN.
1.2 Verify all SDV vent and drain valves are closed.
NOTE - RR pump(s) will be tripped if on Normal Transformer or if ARI/RPT has automatically initiated.
1.3 Ensure operating RR pumps have run back to 22% speed.
ATC NOTE - Steps 1.4 and 1.5 may be performed concurrently.
1.4 Verify all control rods are fully inserted.
1.4.1 If necessary, insert control rods as directed by CRS.
1.5 Observe nuclear instrumentation and perform following:
1.5.1 Insert SRM detectors.
Page 16 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 7 Event
Description:
Unit SCRAM due to low Generator Hydrogen pressure.
Time Position Applicants Action or Behavior 1.5.2 Insert IRM detectors.
1.5.3 Change APRM recorders to IRMs.
1.5.4 Range IRMs on scale.
Check reactor power is lowering ATC Reports NOT all rods inserted during performance of 1.4 of 2.1.5.
6 rods did not fully insert.
BOP Trip the main turbine.
Enters EOP 1A on Low RPV Level and then transfers to EOP 6A and 7A CRS because the reactor is not shutdown under all conditions without Boron.
Report failure of PCIS Group 6 isolation. Enter Procedure 2.1.22.
1.1 IF manual insertion of Group 6 Isolation required, THEN perform 1.1.1 or 1.1.2 1.1.1 To cause full Group 6 Isolation, perform following:
1.1.1.1 Place Mode switch for RMP-RM-452A, RX BLDG VENT RAD MON CH A, to TRIP TEST.
1.1.1.2 Place Mode switch for RMP-RM-452B, RX BLDG VENT RAD MON CH B, to TRIP TEST.
CREW 1.1.1.3 Place Mode switch for RMP-RM-452A to OPERATE.
1.1.1.4 Place Mode switch for RMP-RM-452B to OPERATE.
1.1.2 To cause full Group 6 Isolation, perform following:
1.1.2.1 Place Mode switch for RMP-RM-452C, RX BLDG VENT RAD MON CH C, to TRIP TEST.
1.1.2.2 Place Mode switch for RMP-RM-452D, RX BLDG VENT RAD MON CH D, to TRIP TEST.
1.1.2.3 Place Mode switch for RMP-RM-452C to OPERATE.
Page 17 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 7 Event
Description:
Unit SCRAM due to low Generator Hydrogen pressure.
Time Position Applicants Action or Behavior 1.1.2.4 Place Mode switch for RMP-RM-452D to OPERATE.
END OF EVENT The next event is already active (ATWS).
Notes Page 18 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 8 Event
Description:
ATWS Time Position Applicants Action or Behavior Direct ATC to reset the reactor scram and ARI and insert control rods per CRS Procedure 5.8.3, Alternate Rod Insertion.
Insert Control Rods per 5.8.3.
- 4. ALTERNATE ROD INSERTION 4.1 Perform Attachment 1, Alternate Rod Insertion Methods Flowchart, using the 11" x 17" color-enhanced flowcharts provided in the Control Room.
ATC 4.2 Under ATWS conditions, control rod insertions should start in the center of the core, or for partial ATWS conditions, the center of the region with lowest control rod density, and proceed to every other control rod in an outward spiral pattern. All control rods should be fully inserted, starting from their post ATWS notch position, in a continuous fashion to the fully inserted position.
During failure to scram conditions, insert control rods using one or Critical more methods contained within Procedure 5.8.3 before addressing Task other tasks that detract from inserting control rods in an expeditious manner.
Maintain Reactor Pressure Stabilize RPV pressure below 1050 psig using main turbine BPVs and RPV Pressure Control Systems (TABLE 12) as necessary per step FS/P-5 of EOP 6A.
Table 12 RPV PRESSURE CONTROL SYSTEMS EOP 5.8.12 o HPCI with suction from ECST if available (defeat high area temperature isolation interlocks and high suppression pool water level suction transfer logic if necessary)
BOP o RCIC with suction from ECST if available (defeat low RPV pressure, high RPV water level, high exhaust pressure, and high area temperature isolation interlocks if necessary) o RFPT A o RFPT B o Main steam line drains Page 19 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 8 Event
Description:
ATWS Time Position Applicants Action or Behavior o SRVs only with PC water level above 6 ft (restore IA/N2 supply if necessary) o IF continuous IA/N2 supply to SRV accumulators becomes unavailable:
o THEN perform following:
- Pressure stabilization (FS/P-5):
- 1. Place each SRV control switch in AUTO
- 2. Prevent Low-Low Set actuation o Depressurization (FS/P-8 and FS/P-10):
- 1. Depressurize with sustained SRV opening o RWCU in blowdown mode (only if no boron has been injected into RPV) o AOG 3rd stage air ejector and preheater o Gland sealing steam o Steam jet air ejectors o RWCU with filters bypassed (defeat isolation interlocks if necessary)
CRS Direct BOP to inhibit ADS.
Perform actions for RPV Level Control EOP7A
- 1. Inhibit ADS (FS/L-3)
- 2. IF any main steam line is not isolated THEN start defeating low RPV water level interlocks if necessary, EOP 5.8.20 BOP 3. Is reactor power above 3% or cannot be determined (FS/L-4)
- 4. FS/L5, 6, 7, and 8 NA
- 5. FS/L9 Maintain RPV water level between -183 in. and +54 in. using Outside Shroud Injection Systems (TABLE 13)
Page 20 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 8 Event
Description:
ATWS Time Position Applicants Action or Behavior Upon insertion of all control rods inform the CRS and continue in 2.1.5 post ATC scram activities.
CRS Exit EOPs 6A and 7A and re-enter EOP 1A END OF EVENT Proceed to the next event at direction of the lead examiner.
Notes Page 21 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 9 Event
Description:
FW Line B Break Inside the Drywell Time Position Applicants Action or Behavior When directed by lead examiner, activate trigger 5 (FW leak line Booth break inside primary containment and RCIC flow controller Operator failure).
Direct the actions of 2.4MC-RF, CONDENSATE AND FEEDWATER ABNORMAL Determine that the B Feedwater line has failed and RCIC will need to CRS be used to restore Reactor Water Level.
Enter EOP 3A, Primary Containment Control and direct actions.
Direct Drywell FCUs placed in OVERRIDE.
NOTE to Examiners: HPCI injects into feedwater Line B. (Failure is in FW line B)
Places Drywell FCUs in OVERRIDE as directed.
Perform the actions of 2.4MC-RF, CONDENSATE AND FEEDWATER ABNORMAL as follows:
4.1 If system piping not intact, perform following:
4.4.1 If break is in Turbine Building, concurrently enter Procedure 5.1BREAK.
4.4.2 If break is endangering personnel or equipment necessary for safe operation:
ATC 4.4.2.1 Concurrently enter Procedure 2.1.5.
4.4.2.2 Ensure RFPs tripped.
4.4.2.3 Ensure RFP discharge valves closed.
4.4.2.4 At a RFPT/RVLC HMI, perform following:
4.4.2.4.1 Select RFPT-1A or RFPT-1B System.
Page 22 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 9 Event
Description:
FW Line B Break Inside the Drywell Time Position Applicants Action or Behavior 4.4.2.4.2 Select STARTUP VALVE screen.
4.4.2.4.3 Press EMER CLOSE button.
4.4.2.4.4 Confirm pop-up screen.
4.4.2.5 Ensure condensate booster pumps tripped.
4.4.2.6 If necessary, trip condensate pumps.
4.4.3 Notify Plant personnel to stay clear of affected area via gaitronics.
CREW Determine feedwater leak in FW Line B.
BOP Secure HPCI per the Hard Card.
CREW Update Group 6 isolation.
Take drywell pressure as critical parameter and make periodic updates BOP to the crew as it rises.
Critical Initiate Drywell spray when torus pressure exceeds 10 psig and Task before Pressure Suppression Pressure (PSP) Graph is exceeded.
Direct transfer of reactor level control from Condensate/Feedwater to CRS RCIC.
When RFPs/condensate booster pumps are tripped, use RCIC per BOP Procedure 2.2.67.1 to maintain RPV level.
Monitor and control PC pressure below 1.84 psig using containment pressure control systems, EOP 5.8.17 (PC/P-1).
Before torus pressure reaches 10 psig Spray Torus (PC/P-2).
BOP When torus pressure exceeds 10 psig Spray the Drywell (PC/P-3) maintain drywell pressure between +2 - +10 psig.
Monitor average drywell temperature, EOP 5.8.10, and control below 150°F using available drywell cooling (DW/T-1).
Page 23 of 26
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 1 Event No.: 9 Event
Description:
FW Line B Break Inside the Drywell Time Position Applicants Action or Behavior When average drywell temperature cannot be maintained below 150°F, Operate all available drywell cooling (defeat isolation interlocks if necessary (DW/T-2).
Before average drywell temperature reaches 280°F Spray the Drywell (DW/T-4).
Monitor and control torus water level between +2 in. and -2 in. (refer to SOP 2.2.69.3 prior to discharging water) (SP/L-1).
Monitor average torus water temperature, EOP 5.8.9, and control below 95°F using available suppression pool cooling (SP/T-1).
END OF EVENT When all control rods have been inserted, RPV level and drywell pressure are being controlled within desired band, stop the scenario as directed by the Lead Examiner.
Notes Page 24 of 26
Appendix D Required Operator Actions Form ES-D-2 Simulator Setup Initialize the simulator in IC 16 (BOL) (Protected IC 231)
Triggers and Malfunctions E1 - EG03 at 1.5% with 4.5 minute ramp. (Event 6)
E2 - RR17a 55% with 2 minute ramp. (Event 3)
E3 - ED19C Loss of 125v DC Panel AA-3. (Event 5)
E4 - RC08, Inadvertent RCIC isolation (Event 4)
E5 - FW18b, 30% on a 3:30 ramp rate, MS02b, 12% on a 3:30 ramp rate and 5:00 time delay. (Event 9)
E6 - None E7 - Ia15 Station Air Compressor local start.
E9- None E10- None RD15, Failure of control rods to scram-Active (02-27, 06-15, 14-31, 18-27, 22-07, 22-39) (Event 8)
RP15 PCIS Group 6 fails to actuate on low RPV level (Active) (Event 7)
Overrides None Panel Set-up
- Mark Tendamatic plaque on Board B with A-B-C
- Ensure PMIS IDTs are blank.
- Place the Startup BOL Rod Sequence Book on Panel 9-5.
- Remove D Circulating Water Pump from service.
- Ensure Station Air Compressor A running and B secured.
- Ensure CRD Pump A is operating.
Procedures Needed
- Copy of 2.2.3 Circulating water System marked up to step 5.5, and indicate section 9 Backwash has been completed.
Tags Hung None Parameter Monitoring:
Monitor RPV Pressure, Drywell pressure and RPV level.
Page 25 of 26
Appendix D Required Operator Actions Form ES-D-2 Turnover Sheet:
Plant Status: The plant is operating at approximately 85% at the beginning of the current fuel cycle.
Risk: Green Activities in Progress:
- Preparation for Startup of D Circulating Water Pump to support startup.
Procedure 2.2.3 is completed through step 5.5, and backwash is complete per section 9.0.
LCOs in effect: None Equipment out of service: None.
Activities for the Shift:
- Place D CWP in service to support continued startup.
NOTE: This is NOT the first power rise since the outage.
- Raise power to 90% this hour using Recirculation flow.
Page 26 of 26
Appendix D Required Operator Actions Form ES-D-2 Facility: Cooper Nuclear Station Scenario No.: 2 Op-Test No.: ___1____
Examiners: ____________________________ Operators:_____________________________
Initial Conditions: 100% power, EOL, no equipment out of service, Turnover: Lower power to 95% for HPCI Test. Following HPCI Test return to 100% power.
6.HPCI.103 completed to Step 4.13.
Event Malf. Event Event No. No. Type* Description 1 SW04 C RHRSW Pump trips when started. (2.2.70)
(BOP)
The SRO addresses Tech Spec 3.7.1 Condition A for one TS pump INOP (SRO) 2 N/A N Place RHR Loop B in Suppression Pool Cooling (2.2.69.3)
(BOP) 3 N/A R Lower Power with Reactor Recirculation (2.1.10)
(ATC) 4 HP12 N Perform HPCI Full Flow Test (6.HPCI.103)
(BOP)
TS (SRO) Enters Tech Spec 3.5.1C and declares HPCI INOP 5 RD04a I (ATC) In Service CRD FCV fails closed.
6 RR26c I (BOP) LIS-72C and LIS-72D fail downscale. RCIC initiates.
RR26d (Abnormal Procedure 2.4CSCS)
TS (SRO) LCO 3.5.3 Condition A.
7 IA05 C Instrument Air dryer plugs. (Abnormal Procedure 5.2AIR)
(BOP) 8 RR50A Reactor Recirculation Pump high Vibration (ARP)
RR10A, C Recirculation Pump Seal Failure (ARP)
RR11A (ATC)
(Abnormal Procedures 2.4RR and 2.4PC) 9 RR31A M© LOCA - RR Suction Line Break (EOP 1A, 3A)
(All)
C © RD01 (ATC) Scram Discharge Volume Drain Vlv. Fails to close Page 1 of 32
Appendix D Required Operator Actions Form ES-D-2 10 O/R C© RHR Loop A Drywell Spray Valves de-energize.
(BOP)
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor, (T)echnical Specifications, (©) CT Page 2 of 32
Appendix D Required Operator Actions Form ES-D-2 Initial Conditions: 100% power, EOL, HPCI INOP for testing.
Turnover:
Lower power to 95% for HPCI Test. Following HPCI Test return to 100% power. 6.HPCI.103 completed to step 4.13
==
Description:==
RHR Suppression Pool cooling is placed into service in preparation for the HPCI run. RHR Service Water Booster system is started and then RHR is placed into service.
The B RHRSW Pump trips when B loop of RHRSW is placed in service per Procedure 2.2.70, RHR Service Water Booster Pump System, to support Suppression Pool Cooling. The other pump in the loop is started per procedure. The CRS addresses Tech Spec LCO 3.7.1 and declares the tripped pump inoperable.
The BOP Operator places B Loop of RHR in Suppression Pool Cooling operation to support the HPCI Full Flow Test per 2.2.69.3, RHR Suppression Pool Cooing and Containment Spray.
The ATC reduces reactor power using reactor recirculation flow to 95% reactor power in preparation for the HPCI Full Flow Test per 2.1.10 Station Power Changes.
The BOP Operator performs the HPCI Full Flow Test per 6.HPCI.103. At step 4.16 the test fails and the SRO addresses Tech Spec 3.5.1C and declares HPCI INOP.
The in-service CRD FCV fails closed requiring the ATC to enter Abnormal Procedure 2.4CRD which requires shifting FCVs per procedure 2.2.8.
The BOP responds to alarms 9-3-2/A-5, 9-3-2/B-5 and 9-4-1/A-1. RCIC starts and must be secured per Abnormal Procedure 2.4CSCS. The SRO enters TS LCO 3.5.3, Condition A for RCIC being inoperable.
The BOP responds to alarm A-4/A-5, CONTROL AIR LOW PRESSURE, due to instrument air dryers plugging. The BOP enters Abnormal Procedure 5.2AIR and opens a motor operated valve that bypasses the air dryer. Once the other air dryer train is placed in service the bypass valve can be closed.
The ATC responds to high vibration on the A Reactor Recirculation Pump per alarm 9-4-3/C-3 and begins to reduce recirculation pump speed to reduce vibrations. The vibration continues and the Recirculation Pump seals fail resulting in a LOCA inside the Drywell. The pump is secured and isolated and the primary containment is vented with Standby Gas Treatment. After a time delay the RR suction pipe breaks. The SRO enters EOP 1A and directs the ATC to SCRAM the reactor then enters EOP 3A to address containment pressure issues.
During the SCRAM recovery, one of the SDV drain valves fails to close resulting in a primary system leaking into secondary containment. The ATC recognizes this and closes the valve using the control switch on Panel 9-5 and reports the action to the SRO.
Page 3 of 32
Appendix D Required Operator Actions Form ES-D-2 The SRO directs the BOP operator to utilize Drywell Sprays and control drywell pressure between 2 psig and 10 psig per EOP 3A. If the operator fails to control drywell pressure the valves will NOT close resulting in a negative pressure in primary containment.
The scenario ends when the primary containment pressure is being controlled in band (+2 to
+10 psig) as directed by the SRO and Reactor water level is in the normal range.
Critical Task List Event 9- (ATC) Isolate primary system discharging into secondary containment before any Max Safe Operating Limit is reached.
Critical Task NOTE to Examiners: The SDIV drain valve (AO-33) on the south volume fails to isolate when required post scram.
Event 9 - (BOP) Initiate Drywell Spray prior to Drywell pressure exceeding Critical the Pressure Suppression Pressure (PSP) graph.
Task Note to Examiners: Either Loop of RHR may be used for Torus Spray and Drywell Spray. Only A Loop of RHR may be used for Torus cooling.
Event 10 - (BOP) Secure RHR Loop A drywell sprays or lower Loop B sprays prior to Drywell Pressure reaching negative pressure.
Critical NOTE to Examiners: During performance of Drywell Sprays using Task procedure 2.2.69.3 during execution of EOP 3A if the operator fails to recognize DW Spray valves have lost power the valves will fail to close resulting in negative DW pressure and challenging PC Integrity.
Procedures used 2.2.70, RHR Service Water Booster Pump System (Normal)
Annunciator 9-4-3/A-2 or 9-3-3/D-1 for RHR Service Water Pump trip (ARP) 2.2.69.3, RHR Suppression Pool Cooling and Containment Spray (Normal) 2.1.10, Station Power Changes (Normal) 6.HPCI.103, HPCI IST AND 92 DAY TEST MODE SURVEILLANCE OPERATION (Normal)
Annunciator 9-5-2/E-6, CRD Flow Control Valve fails closed. (ARP) 2.4CRD, place standby CRD Flow Control Valve into service. (AOP)
Annunciator 9-3-2/A-5, reactor low-low level due to LIS failure (ARP)
Annunciator 9-3-2/B-5, reactor low-low level due to LIS failure (ARP)
Annunciator 9-4-1/A-1, RCIC initiation due to LIS failure (ARP) 2.4CSCS, Inadvertent ECCS Initiation due to LIS failure (AOP)
Annunciator A-4/A-5 for instrument air dryer plugging (ARP)
Page 4 of 32
Appendix D Required Operator Actions Form ES-D-2 5.2AIR for instrument air dryer plugging (AOP)
Annunciator 9-4-3/C-3 for RR pump high vibration (ARP)
Annunciator 9-4-3/A-3 for RR pump seal failure (ARP) 2.4RR for RR pump seal failure (AOP) 2.4PC for RR pump seal failure (AOP) 2.2.68.1, Reactor Recirculation System Operations for single loop operation (Normal) 2.1.5, Scram (EOP)
EOP-1A EOP-3A 2.2.69.3, RHR Suppression Pool Cooling and Containment Spray to spray the torus and drywell (Hard Card)
Page 5 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 1 Event
Description:
RHRSWBP trips Time Position Applicants Action or Behavior NOTE to Examiners: SWB Pump B or D will trip shortly after starting.
Booth Allow the SWBP to run for a couple of seconds before tripping the first Operator one started. Insert Trigger 10 for SWBP B or Trigger 11 for SWBP D.
Place RHRSW system B in service per 2.2.70 5.2.1 Place and hold SWBP B or D switch to START until pump starts.
5.2.2 At Panel 9-3, check SWBP B or D AMPS are normal.
5.2.3 At Panel 9-3, check SW-MO-89B, HX-B SW DISCH VLV, opens.
BOP Respond to alarm 9-3-3/C-1 (Pump B) or 9-3-3/D-1 (Pump D).
2.3 Start SWBP B(D), as required, per Procedure 2.2.70.
Respond to alarm 9-3-3/A-1 (Pump B) or 9-3-3/B-1 (Pump D).
2.3 Start SWBP B(D), as required, per Procedure 2.2.70.
ROLE PLAY: If contacted as the E Shop to investigate the SWBP trip, Booth wait 5 minutes and report a bad overload/ground relay in the start Operator circuit is the cause.
Booth After the E Shop report, call the CRS as AOM Shift and direct the B Operator Loop of RHRSW be placed into service.
CRS Direct BOP to place the other RHRSW pump in service per 2.2.70.
Refers to Tech Spec 3.7.1 Condition A, One RHRSWB Pump inoperable.
CRS Action A.1 Restore RHR suppression pool cooling subsystem to OPERABLE status.
Time 30 Days to restore 5.2.1 Place and hold SWBP B or D switch to START until pump starts.
BOP 5.2.2 At Panel 9-3, check SWBP B or D AMPS are normal.
5.2.3 At Panel 9-3, check SW-MO-89B, HX-B SW DISCH VLV, opens.
Page 6 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 1 Event
Description:
RHRSWBP trips Time Position Applicants Action or Behavior 5.1.4.1 Flow on SW-FI-132B, SW FLOW, between 2500 and 4000 gpm.
5.1.4.2 SWBP B or D AMPS 136 amps.
5.1.5 Ensure differential pressure on SW-DPI-359B, RHR HX B SW SIDE DIVIDER PLATE DIFFERENTIAL PRESSURE (R-903-B RHR HX Room), 17.0 psid.
5.1.5.1 Record SW-DPI-359B P (R-903-B RHR HX Room) in Narrative Logs When requested as NLO to report differential pressure at step 5.2.5 of Booth SW 2.2.70, respond it indicates 5 psid. (<17 psid is procedurally Operator acceptable)
END OF EVENT Notes Proceed to the next event when CRS directs SPC placed into service..
Page 7 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 2 Event
Description:
Place RHR Loop B in Suppression Pool Cooling (Procedure 2.2.69.3)
Time Position Applicants Action or Behavior Directs BOP to place RHR Loop B in Suppression Pool Cooling per CRS 2.2.69.3.
Booth ROLE PLAY: When contacted, report suction line drain flush for hot Operator spots is not required.
Contact ALARA to determine if suction line drain flush for hot spots is needed.
Ensure RHR Subsystem B in Standby Status per Procedure 2.2.69.
Notify Radiation Protection of RHR startup.
BOP IF RHR Subsystem B is being placed in suppression pool cooling to support non-emergency evolutions, THEN perform Section 3 concurrent with this section.
3.1.2 Initiate 6.LOG.601 Torus Average Temperature and Drywell Bulk Average Temperature Log Attachment for testing which adds heat to the suppression pool.
NOTE to Examiners: Annunciator 9-3-1/G-1, ADS AUX COOLING INTERLOCK, is an expected alarm when starting an RHR pump.
Initiate Suppression Pool Cooling:
8.23 Open RHR-MO-39B, SUPPR POOL COOLING/TORUS SPRAY VLV 8.25 Start RHR Pump B or D.
8.26 Throttle open RHR-MO-34B, SUPPR POOL COOLING INBD THROTTLE VLV, to obtain rated cooling flow or as directed by BOP Control Room Supervisor 8.27 Ensure RHR-MO-16B (min flow valve) closed.
8.28 Perform one of the following:
8.28.1 Close CM-38, LOOP B INJECTION LINE PRESSURE MAINTENANCE SHUTOFF (R-958-SW).
8.28.2 Maintain RHR Subsystem B pressure greater than Page 8 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 2 Event
Description:
Place RHR Loop B in Suppression Pool Cooling (Procedure 2.2.69.3)
Time Position Applicants Action or Behavior Condensate Transfer System pressure to prevent filling Torus.
8.29 Throttle closed RHR-MO66B, HX BYPASS VLV, to obtain desired cooling rate.
END OF EVENT Notes Proceed to the next event when the CRS directs lowering reactor power.
Page 9 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 3 Event
Description:
Reduce Power with Reactor Recirculation Time Position Applicants Action or Behavior Conducts Reactivity Briefing.
Notifies Shift Manager and Load Dispatcher of power reduction CRS for HPCI testing.
Directs ATC to lower reactor power to 95% per 2.1.10.
NOTE to Examiners: RR pump flows can be read on recorder RR-FR-163 on VBd 9-4.
Enter Procedure 2.1.10 Station power changes, Section 7 RR FLOW.
7.4 Lower power by lowering RR pump flow. Maintain rate of ATC power change consistent with system capabilities as determined by Load Dispatcher and TG limits.
Monitors reactor power, level, and power-to-flow map.
Reports power lowered to 95% to SRO.
END OF EVENT Notes Proceed to the next event when CRS direct surveillance to begin.
Page 10 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 4 Event
Description:
Perform HPCI Full Flow Test (Procedure 6.HPCI.103)
Time Position Applicants Action or Behavior NOTE to Examiners: The HPCI Aux Oil Pump discharge line rupture is passive until the pump is started.
CRS Directs performance of 6.HPCI.103 ROLE PLAY: When requested to establish communications, respond Both that you are setup and ready to begin 6.HPCI.103 at step 4.16.
Operator Wait 2 minutes and report oil pressures were recorded.
Reviews procedure 6.HPCI.103 in preparation for continuing surveillance.
Establish Communications with local Operator in HPCI room.
Begins at step 4.13 4.13 Informs CRS that HPCI System is inoperable for testing.
BOP 4.14 Step already completed 4.15 Step already completed 4.16 (Time) Start AUXILIARY OIL PUMP and time STOP VALVE opening stroke time ROLE PLAY-After HPCI AOP is started and Trigger 13 becomes active, Booth call the control room and report a large lube oil leak on the AOP Operator discharge piping.
CRS Halt the HPCI surveillance.
Refers to Tech Spec 3.5.1 Condition C and declares HPCI INOP.
Action C.1 Verify by administrative means RCIC System is OPERABLE within one CRS hour AND C.2 Restore HPCI System to OPERABLE status within 14 days.
Page 11 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 4 Event
Description:
Perform HPCI Full Flow Test (Procedure 6.HPCI.103)
Time Position Applicants Action or Behavior BOP Place HPCI AOP control switch to Pull-To-Lock.
END OF EVENT Notes Proceed to the next event at direction of the lead examiner.
Page 12 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 5 Event
Description:
In-Service CRD FCV fails closed.
Time Position Applicants Action or Behavior Booth When directed by the Lead Examiner, Insert Trigger 6, (CRD FCV fails Operator closed).
Respond to alarm 9-5-2/E-6, CRD CHARGING HEADER HIGH PRRESSURE.
1.1 Check drive water flow control valves for proper operation.
1.2 Adjust CRD-MO-20 to maintain following:
1.2.1 Drive water DP of ~ 265 psid.
ATC 1.2.2 Cooling water DP of ~ 20 psid.
1.3 Adjust charging water pressure manually with CRD-170, PUMP DISCHARGE MANUAL PRESSURE CONTROL VALVE, per Procedure 2.2.8.
1.4 IF annunciator due to CRD flow degradation, THEN enter Procedure 2.4CRD.
Report alarm references 2.4CRD.
.Enter Abnormal Procedure 2.4CRD, CRD TROUBLE.
Page 13 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 5 Event
Description:
In-Service CRD FCV fails closed.
Time Position Applicants Action or Behavior Enter 2.4CRD Attachment 5 for cooling water trouble.
CWT-1 CWT-2 CWT-3 Stop Any Cooling Ensure HCU Valve START Rod Water Flow Lineup Correct Movement 45-50 gpm? YES Per Procedure 2.2.8A CWT-4 NO Take Manual Flow Control with CRD-FC-301 CWT-5 Cooling YES Water Flow 45-50 gpm?
CWT-6 CRDM NO temperature
> 350F?
NO CWT-7 CWT-14 CWT-15 Rx Eng and ATC Shift FCVs per Procedure Address OPERABILITY per TS 3.1.4 (ref Proc 10.35) and obtain Rx Eng CRD System Eng Provide 2.2.8 and CRD System Eng Guidance Guidance NO CWT-13 CRDM temperature
> 350F?
CWT-8 Cooling Water Flow YES 45-50 gpm?
NO YES YES CWT-9 CWT-11 CWT-10 CWT-12 Cooling Take Manual Flow Cooling Take Manual YES NO Water Flow Control with Local Water Flow Flow Control with 45-50 gpm? Controller per 45-50 gpm?
CRD-FC-301 Procedure 2.2.8 CWT-16 NO Rx Eng, Management, CRD System Eng Provide Guidance Follow 2.4CRD Attachment 5 path to step CWT-7 and shift FCVs per Procedure 2.2.8.
20.1 Ensure CRD-FC-301 in BAL with settape adjusted, as required, for obtaining
~ 50 gpm cooling water flow.
ATC 20.4 .1 Step performed locally by building operator (controller in manual) 20.4.2 Building operator opens FCV B inlet valve.
20.4.3 Building operator opens FCV B outlet valve.
20.4.4 Building operator ensures FCV A in manual.
Page 14 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 5 Event
Description:
In-Service CRD FCV fails closed.
Time Position Applicants Action or Behavior 20.4.5 Step is N/A because the valve is closed.
20.4.5 Building operator opens FCV B.
20.4.9 & 10 Building operator isolates FCV A.
When directed to CRD FCV use remote function RD12 to OPEN to Booth unisolate FCV B. Use remote function RD11 to CLOSE to isolate FCV Operator A.
END OF EVENT Notes Proceed to the next event at direction of the lead examiner.
Page 15 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 6 Event
Description:
LIS-72C and LIS-72D fails downscale.
Time Position Applicants Action or Behavior Booth When directed by the Lead Examiner, Insert Trigger 7 (RD26C and Operator D. NBI-LIS-72C and D)
Respond to alarms:
9-3-2/A-5, RX LOW WATER LEVEL -42 2.1 If alarm is not valid, then enter Procedure 2.4CSCS to secure HPCI and RCIC as dictated by plant conditions.
9-3-2/B-5, RX LOW WATER LEVEL -113 2.1 If alarm not valid, then perform following:
2.1.1 Enter Procedure 2.4PC.
2.1.2 Enter Procedure 2.4CSCS.
BOP 2.1.3 Step is N/A.
9-4-1/A-1, RCIC LOGIC ACTUATED 2.1 If initiation not valid, perform following:
2.1.1 Press and hold TURBINE TRIP button until throttle valve closed.
2.1.2 Leave RCIC-MO-131 open, so turbine trip will not reset.
2.1.3 Enter Procedure 2.4CSCS.
CRS Enter Abnormal Procedure 2.4CSCS. Assign actions to BOP.
ROLE PLAY: If directed to go to local instrument racks, report Booth NBI-LIS-72C and 72D are both down scale. NBI-LIS-72A and B Operator are reading normal.
Review TS LCO 3.5.3 Condition A for RCIC and determine Condition B applies due to HPCI being inoperable.
Be in MODE 3 in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and reduce reactor steam dome CRS pressure 150 psig within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.
Review TS LCO 3.3.5.1-1 for Function 3a (HPCI low level initiation) Note half of HPCI initiation logic is tripped.
Page 16 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 6 Event
Description:
LIS-72C and LIS-72D fails downscale.
Time Position Applicants Action or Behavior TS LCO 3.3.5.2-1 for Function 1(RCIC low level actuation)-Note logic is tripped.
Trip RCIC by depressing the Turbine Trip pushbutton on Panel 9-4.
BOP Observe RCIC speed lowers to zero.
Verify MO-131, STEAM SUPPLY TO TURBINE valve remains open.
END OF EVENT Notes Proceed to the next event at direction of the lead examiner.
Page 17 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 7 Event
Description:
Instrument Air dryer plugs Time Position Applicants Action or Behavior Booth When directed by the Lead Examiner, Insert Trigger 2 (IA05, Operator Instrument Air dryer plugging)
Respond to alarm A-4/A-5, CONTROL AIR LOW PRESSURE.
1.1 Verify SACs operating properly.
1.2 Check for excessive air leaks or usage.
BOP 1.3 Enter Procedure 5.2AIR Report Instrument air pressure from IA-PI-606 (Panel A)
Report Service air pressure from SA-PI-611.
Report Service air pressure high and instrument air pressure low.
CRS Enter Abnormal Procedure 5.2AIR. Assign actions to BOP.
Booth ROLE PLAY: If directed to report air filter dP, wait 3 minutes and Operator report the filter dP is rising.
4.3 If air drying/filtering components at fault then perform following:
4.3.1 Open SA-MO-81, SA TO IA CROSSTIE (Panel A) 4.3.2 Place standby dryer and filters in service per Procedure 2.2.59.
BOP 4.3.3 If necessary, manually bypass any obstructed component(s).
4.3.4 When dryer and filter flow returned to service, close SA-MO-81.
Contact building operator and direct other air dryer/filter placed in service.
Booth If directed to place other air dryer/filter in service, wait 5 Operator minutes delete malfunction IA05, and report the other Page 18 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 7 Event
Description:
Instrument Air dryer plugs Time Position Applicants Action or Behavior dryer/filter is in service.
END OF EVENT Notes Proceed to the next event at direction of the lead examiner.
Page 19 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 8 Event
Description:
Reactor Recirculation Pump High Vibration (ARP 9-4-3/C-3)
Recirculation Pump Seal Failure (ARP 9-4-3/A-3)
Time Position Applicants Action or Behavior Booth When directed by lead examiner, insert Trigger 4 (RR10a, RR11a, RR50a RR31a, RR Pump A #1 and #2 seal failure, RR Motor A high Operator vibration, and RR Loop A suction rupture)
Respond to alarm 9-4-3/C-3, RECIRC A PUMP MOTOR HI VIBRATION 1.1 Monitor RR A pump/motor vibration using PMIS Points.
ATC 1.2 NA 1.3 Notify System Engineer of valid alarms.
ROLE PLAY: If sent to the 976' elevation to observe RR Pump A motor Booth vibrations, wait 4 minutes and report the MOTOR LOWER vibration is Operator indicating 10 mils (Alert) and the UPPER MOTOR velocity is 6 mils (Alert).
NOTE to Examiners: ATC may trip RR pump A before SRO directs it if a drywell pressure increase is noted with the seal trouble annunciator.
ATC Respond to alarm 9-4-3/A-3, RECIRC PUMP A SEAL TROUBLE Operator responds to annunciator, announces alarm RR Pump A seal ATC failures, and refers to alarm procedure.
CRS Directs ATC to trip RR pump A and entry into 2.4RR.
BOP Report drywell pressure rise.
Enter Abnormal Procedure 2.4 PC and direct BOP to vent the drywell to CRS maintain drywell pressure within band.
Vent the drywell per the Hard Card:
1.5 Ensure PC-AD-R-1B is open and PC-AD-R-1A is closed.
BOP 1.6 Start preferred SGT fan.
Page 20 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 8 Event
Description:
Reactor Recirculation Pump High Vibration (ARP 9-4-3/C-3)
Recirculation Pump Seal Failure (ARP 9-4-3/A-3)
Time Position Applicants Action or Behavior 1.7 Open SGT-DPCV-546A(B) valve.
NOTE - Steps 1.4 and 1.5 may be performed in any order or concurrently, depending on plant conditions.
1.8 Vent Torus by performing following:
1.8.1 Ensure PC-MO-1308 is closed.1 1.8.2 Open PC-AO-245AV.
1.8.3 Open PC-MO-305MV.
1.8.4 WHEN Torus pressure ~ 0.25 psig, THEN close PC-MO-305MV.
1.8.5 Close PC-AO-245AV.
1.8.6 Place switch for PC-AO-245AV to AUTO.
1.9 Vent Drywell by performing following:
1.9.1 Open PC-AO-246AV.
1.9.2 While ensuring Torus pressure does not exceed Drywell pressure by > 0.1 psig, open PC-MO-306.1 1.9.3 WHEN Drywell pressure ~ 0.25 psig, THEN close PC-MO-306.
1.9.4 Close PC-AO-246AV.
1.9.5 Place switch for PC-AO-246AV to AUTO.
1.10 Place switch for running SGT fan to AUTO.
1.11 Place switch for SGT-DPCV-546A(B) to AUTO.
ATC Trips RR pump A and enters 2.4RR.
Page 21 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 8 Event
Description:
Reactor Recirculation Pump High Vibration (ARP 9-4-3/C-3)
Recirculation Pump Seal Failure (ARP 9-4-3/A-3)
Time Position Applicants Action or Behavior 4.3 Checks power-to-flow map for operating in the exclusion zone 4.4 Secure OWC Injection System, place OWC INJECTION SYS ENABLE SWITCH to SHUTDOWN (PANEL A).
4.5 Perform applicable Attachment 2, RECIRCULATION PUMP SEAL FAILURE Attachment 2
- 1. If both seals have failed and affected RR pump requires prompt isolation, perform following:
1.1 Ensure DRIVE MOTOR BKR 1CN, 1CS (1DN, 1DS) is tripped.
1.2 Close RR-MO-43A(B), PUMP SUCTION VLV.
1.3 Close RR-MO-53A(B), PUMP DISCHARGE VLV.
1.4 Close CRD-50 (CRD-51), REACTOR RECIRCULATION PUMP A (B) SEAL FLOW REGULATOR 46A (B) INLET (R-903-SE).
1.5 Following steps may be performed concurrently:
1.5.1 Enter Single Loop Operation section of Procedure 2.2.68.1.
1.5.2 Ensure RRMG Set A(B) GEN FIELD BKR open.
1.5.3 Ensure operating RRMG is transferred to Startup Transformer per Procedure 2.2.18.
If both seals have degraded and time allows, shut down and isolate affected pump per Procedure 2.2.68.1.
NOTE to Examiners: Venting the drywell with Standby Gas Treatment can keep up with RR seal leakage until the RR suction piping failure leakage exceeds venting capabilities.
END OF EVENT Notes Page 22 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 8 Event
Description:
Reactor Recirculation Pump High Vibration (ARP 9-4-3/C-3)
Recirculation Pump Seal Failure (ARP 9-4-3/A-3)
Time Position Applicants Action or Behavior The next event is already active.
Page 23 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 9 Event
Description:
LOCA - RR Suction Line Break (EOP 1A, 3A)
Time Position Applicants Action or Behavior NOTE to Examiners: malfunction RR31A, 5%, RR Suction line leak is already ramping in (Active).
BOP Report reversal in drywell pressure.
Accept scram action of 1.5 psig drywell pressure from Abnormal Procedure ATC 2.4PC.
CRS Direct ATC to SCRAM at 1.5 psig drywell pressure.
CRS Enters EOP 1A and 3A on high drywell pressure and directs actions.
SCRAM or verify SCRAM per 2.1.5
1.2 Place REACTOR MODE switch to REFUEL.
ATC 1.3 IF reactor power > 3%, THEN perform following:
1.3.1 Place REACTOR MODE switch to SHUTDOWN.
1.3.2 Initiate ARI.
Critical Isolate primary system discharging into secondary containment before Task any Max Safe Operating Limit is reached.
NOTE to Examiners: The SDIV drain valve (AO-33) on the south volume fails to isolate when required post scram.
Perform Attachment 2 Reactor Power Control of 2.1.5 as follows:
ATC 1 REACTOR POWER CONTROL Page 24 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 9 Event
Description:
LOCA - RR Suction Line Break (EOP 1A, 3A)
Time Position Applicants Action or Behavior 1.1 Ensure REACTOR MODE switch is in SHUTDOWN.
1.2 Verify all SDV vent and drain valves are closed.
Report failure of drain isolation valve AO-33 to close. (Panel 9-5)
Places SDV Isolation switch on Panel 9-5 to ISOL.
Reports SDV drain valve closed.
NOTE - RR pump(s) will be tripped if on Normal Transformer or if ARI/RPT has automatically initiated.
1.3 Ensure operating RR pumps have run back to 22% speed.
NOTE - Steps 1.4 and 1.5 may be performed concurrently.
1.4 Verify all control rods are fully inserted.
1.4.1 If necessary, insert control rods as directed by CRS.
1.5 Observe nuclear instrumentation and perform following:
1.5.1 Insert SRM detectors.
1.5.2 Insert IRM detectors.
1.5.3 Change APRM recorders to IRMs.
1.5.4 Range IRMs on scale.
Check reactor power is lowering.
Stabilize RPV pressure below 1050 psig using main turbine BPVs and RPV BOP Pressure Control Systems (TABLE 1) as necessary (RC/L-5)
If ADS timer has initiated THEN inhibit ADS Page 25 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 9 Event
Description:
LOCA - RR Suction Line Break (EOP 1A, 3A)
Time Position Applicants Action or Behavior Note to Examiners: Either Loop of RHR may be used for Torus Spray and Drywell Spray.
Only A Loop of RHR may be used for Torus cooling.
Critical Initiate Drywell Spray prior to Drywell pressure exceeding the Pressure Task Suppression Pressure (PSP) graph.
CRS Enters EOP 3A and directs Containment Sprays initiated.
(PC/P-1 )
Monitor and control PC pressure below 1.84 psig using containment pressure control systems, EOP 5.8.17 (PC/P-2)
BEFORE torus pressure reaches 10 psig, Spray Torus (PC/P-3)
When Torus pressure exceeds 10 PSIG Spray the Drywell
- 2. Containment Sprays (RHR Hard Card) 2.1 IF required, with CRS permission, THEN place CONTMT COOLING 2/3 CORE VALVE CONTROL PERMISSIVE switch to MANUAL OVERRD.
BOP 2.2 IF required, THEN place CONTMT COOLING VLV CONTROL PERMISSIVE switch to MANUAL.
2.3 Ensure RHR-MO-39A(B) open.
2.4 IF reactor pressure 300 psig and injection not desired, THEN close RHR-MO-27A(B), OUTBD INJECTION VLV.
2.5 Ensure RHR PUMP(s) running.
NOTE - RHR pump operation at minimum flow should be limited to
< 15 minutes or pump damage may result.
2.6 Throttle RHR-MO-38A(B) to maintain desired containment pressure.
2.7 Throttle RHR-MO-66A(B) to obtain desired cooling rate.
2.8 IF Drywell Spray required, THEN perform following:
2.8.1 Open RHR-MO-31A(B).
Page 26 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 9 Event
Description:
LOCA - RR Suction Line Break (EOP 1A, 3A)
Time Position Applicants Action or Behavior 2.8.2 Throttle RHR-MO-26A(B) to maintain desired containment pressure.
2.9 IF PCIS Group 6 lights lit on Panel 9-5, THEN ensure one of following open:
2.9.1 REC-MO-711; or 2.9.2 REC-MO-714.
2.10 Place RHR SW System in service:
2.10.1 Start SWBP(s).
2.10.2 Adjust SW-MO-89A(B) to maintain flow between 2500 and 4000 gpm.
2.11 Throttle RHR-MO-66A(B) to maintain desired cooling rate.
Maintain Drywell pressure between +2 & +10 psig.
Ensure each of following initiated:
- ECCS initiations
- DGs (RC/L-3)
ATC Restore and maintain RPV water level between +3 in. and +54 in. with one or more Injection Systems (TABLE 3)
(RC/L-4)
When RPV water level cannot be restored and maintained between +3 in.
and +54 in.
(RC/L-6)
Restore and maintain RPV water level above -150 in. using Injection Systems (TABLE 3) and, if necessary, Alternate Injection Subsystems (TABLE 4)
Page 27 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 9 Event
Description:
LOCA - RR Suction Line Break (EOP 1A, 3A)
Time Position Applicants Action or Behavior END OF EVENT Notes Proceed to the next event.
Page 28 of 32
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 2 Event No.: 10 Event
Description:
RHR Drywell Spray Valves fail to auto close on low DW pressure.
Time Position Applicants Action or Behavior NOTE to Examiners: During performance of Drywell Sprays using procedure 2.2.69.3 during execution of EOP 3A if the operator fails to recognize DW Spray valves have lost power the valves will fail to close resulting in negative DW pressure and challenging PC Integrity.
Critical Secure RHR Loop A drywell sprays or lower Loop B sprays prior to Task Drywell Pressure reaching negative pressure.
Booth As drywell pressure is lowered to ~5 psig, insert Trigger 5 to de-Operator energize MO26A and MO-31A open.
Recognizes that RHR-MO-26A, DRYWELL SPRAY OUTBD THROTTLE VLV and RHR-MO-31A, DRYWELL SPRAY INBD VLV will not close while spraying the Drywell.
BOP If RHR Loop B also being used to spray the drywell, isolate drywell sprays in that loop to maintain drywell pressure above 2 psig.
OR Secure all RHR Loop A pumps.
Report status to the CRS Acknowledges and directs the drywell pressure maintained positive.
CRS When Drywell Pressure is being controlled and RPV level is within band, stop the scenario as directed by the lead examiner.
Page 29 of 32
Appendix D Required Operator Actions Form ES-D-2 Simulator Setup Initialize the simulator in Protected IC 232.
Triggers and Malfunctions E4 - RR10A, RR #1 seal failure, 100% severity with a 5:00 ramp time.
RR11A, RR #2 seal failure, 100% severity with a 15:00 ramp time.
RR31A, RR Suction Line Break, 3.5% severity with a 10:00 ramp time. 6 minute TD.
RR50A RR Pump A High Vibration, 50% severity.
E5 - RH23a and RH19a Loop A DW Spray Valves fail open.
E6 - RD04a 0% with 15 second ramp.
E7 - RR26 C and D.
E9- DMF RD01a (Allows SDIV drain valve to close)
E13- None Trgset 9 "zdirpssws10[1]==1" (SDIV control switch to ISOL)
Trgset 13 "zdihpcisws20[4]==1" (HPCI Aux Oil Pump control switch to START)
RD01a, 100% (Open) South SDV Drain Valve Fails to Close (Active)
HP 12, HPCI oil discharge line rupture (15 second time delay) (Active)
IA05 100% with a 5 minute ramp.
Remotes E5- rh19a, RHR-MO-26a control power failure rh23a, RHR-MO-31a control power failure E10- SW04b RHRSW Pump B trip.
E11- SW04d RHRSW Pump D trip.
Overrides None Panel Set-up
- Ensure HPCI Test displayed on SSSP.
- Ensure Tendamatic plaque labeled B-A-C
- Ensure PMIS IDTs are blank.
- Place the Shutdown EOL Rod Sequence Book on Panel 9-5.
- Ensure Recirculation Controllers are selected to P Procedures Needed 6.HPCI.103 - Completed up to step 4.13, then steps 4.14 and 4.15 are complete.
Tags Hung None Page 30 of 32
Appendix D Required Operator Actions Form ES-D-2 Parameter Monitoring:
Monitor RPV Power, Pressure and Level, Drywell Pressure Page 31 of 32
Appendix D Required Operator Actions Form ES-D-2 Turnover Sheet:
Plant Status: 100% power, EOL Risk: Green Activities in Progress:
Prejob brief for SPC and HPCI surveillance was briefed yesterday.
Procedure 2.2.69.3 is complete through Step 8.17.
RHR Heat Exchanger B was vented at the end of the previous shift in preparation for performing HPCI surveillance test.
6.HPCI.103 - procedure completed up to Step 4.13; Steps 4.14 and 4.15 are N/A.
LCOs in effect: None Equipment out of service: None Activities for the Shift:
- Place B Loop of RHR in Suppression Pool Cooling.
- Lower power to 95% for HPCI Test
- Perform 6.HPCI.103 Test
- Return to 100% power following HPCI test Page 32 of 32
Appendix D SCENARIO OUTLINE Form ES-D-1 Facility: Cooper Nuclear Station Scenario No.: 3 Op-Test No.: ___1____
Examiners: ____________________________ Operators: _____________________________
Initial Conditions: _4%, BCL, power, plant startup in progress.______
Turnover: Procedure 2.1.1, Steps 4.22 and 5.36 are completed, 2.2.77 Attachment 1, Step 1.14 is complete, 2.2.28.1 Step 5.14 is complete. Fuel is being de-channeled on the refueling floor, No Tech Specs Limitations in effect. Reactor Coolant samples (1xE-3 Micro-Curies / CC) indicate higher than normal gross activity level for this point in a startup. Site Management and Reactor Engineering have indicated the startup can continue. PRA risk is green. Continue plant startup.
Event Malf. No. Event Event No. Type* Description 1 N/A R Continue startup using control rods (ATC) 2 NM05A I IRM power supply failure (ARP 9-5-1/D-8)
(ATC)
TS Tech Specs LCO 3.3.1.1, Reactor Protection System (RPS)
(SRO) Instrumentation 3 SW01d C Service Water Pump D Trip (ARP B-3/B-7)
(BOP)
N/A Tech Spec LCO 3.7.2 Service Water (SW) System and TS Ultimate Heat Sink (UHS) for number of Operable SW (SRO) Pumps.
4 RD03d C Control Rod Drifts IN (2.4 CRD)
(ATC)
N/A Tech Spec LCO 3.1.3 for Inoperable Control Rod.
TS (SRO) 5 HP05,CR I HPCI Inadvertent Initiation / Fuel Failure (2.4CSCS) 01, CR03 (BOP) 6 HP06, M (All) LOCA - Steam line break into Secondary Containment (EOP-HP09, © 5A, 2.4 OG, 5.1RAD)
HP15 R SCRAM (2.1.5)
(ATC) 7 N/A M© Emergency Depressurization (>2 above Max Safe) EOP-2A (BOP) 8 FW28B I Reactor Feedpump fails to trip on high level (ATC) 9 PC18a/b I SGT Fans A & B fail to auto start.
(BOP)
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor, (T)echnical Specifications, (©) CT Page 1 of 27
Appendix D SCENARIO OUTLINE Form ES-D-1 Initial Conditions: 4%, BCL, power, plant startup in progress.
Turnover:
Procedure 2.1.1, Steps 4.22 and 5.36 are completed, 2.2.77 Attachment 1, Step 1.14 is complete, 2.2.28.1 Step 5.14 is complete, LCOs and Logs are complete for change to MODE 1.
Fuel is being de-channeled on the refueling floor, No Tech Specs Limitations in effect. Reactor Coolant samples (1xE-3 Micro-Curies / CC) indicate higher than normal gross activity level for this point in a startup. Site Management and Reactor Engineering have indicated the startup can continue normally. PRA risk is green. Continue plant startup.
==
Description:==
A startup is in progress following a refueling outage. Reactor Power is approximately 4% and the intention is to raise power. Reactor Coolant activity is above normal. The ATC continues the plant startup using control rods using procedure 2.1.1, Startup and procedure 10.13, Control Rod Movement Sequence.
During control rod withdrawal, one IRM power supply fails requiring the ATC to bypass the IRM per ARP 9-5-1/D-8. The SRO addresses Tech Spec 3.3.1.1, Reactor Protection System (RPS)
Instrumentation and declares IRM B inoperable. Potential LCO 3.3.1 is logged. The half reactor scram is reset per Procedure 2.1.5.
The BOP operator responds to a Service Water Pump Trip per ARP B-3/B-7 and responds by starting another pump.
The SRO addresses Tech Spec LCO 3.7.2 Service Water (SW) System and Ultimate Heat Sink (UHS) for number of Operable SW Pumps and determines 30 day LCO entry is required per 3.7.2 and 7 day LCO entry is required per 3.8.1 with DG-1 declared inoperable.
One Control Rod drifts in due to a leaking outlet scram valve and the ATC responds per 2.4CRD to fully insert the Control Rod using the emergency in switch. The control rod is fully inserted and the SRO enters Tech Spec 3.1.6 because BPWS is not met. The control rod is declared INOP and de-activated. The SRO addresses Tech Spec LCO 3.1.3 for Inoperable Control Rod.
An Inadvertent HPCI Actuation and Injection occurs resulting in a power excursion that results in some Fuel Failure. The BOP Operator responds per 2.4CSCS and secures HPCI. During the process of tripping HPCI the HPCI Steam line breaks in Secondary Containment. The SRO enters EOP 5A due to high Reactor Building temperature and radiation. EOP 5A provides direction to isolate systems discharging into the area As area temperatures and radiation continue to rise the SRO directs the ATC to SCRAM the reactor per 2.1.5, prior to commencing emergency depressurization, due to the inability to isolate the HPCI steam line break and follows up by entering 5.1 RAD and 2.4 OG.
The crew will be able to anticipate emergency depressurization but will have to close the MSIVs due to MSL HI-HI RAD. Once two or more areas are above Max Safe the SRO will direct the BOP operator to Emergency Depressurize the Reactor per EOP 2A prior to exceeding 312oF anywhere in the reactor building.
Page 2 of 27
Appendix D SCENARIO OUTLINE Form ES-D-1 The SGT fans fail to auto start and the BOP operator must manually start them to prevent the secondary containment pressure from becoming positive and a potential radioactivity release.
During recovery of reactor water level using Feedwater the remaining Reactor Feedpump fails to trip on high level requiring the BOP operator to control RPV level using ECCS Systems.
The scenario ends when the RPV level has been restored to the normal range following emergency depressurization and the SGT system has restored negative pressure in the secondary containment.
Critical task List Event 6- (ATC) With a primary system discharging into secondary containment Critical through an un-isolable break, SCRAM the reactor per EOP 5A and EOP 1A Task prior to commencing Emergency Depressurization.
Event 7- (BOP) With a primary system discharging into secondary containment through an un-isolable break, execute Emergency Depressurization when Critical Maximum Safe Operating Values are exceeded in two or more areas for the Task same parameter per EOP2A prior to exceeding 3120F anywhere in the reactor building.
Procedures used 10.13, control rod withdrawal to raise power (Normal)
Annunciator 9-5-1/D-8, IRM upscale trip due to instrument failure (ARP)
Annunciator 9-5-2/A-3, IRM upscale trip due to instrument failure (ARP)
Annunciator 9-5-2/B-1, IRM upscale trip due to instrument failure (ARP) 2.1.5, Scram for resetting 1/2 scram due to IRM failure (Normal)
Annunciator B-3/B-7 for SW pump trip (ARP)
Annunciator B-3/C-7 for SW pump trip (ARP) 2.2.71, Service Water System for aligning SW Pump selector switch (Normal)
Annunciator 9-5-1/C-4 for control rod drifting inwards (ARP) 2.4CRD, CRD Trouble for drifting control rod (AOP)
Annunciator 9-3-2/F-4 for HPCI inadvertent start (ARP) 2.4CSCS, Inadvertent ECCS Initiation for HPCI start (AOP)
Annunciator 9-3-1/E-10 building high temperature for HPCI operating (ARP)
Annunciator 9-3-1/A-9 building high radiation for HPCI operating (ARP)
EOP-5A EOP-1A 2.1.5, Scram to scram reactor 5.1RAD, Building Radiation Trouble for high reactor building high radiation (AOP) 2.4OG, Off-Gas Abnormal for high off-gas radiation (AOP)
Page 3 of 27
Appendix D SCENARIO OUTLINE Form ES-D-1 5.2FUEL, Fuel Failure for MSL high radiation due to failed fuel (AOP)
EOP-2A Page 4 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 1 Event
Description:
Continue startup using control rods Time Position Applicants Action or Behavior Performs a Reactivity Briefing CRS Directs the ATC to continue startup.
NOTE to Examiners: Reactivity Briefing is normally conducted in briefing room during turnover prior to entering the simulator.
Continue to withdrawal rods using procedure 10.13 starting at step 4.2.1 - Proceed with consecutive step order on Attachment 5 in the Control Rod Sequence Package.
ATC 4.2.3 The Operator shall initial in the "PERFORMED BY" column on Attachment 5.
4.2.2 The Operator or Concurrent Verifier shall place a check mark in the DESIRED ROD SELECTED block for the selected rod.
4.2.3 The Operator shall initial in the "PERFORMED BY" column on BOP Attachment 5.
4.2.4 The Concurrent Verifier shall initial in the "CONCURRENT VERIFICATION" column on Attachment 5.
END OF EVENT Notes Proceed to the next event at direction of the lead examiner.
Page 5 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 2 Event
Description:
IRM power supply failure (ARP 9-5-1/D-8)
Time Position Applicants Action or Behavior When directed by the lead examiner insert Trigger 6 (NM05b Booth Operator IRM Power Supply Failure)
Respond to Annunciators 9-5-1/D-8, IRM RPS CH B UPSCALE TRIP OR INOP.
9-5-2/A-3, RX SCRAM CHANNEL B 9-5-2/B-1, NEUTRON MONITORING TRIP Refers to INSTRUMENT OPERATING PROCEDURE 4.1.2,INTERMEDIATE RANGE MONITORING SYSTEM Visually inspects the IRM B cabinet and recognizes the white INOP light is illuminated and the outputs are downscale indicating a power supply failure.
ATC Bypasses IRM B using joystick on panel 9-5 Verifies remaining IRMs indications have normal reading for the reactor power.
Resets RPS B trip per Procedure 2.1.5, Section 4.
- 4. HALF SCRAM RESET 4.1 Place REACTOR SCRAM RESET switch to Group 1 and 4, Group 2 and 3, then back to NORM.
4.2 Ensure eight SCRAM GROUP lights (Panels 9-15 and 9-17) or SCRAM INDICATIONS GROUP A and GROUP B lights are on.
Booth If requested as I&C to investigate the IRM B power supply, respond that you will prepare a troubleshooting request and Operator investigate.
NOTE to Examiners: TS requires 3 IRMS per trip system so LCO 3.3.1.1 is met. The CRS will call the LCO a Potential LCO and track it in NOMS.
Refers to TECH SPEC LCO 3.3.1.1, Reactor Protection System (RPS) Instrumentation.
CRS LCO 3.3.1.1, Table 3.3.1.1-1, Functions 1a and 1b.
Page 6 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 2 Event
Description:
IRM power supply failure (ARP 9-5-1/D-8)
Time Position Applicants Action or Behavior Declares IRM B Inoperable.
END OF EVENT Notes Proceed to the next event at direction of the lead examiner.
Page 7 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 3 Event
Description:
Service Water Pump D Trip Time Position Applicants Action or Behavior Booth When directed by lead examiner, insert Trigger 4 (Service Water Pump D Trip).
Operator Responds to Annunciator B-3/B-7 SERVICE WATER PUMP D TRIP and B-3/C-7, SERVICE WATER PUMP D OVLD/GROUND 1.2 Maintain SW System pressure >38psig 1.2.1 Place available non-running Service Water Pump in MAN.
BOP 1.2.2 Start available Service Water pump(s) as necessary.
1.3 Ensure MODE SELECTOR switches are aligned per procedure 2.2.71.
Starts SW Pump B at Panel B.
Dispatch an Operator to investigate the pump trip.
When asked to investigate the Service Water Pump D Trip, report the motor is very hot.
Booth If asked to investigate the local SW Pump 4160 V breaker, report the Operator 51X overload/ground relay has tripped for the pump. State a 50-1 flag is showing on the relay.
Refer to Tech Spec 3.7.2.A.1 Declare D Service Water Pump Inoperable.
30 Day LCO applies, and CRS Refer to Tech Spec 3.8.1, B declare the Diesel Generator 1 inoperable, with a seven day LCO.
END OF EVENT Notes Page 8 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 3 Event
Description:
Service Water Pump D Trip Time Position Applicants Action or Behavior Proceed to the next event at direction of the lead examiner.
Page 9 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 4 Event
Description:
Control Rod Drifts IN (2.4 CRD)
Time Position Applicants Action or Behavior Booth When directed by the lead examiner, activate RD03d, Rod 18-39 Drift in (Trigger 1)
Operator Respond to annunciator 9-5-1/C-4, ROD DRIFT.
ATC Determine that rod 18-39 is drifting inward.
Verify no other rod drift indications.
Enter 2.4CRD, Attachment 4, Single Rod Drift IN.
Direct rod driven in with Emergency IN Switch.
CRS Contact the WCC for troubleshooting plan.
Contact Reactor Engineering.
ATC Insert rod 18-39 using Emergency IN switch to full in.
ROLE PLAY: As Reactor Engineer, when contacted by the CRS regarding the control rod drifting in, tell them if they determine the rod is INOP they can continue with the Booth startup.
Operator ROLE PLAY: If contacted as the Work Control Center for the rod drifting in, tell them you will put a team together and develop a troubleshooting plan.
ROLE PLAY: When contacted by the control room as the NLO to isolate Booth HCU 18-39, reply you will isolate the HCU and tag it.
Operator ACTION: THEN: wait 5 minutes then delete malfunction RD03d.
NOTE to Examiners: If the CRS declares control rod 18-39 inoperable first, then LCO 3.1.6 does not apply. (LCO 3.1.6 applies only to OPERABLE control rods)
Refer to Tech Spec 3.1.6 and determine Condition A applies.
A.1 Move control rod 18-19 to its correct position within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.
CRS OR A.2 Declare control rod 18-19 inoperable within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.
Page 10 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 4 Event
Description:
Control Rod Drifts IN (2.4 CRD)
Time Position Applicants Action or Behavior Refer to Tech Spec 3.1.3 and determine Condition C applies.
C.1 Fully insert control rod 18-19 within 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br />.
C.2 Disarm control rod 18-19 within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
Declare the Control Rod Inoperable and direct it to be deactivated.
Call NLO and direct them to stop by the WCC to get a clearance and to ATC isolate control rod 18-39 and tag it.
END OF EVENT Notes Proceed to the next event at direction of the lead examiner.
Page 11 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 5 Event
Description:
HPCI Inadvertent Initiation / Fuel Failure (2.4CSCS)
Tech Spec 3.5.1, ECCS Operating Time Position Applicants Action or Behavior Booth When directed by Lead Examiner, Insert Trigger 3 (HP05, HPCI Operator Inadvertent Initiation and HP06 HPCI steam line break)
Responds to alarm 9-3-2/F-4, HPCI PUMP LOW FLOW.
Makes report HPCI has started.
ATC Check Reactor Level and Drywell pressure.
Verify there are no valid start signals for HPCI.
CRS Direct HPCI tripped per 2.4CSCS Respond to inadvertent initiation of HPCI using 2.4CSCS and 3.1 IF HPCI initiated, THEN perform following:
3.1.1 Ensure AUXILIARY OIL PUMP control switch in START.
3.1.2 Press and hold TURBINE TRIP button.
BOP 3.1.3 AFTER turbine stops, THEN place AUXILIARY OIL PUMP in PULL-TO-LOCK.
3.1.4 Release TURBINE TRIP button.
Inform the CRS that HPCI is INOP.
Enter EOP 5A on high building temperature (9-3-1/E-10) high building CRS radiation (9-3-1/A-9)
Make plant announcement warning personnel of high reactor building CREW temperature or radiation.
Refers to Tech Spec 3.5.1, ECCS Operating, Action C requires verification CRS of RCIC operable within one hour and determines Action C.2 applies requiring restoring HPCI to operability within 14 days.
END OF EVENT Notes Page 12 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 5 Event
Description:
HPCI Inadvertent Initiation / Fuel Failure (2.4CSCS)
Tech Spec 3.5.1, ECCS Operating Time Position Applicants Action or Behavior The next event is already in progress.
Page 13 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 6 Event
Description:
LOCA - Steam line break into Secondary Containment Time Position Applicants Action or Behavior NOTE to Examiners: Malfunctions HP09, and HP15 (HPCI failure to automatically isolate) and CR01 CR03 (fuel element failure) are ACTIVE.
Crew recognizes rising temperature and radiation levels in the reactor CREW building and diagnose a break in the HPCI Steam Line.
Enters EOP 5A, direct actions as follows:
Direct HPCI to be isolated.
Rad Release Isolate all primary systems discharging into areas outside primary and secondary containments except systems required to support EOPs (RR-2)
Before offsite gaseous radioactivity release rate reaches that which requires a General Emergency BUT ONLY IF primary system is discharging into area outside primary and secondary containments Emergency Depressurize the reactor (RR-3)
Secondary Containment Control When Reactor Bldg. exhaust plenum radiation level exceeds 10 mr/hr CRS ensure:
- isolation of Rx Bldg. HVAC
- initiation of SGT When Reactor Building HVAC isolates AND Rx Bldg. exhaust plenum radiation level is below 10 mr/hr, then restart Rx Bldg HVAC (defeat high drywell pressure and low RPV water level isolation interlocks if necessary, EOP 5.8.20) (SC-1)
Monitor and Control TEMPERATURE, RADIATION, & WATER LEVEL BEFORE any secondary containment parameter reaches its maximum normal operating value:
- Temperatures (TABLE 9)
- Radiation (TABLE 10)
- Water levels (TABLE 11)
Isolate all primary systems discharging into areas outside primary and Page 14 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 6 Event
Description:
LOCA - Steam line break into Secondary Containment Time Position Applicants Action or Behavior secondary containments except systems required to support EOPs (SC-10)
BEFORE any secondary containment parameter reaches its maximum safe operating value:
- Temperatures (TABLE 9)
- Radiation (TABLE 10)
- Water levels (TABLE 11) with a primary system discharging into secondary containment enter EOP 1A, SCRAM the reactor.
Take action in EOP5A as follows:
BEFORE any secondary containment parameter reaches its maximum safe operating value:
- Temperatures (TABLE 9)
- Radiation (TABLE 10)
- Water levels (TABLE 11)
BOP/ATC 1. Start all reactor building quad room coolers.
- 2. Open REC cooling water supply (MO-711/714) to provide cooling to the quad room coolers.
Respond to Annunciator 9-3-1/A-9 REACTOR BLDG HIGH RAD
- 1. Evacuate plant personnel from the area Attempt to isolate HPCI.
BOP Report to CRS that HPCI will not Isolate.
Send NLO to ASD Room to Isolate HPCI.
If sent to the ASD Room to attempt to isolate HPCI:
Override Alarm 9-3-3/G-5 ASD ROOM DOOR OPEN to ON Booth Then Override Alarm 9-3-3/F-5, ASD SWITCH POSITION ABNORMAL Operator to ON Then report you can NOT get control of the valves from the ASD Room.
DELETE the overrides on the alarms.
Enter 5.1RAD and 2.4OG on notification of High Reactor Bldg. Radiation.
CRS Direct actions.
Enter EOP1A and direct a reactor Scram.
With a primary system discharging into secondary containment Critical through an un-isolable break, SCRAM the reactor per EOP 5A and EOP Task 1A prior to commencing Emergency Depressurization.
Page 15 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 6 Event
Description:
LOCA - Steam line break into Secondary Containment Time Position Applicants Action or Behavior Perform Scram actions using procedure 2.1.5 Attachment 1.
Perform Attachment 1 mitigating task scram actions of 2.1.5 as follows:
1.2 Place REACTOR MODE switch to REFUEL.
1.3 IF reactor power > 3%, THEN perform following:
1.3.1 Place REACTOR MODE switch to SHUTDOWN.
1.3.2 Initiate ARI.
Perform Attachment 2 Reactor Power Control of 2.1.5 as follows:
1 REACTOR POWER CONTROL 1.1 Ensure REACTOR MODE switch is in SHUTDOWN.
ATC 1.2 Verify all SDV vent and drain valves are closed.
NOTE - RR pump(s) will be tripped if on Normal Transformer or if ARI/RPT has automatically initiated.
1.3 Ensure operating RR pumps have run back to 22% speed.
NOTE - Steps 1.4 and 1.5 may be performed concurrently.
1.4 Verify all control rods are fully inserted.
1.4.1 If necessary, insert control rods as directed by CRS.
1.5 Observe nuclear instrumentation and perform following:
1.5.1 Insert SRM detectors.
1.5.2 Insert IRM detectors.
1.5.3 Change APRM recorders to IRMs.
Page 16 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 6 Event
Description:
LOCA - Steam line break into Secondary Containment Time Position Applicants Action or Behavior 1.5.4 Range IRMs on scale.
Check reactor power is lowering.
Perform action of 5.1RAD, BUILDING RADIATION TROUBLE 4.2 Notify Plant personnel to clear affected area via gaitronics.
Perform actions of 2.4OG, OFF-GAS ABNORMAL Verify automatic actions
- 2. AUTOMATIC ACTIONS 2.1 Standby off-gas dilution fan starts on low dilution flow.
2.2 A 5 minute time delay on low dilution flow or 15 minutes of continuous Alarm 9-4-1/C-4, OFFGAS TIMER INITIATED, causes an off-gas isolation signal.
2.3 An off-gas isolation signal causes following:
2.3.1 OG-AO-254, OG SYSTEM ISOLATION, closes.
2.3.2 AOG-AO-902, AOG RETURN, closes.
NOTE - 50 to 60 psig on AR-12AV and OG-13AV air regulators indicates BOP valves closed.
2.3.3 OG-AO-13, OFF-GAS FILTERS A & B DRAIN, closes.
2.3.4 AR-AO-12, 30 MINUTE HOLDUP PIPE DRAIN, closes.
2.3.5 OWC Injection System trips.
- 3. NA
- 4. Subsequent Actions:
4.1 Record date and time.
4.2 NA 4.3 IF off-gas isolation has occurred, THEN place OWC-SW-ENABLE, OWC INJECTION SYS ENABLE, to SHUTDOWN (PANEL A).
4.3.1 Complete securing OWC Injection System per Procedure 2.2.98 when conditions permit.
4.4 Concurrently perform Attachment 1, Off-Gas System High Radiation Attachment 1
- 1. OFF-GAS SYSTEM HIGH RADIATION:
Page 17 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 6 Event
Description:
LOCA - Steam line break into Secondary Containment Time Position Applicants Action or Behavior 1.1 Lower reactor power per Procedure 2.1.10 to prevent off-gas timer from timing out or to clear Annunciator 9-4-1/C-4, OFFGAS TIMER INITIATED.
1.2 IF off-gas isolation is immediately desired, THEN at Panel 9-02, place OFFGAS TIMER switch to CLOSE.
1.3 IF fuel cladding has not been confirmed lost per EPIP 5.7.1, Emergency Classification, THEN request Chemistry obtain isotopic analysis of off-gas stream.
1.4 IF Off-Gas System automatically isolates or is manually isolated due to high-high radiation, THEN:
1.4.1 SCRAM and enter Procedure 2.1.5.
1.4.2 Close MSIVs and MSIV drains.
1.4.3 Ensure OFFGAS TIMER switch on Panel 9-02 is in CLOSE.
1.4.4 Ensure following valves are closed:
1.4.4.1 RHR-920MV, AOG STEAM SUPPLY VALVE (PNL 9-3).
1.4.4.2 RHR-1485MV, AOG STEAM BYP THROTTLE VLV (PNL 9-3).
1.4.4.3 RHR-921MV, AOG STEAM SUPPLY VALVE (PNL 9-3).
1.4.4.4 AOG-AO-902, AOG RETURN (VBD-K).
1.4.4.5 OG-AO-254, OFFGAS SYSTEM ISOLATION (VBD-K).
1.4.5 Remove SJAEs from service per Procedure 2.2.55.
1.4.6 Ensure gland steam exhauster running.
1.4.7 NA 1.4.8 NA 1.4.9 NA 1.4.10 Monitor ERP gas activity levels.
END OF EVENT Notes The next event is a continuation of the current event.
Page 18 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 7 Event
Description:
Emergency Depressurization (>2 above Max Safe) EOP-2A Time Position Applicants Action or Behavior NOTE to Examiners: This event is a continuation of the previous event.
Enter 5.2FUEL and direct actions as follows:
4.6 IF valid MAIN STM LINE HI HI RAD (9-4-1/A-4) alarm is actuated and reactor is shut down, THEN close MSIVs and MSL drain valves.
CRS 4.7 Direct Chemistry to sample reactor coolant activity.
4.8 Notify Reactor Engineering and follow their recommendations per Procedure 10.31.
BOP Close MSIVs and MSL Drains With a primary system discharging into secondary containment through an un-isolable break, execute Emergency Depressurization Critical when Maximum Safe Operating Values are exceeded in two or more Task areas for the same parameter per EOP2A prior to exceeding 312°F anywhere in the reactor building.
EOP1A When CRS determines the second containment area temperature is going to CRS exceed MAX SAFE temperature of 195°F, ANTICIPATE Emergency Depressurization and direct BOP to fully open main turbine bypass valves.
When directed fully open main turbine bypass valves per Hard Card. (Panel B DEH HMI)
3.2 Press MANUAL button and check it backlights yellow.
3.3 On BYPASS VALVE POSITION control, use UP/DOWN, JOG UP/JOG DOWN and FAST/SLOW controls to adjust BYPASS Page 19 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 7 Event
Description:
Emergency Depressurization (>2 above Max Safe) EOP-2A Time Position Applicants Action or Behavior VALVE POSITION to desired value.
BEFORE any 2 secondary containment parameters reach their maximum safe operating value:
- Temperatures (TABLE 9)
- Radiation (TABLE 10)
- Water levels (TABLE 11) with a primary system discharging into secondary containment Emergency Depressurize the reactor.
EOP 2A (RC/P-12)
Rapidly depressurize RPV (disregard cooldown rate)
CRS (RC/P-13) NA (RC/P-14)
WHEN shutdown cooling RPV pressure interlock clears (70 psig) AND further cooldown is required (RC/P-15)
Cool down to cold shutdown conditions with shutdown cooling (use only RHR pumps not required to maintain RPV water level above +3 in.)
CRS Request torus water level before ordering SRVs opened for emergency depressurization.
Report torus water level to CRS.
BOP Open 6 SRVs with control switches.
BOP Report RPV pressure as it lowers.
Restore RPV Level using Low Pressure ECCS Systems (RHR, Core Spray)
BOP to normal range.
Page 20 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 7 Event
Description:
Emergency Depressurization (>2 above Max Safe) EOP-2A Time Position Applicants Action or Behavior END OF EVENT Notes Proceed to the next event at direction of the lead examiner.
Page 21 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 8 Event
Description:
Reactor Feedpump fails to trip on high level Time Position Applicants Action or Behavior NOTE to Examiners: Following Emergency Depressurization reactor water level will swell resulting in a Reactor Feed Pump (RFP) Trip setpoint and the RFP will not trip automatically. RPV overfill results if the RFP is not tripped.
Recognizes that reactor water level has exceeded the trip setpoint for the ATC running reactor Feedpump and the reactor Feedpump should have tripped.
Press TURBINE TRIP pushbutton on benchboard A.
When requested to investigate the Reactor Feedpump for reasons it Booth may not have tripped when required, respond that there is nothing Operator abnormal around the Reactor Feedpump.
Acknowledges the Reactor Feedpump did not trip automatically and it has been manually tripped.
CRS Directs the BOP Operator to maintain reactor water level using ECCS Systems.
BOP Maintains Reactor Water Level using Core Spray, and/or RHR.
END OF EVENT Notes The next event is already active.
Page 22 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 9 Event
Description:
SGT Fans A & B fail to auto start Time Position Applicants Action or Behavior NOTE to Examiners: Malfunctions PC18a and PC18b, SGT Fans Fail to Auto Start are ACTIVE. (Reactor Building exhaust plenum radiation level become high and it is imperative to filter the release.
Recognizes the SGT fan failed to auto start upon a group 6 isolation signal and SGT inlet valves SGT-AO-249 (250) and outlet valves SGT-AO-251 (252) did not auto open.
Informs CRS that SGT fans did not start.
BOP Places the Fan Control Switches to RUN to start both Fans.
Ensures both Inlet and Outlet valves open following start of fans.
Directs BOP to place the SGT Fan switches to RUN and ensure system is CRS maintaining negative pressure in the reactor building.
Booth If requested to investigate the SGT Fans for reasons they may not Operator have started, respond you will notify maintenance to investigate.
END OF EVENT Notes Page 23 of 27
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: 1 Scenario No.: 3 Event No.: 9 Event
Description:
SGT Fans A & B fail to auto start Time Position Applicants Action or Behavior When the RPV has been depressurized and RPV level is has been restored within band, stop the scenario as directed by the lead examiner.
END OF SCENARIO Page 24 of 27
Appendix D Required Operator Actions Form ES-D-2 Simulator Setup Initialize the simulator in IC 10 (BOL) (Protected IC 233)
Triggers and Malfunctions E4 - SW01d, Trip, Service Water Pump D trip E1 - RD03d, Severity 22%, Control rod 18-39 drifts in.
E3 - HP05, Inadvertent initiation CR01, TD 5:00, Severity 1%
CR03, TD 6:00, Severity 100%, Ramp 10:00 minutes HP06, HPCI steam line break, Severity 5%, Ramp 10:00 minutes E6 - NM05b, IRM B power supply failure PC18a (Active) Standby Gas Treatment train A failure to start.
PC18b (Active) Standby Gas Treatment train B failure to start.
FW28a and FW28b (Active), RFP fails to trip on high water level.
HP09 (Active) HPCI fails to automatically isolate.
HP15 (Active) HPCI fails to automatically isolate on low steam supply pressure.
Overrides
- zdihpcisws2[2] Control Switch for HPCI-MO-16, OPEN (Active)
- zdihpcisws1[2] Control Switch for HPCI-MO-15, OPEN (Active)
- zdihpciswmo15[2] Control Switch for HPCI-MO-15 (ASD ROOM), OPEN (Active)
- zdihpciswmo16[2] Control Switch for HPCI-MO-16 (ASD ROOM), OPEN (Active)
- zdihpcisws32[1] HPCI Manual Isolation Switch, OFF (Active)
- an:p1641, HPCI LOGIC INITITATED Alarm, OFF(Active)
Panel Set-up
- Ensure the following breakers are in Normal After Trip position:
- a. 1CN
- b. 1DN
- c. 1AN
- d. 1BN
- Place the Breakers must be cycled tags on the following breakers:
- e. 1CN
- f. 1DN
- g. 1AN
- h. 1BN
- Place PC-PIC-513 in manual and shut and lower Containment Pressure to 0.
Page 25 of 27
Appendix D Required Operator Actions Form ES-D-2 Procedures Needed
- Procedure 2.1.1 (2 Copies) with steps 4.22 and 5.3.6 completed.
- Procedure 2.2.77, Attachment 1, Step 1.14 complete.
- Procedure 2.2.28.1 Step 5.14 completed.
Tags Hung
- Mark up boards and ensure tag reflects CREF is on Division I.
Parameter Monitoring:
Monitor RPV Pressure, Average Torus Water Temperature and Torus Water Level (HCTL
&BIIT)
Page 26 of 27
Appendix D Required Operator Actions Form ES-D-2 Turnover Sheet:
Plant Status: The plant is at 4% reactor power during a startup following refueling. Procedure 2.1.1, Steps 4.22 and 5.36 are completed, 2.2.77 Attachment 1, Step 1.14 is complete, 2.2.28.1 Step 5.14 is complete, LCOs and Logs are complete for change to MODE 1.
Fuel is being de-channeled on the refueling floor, Reactor Coolant samples (1xE-3 Micro-Curies / CC) indicate higher than normal gross activity level for this point in a startup. Site Management and Reactor Engineering have indicated the startup can continue normally. Continue plant startup.
Risk: Green Activities in Progress: Lately irradiated fuel is being de-channeled on the refueling floor.
LCOs in effect: No Tech Specs Limitations in effect.
Equipment out of service: None Activities for the Shift: Continue plant startup.
Page 27 of 27
ES-301 Transient and Event Checklist Form ES-301-5 Facility: Cooper Nuclear Station Date of Exam: 7/28/2014 Operating Test No.: 1 A E Scenarios P V 1 2 3 4 T M P E O I L N CREW CREW CREW CREW T N I T POSITION POSITION POSITION POSITION A I
M C S A B S A B S A B S A B L U A T R T O R T O R T O R T O M(*)
N Y O C P O C P O C P O C P R I U T P E
RO-1 RX 3 1 1 1 0 X
SRO-I NOR 0 1 1 1 I/C 5, 8, 3, 5, 6 4 4 2 SRO-U 9 9 MAJ 9 6, 7 3 2 2 1 TS N/A 0 2 2 RX 1, 6 2 1 1 0 RO -2 X NOR 2, 4 2 1 1 1 SRO-I I/C 1, 6, 7, 2, 4, 7 4 4 2 10 8 SRO-U MAJ 9 6 2 2 2 1 TS N/A 0 2 2 RO-3 RX 3 1 1 1 0 X
SRO-I NOR 0 1 1 1 I/C 5, 8, 3, 5, 6 4 4 2 SRO-U 9 9 MAJ 9 6, 7 3 2 2 1 TS N/A 0 2 2 RO-4 RX 1, 6 2 1 1 0 X
SRO-I NOR 2, 4 2 1 1 1 I/C 1, 6, 7, 2, 4, 7 4 4 2 SRO-U 10 8 MAJ 9 6 2 2 2 1 TS N/A 0 2 2 Rev 2 (6/29/14)
Instructions:
- 1. Check the applicant level and enter the operating test number and Form ES-D-1 event numbers for each event type; TS are not applicable for RO applicants. ROs must serve in both the at-the-controls (ATC) and balance-of-plant (BOP) positions; Instant SROs must serve in both the SRO and the ATC positions, including at least two instrument or component (I/C) malfunctions and one major transient, in the ATC position. If an Instant SRO additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.
- 2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a 1-for-1 basis.
- 3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicants competence count toward the minimum requirements specified for the applicants license level in the right-hand columns.
Rev 2 (6/29/14)
ES-301 Transient and Event Checklist Form ES-301-5 Facility: Cooper Nuclear Station Date of Exam: 7/28/2014 Operating Test No.: 1 A E Scenarios P V 1 2 3 4 T M P E O I L N CREW CREW CREW CREW T N I T POSITION POSITION POSITION POSITION A I
M C S A B S A B S A B S A B L U A T R T O R T O R T O R T O M(*)
N Y O C P O C P O C P O C P R I U T P E
RO-5 RX 1, 6 2 1 1 0 X
SRO-I NOR 2, 4 2 1 1 1 I/C 1, 6, 7, 2, 4, 7 4 4 2 SRO-U 10 8 MAJ 9 6 2 2 2 1 TS N/A 0 2 2 RX 3 1, 6 3 1 1 0 RO NOR 0 1 1 1 I/C 5, 8, 2, 3, 9 4 4 2 SRO-I-1 9 4, 5, X 8, 9 SRO-U MAJ 9 6, 7 3 2 2 1 TS 2, 3, 3 0 2 2 4
RO RX 3 1 1 1 0 NOR 2, 4 2 1 1 1 SRO-I I/C 1, 5, 6 4 4 2 6, 7, SRO-U-1 8, 10 X
MAJ 9 1 2 2 1 TS 1, 4, 3 0 2 2 6,
RO RX 3 1 1 1 0 NOR 2, 4 2 1 1 1 SRO-I I/C 1, 5, 6 4 4 2 6, 7, SRO-U-2 8, 10 X
MAJ 9 1 2 2 1 TS 1, 4, 3 0 2 2 6
Rev 2 (6/29/14)
Instructions:
- 1. Check the applicant level and enter the operating test number and Form ES-D-1 event numbers for each event type; TS are not applicable for RO applicants. ROs must serve in both the at-the-controls (ATC) and balance-of-plant (BOP) positions; Instant SROs must serve in both the SRO and the ATC positions, including at least two instrument or component (I/C) malfunctions and one major transient, in the ATC position. If an Instant SRO additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.
- 2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a 1-for-1 basis.
- 3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicants competence count toward the minimum requirements specified for the applicants license level in the right-hand columns.
Rev 2 (6/29/14)
ES-301 Transient and Event Checklist Form ES-301-5 Facility: Cooper Nuclear Station Date of Exam: 7/28/2014 Operating Test No.: 1 A E Scenarios P V 1 2 3 4 T M P E O I L N CREW CREW CREW CREW T N I T POSITION POSITION POSITION POSITION A I
M C S A B S A B S A B S A B L U A T R T O R T O R T O R T O M(*)
N Y O C P O C P O C P O C P R I U T P E
RO RX 3 1 1 1 0 NOR 2, 4 2 1 1 1 SRO-I I/C 1, 5, 6 4 4 2 6, 7, SRO-U-3 8, 10 X
MAJ 9 1 2 2 1 TS 1, 4, 3 0 2 2 6
RO RX 1 1 0 NOR 1 1 1 SRO-I I/C 4 4 2 SRO-U MAJ 2 2 1 TS 0 2 2 RO RX 1 1 0 NOR 1 1 1 SRO-I I/C 4 4 2 SRO-U MAJ 2 2 1 TS 0 2 2 RO RX 1 1 0 NOR 1 1 1 SRO-I I/C 4 4 2 SRO-U MAJ 2 2 1 TS 0 2 2 Rev 2 (6/29/14)
Instructions:
- 1. Check the applicant level and enter the operating test number and Form ES-D-1 event numbers for each event type; TS are not applicable for RO applicants. ROs must serve in both the at-the-controls (ATC) and balance-of-plant (BOP) positions; Instant SROs must serve in both the SRO and the ATC positions, including at least two instrument or component (I/C) malfunctions and one major transient, in the ATC position. If an Instant SRO additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.
- 2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a 1-for-1 basis.
- 3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicants competence count toward the minimum requirements specified for the applicants license level in the right-hand columns.
Rev 2 (6/29/14)
ES-301 Competencies Checklist Form ES-301-6 Facility: CNS Date of Examination: 7/28/2014 Operating Test No.: 1 APPLICANTS RO-1 X RO-2 X RO-3 X RO-4 X SRO-I SRO-I SRO-I SRO-I SRO-U SRO-U SRO-U SRO-U Competencies SCENARIO SCENARIO SCENARIO SCENARIO 1 2 3 4 1 2 3 4 1 2 3 4 1 2 3 4 Interpret/Diagnose 5,8, 9 3,5,6,7 1,4,6,7, 2,4,7 5,8, 9 3,5,6,7 1,4,6,7, 2,4,7 8,9 9, 10 8,9 9, 10 Events and Conditions Comply With and 3,5,8,9 3,5,6,7 1,2,4,6, 2,4,6,7 3,5,8, 3,5,6,7 1,2,4,6, 2,4,6,7 8,9 7,9,10 9 8,9 7,9,10 Use Procedures (1)
Operate Control 3,5,8,9 3,5,6,7 1,2,4,6, 1,2,4,7 3,5,8, 3,5,6,7 1,2,4,6, 1,2,4,6 8,9 7,9,10 9 8,9 7,9,10 7 Boards (2)
Communicate 1-10 1-9 1-10 1-9 1-10 1-9 1-10 1-9 and Interact Demonstrate Supervisory Ability (3)
Comply With and Use Tech. Specs. (3)
Notes:
(1) Includes Technical Specification compliance for an RO.
(2) Optional for an SRO-U.
(3) Only applicable to SROs.
Instructions:
Check the applicants license type and enter one or more event numbers that will allow the examiners to evaluate every applicable competency for every applicant.
Rev 2 (6/29/14)
ES-301 Competencies Checklist Form ES-301-6 Facility: CNS Date of Examination: Operating Test No.: 1 APPLICANTS RO-5 X RO RO RO SRO-I SRO-I-1 X SRO-I SRO-I SRO-U SRO-U SRO-U-1 X SRO-U-2 X Competencies SCENARIO SCENARIO SCENARIO SCENARIO 1 2 3 4 1 2 3 4 1 2 3 4 1 2 3 4 Interpret/Diagnose 1,4,6,7, 2,4,7 5,8,9 2,3.],4, 1,5,6,7 1,5,6,7, 9, 10 5,6,7 ,8,9 8,9 Events and Conditions Comply With and 1,2,4,6, 2,4,6,7 3,5,8,9 1-9 1-10 1-10 7,9,10 Use Procedures (1)
Operate Control 1,2,4,6, 1,2,4,6, 3,5,8,9 7,9,10 7 Boards (2)
Communicate 1-10 1-9 1-10 1-9 1-10 1-10 and Interact Demonstrate 1-9 1-10 1-10 Supervisory Ability (3)
Comply With and 2,3,4 1,4,6 1,4,6 Use Tech. Specs. (3)
Notes:
(1) Includes Technical Specification compliance for an RO.
(2) Optional for an SRO-U.
(3) Only applicable to SROs.
Instructions:
Check the applicants license type and enter one or more event numbers that will allow the examiners to evaluate every applicable competency for every applicant.
Rev 2 (6/29/14)
ES-301 Competencies Checklist Form ES-301-6 Facility: CNS Date of Examination: Operating Test No.: 1 APPLICANTS RO RO RO RO SRO-I SRO-I SRO-I SRO-I SRO-U-3 X SRO-U SRO-U SRO-U Competencies SCENARIO SCENARIO SCENARIO SCENARIO 1 2 3 4 1 2 3 4 1 2 3 4 1 2 3 4 Interpret/Diagnose 1,5,6, 7,8,9 Events and Conditions Comply With and 1-10 Use Procedures (1)
Operate Control Boards (2)
Communicate 1-10 and Interact Demonstrate 1-10 Supervisory Ability (3)
Comply With and 1,4,6 Use Tech. Specs. (3)
Notes:
(1) Includes Technical Specification compliance for an RO.
(2) Optional for an SRO-U.
(3) Only applicable to SROs.
Instructions:
Check the applicants license type and enter one or more event numbers that will allow the examiners to evaluate every applicable competency for every applicant.
Rev 2 (6/29/14)