ML051230435: Difference between revisions

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| number = ML051230435
| number = ML051230435
| issue date = 03/25/2005
| issue date = 03/25/2005
| title = Comanche Peak-03-2005-Final-Operating Exam
| title = 03-2005-Final-Operating Exam
| author name =  
| author name =  
| author affiliation = NRC/RGN-IV/DRS/OB
| author affiliation = NRC/RGN-IV/DRS/OB
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Current Value 1/1-PCPR1 Amps 580 580 1/1-PCPR Amps 0 200 1/1-PCPR2 Amps 565 565 1/1P-CPR3 Amps 0 176 1B1 Volts 474 468 1B2 Volts 483 476 1B3 Volts 476 470 1B4 Volts 485 480 PC point V6303A 487.2 486.9 PC point V6302A 488.1 487.1 PC point V6301A 487.2 486.9 PC point V6304A 488.3 487.1 PC point A6801A 571.2 570.1 PC point A6802A 0 193 PC point A6803A 559.8 560 PC point A6804A 0 176 1EA1 Amps 282.7 261.4 1EA2 Amps 358.5 423.7  NOTE: The candidate can use either the MCB meter amperages or the plant computer values for heater amperages. The IPO allows both and there is no significant difference.
Current Value 1/1-PCPR1 Amps 580 580 1/1-PCPR Amps 0 200 1/1-PCPR2 Amps 565 565 1/1P-CPR3 Amps 0 176 1B1 Volts 474 468 1B2 Volts 483 476 1B3 Volts 476 470 1B4 Volts 485 480 PC point V6303A 487.2 486.9 PC point V6302A 488.1 487.1 PC point V6301A 487.2 486.9 PC point V6304A 488.3 487.1 PC point A6801A 571.2 570.1 PC point A6802A 0 193 PC point A6803A 559.8 560 PC point A6804A 0 176 1EA1 Amps 282.7 261.4 1EA2 Amps 358.5 423.7  NOTE: The candidate can use either the MCB meter amperages or the plant computer values for heater amperages. The IPO allows both and there is no significant difference.
NOTE:  The shaded parameters should NOT be used. The following problems exist with the shaded data:  1. The pressurizer heaters are supplied by 1EB1-4, NOT 1B1-4 2. 1EA1/2 amperage is not necessary to complete the calculations. 3. Data from the last set of logs should NOT be used for the Operability determination. Plant conditions could have changed significantly si nce the readings were taken. The IPO wants current plant data to determine Operability.
NOTE:  The shaded parameters should NOT be used. The following problems exist with the shaded data:  1. The pressurizer heaters are supplied by 1EB1-4, NOT 1B1-4 2. 1EA1/2 amperage is not necessary to complete the calculations. 3. Data from the last set of logs should NOT be used for the Operability determination. Plant conditions could have changed significantly si nce the readings were taken. The IPO wants current plant data to determine Operability.
Initial License Exam                      03/2005 Job Performance Measure JPM: SRO/RO A1.a KEY  Page 5 of 5 Rev Date: 1/19/05 Circle the correct status for each Bank of Pressurizer Heaters Heater Bank Status Status B/U Heater Grp. A Operable Inoperable B/U Heater Grp. B Operable Inoperable Control Grp. C Operable Inoperable B/U Heater Grp. D Operable Inoperable Example of the completed procedure:  
Initial License Exam                      03/2005 Job Performance Measure JPM: SRO/RO A1.a KEY  Page 5 of 5 Rev Date: 1/19/05 Circle the correct status for each Bank of Pressurizer Heaters Heater Bank Status Status B/U Heater Grp. A Operable Inoperable B/U Heater Grp. B Operable Inoperable Control Grp. C Operable Inoperable B/U Heater Grp. D Operable Inoperable Example of the completed procedure:
 
5.3 Heatup And Pressurization For MODE 3 Entry
===5.3 Heatup===
And Pressurization For MODE 3 Entry  
[C] This section describes steps for heatup and pressurization to enter MODE 3. 5.3.1 Verify at least two groups of pressurizer heaters have a capacity of at least 150KW each.(TS SR 3.4.9.2)  A. Energize each group of heaters, as required, to measure current.                        _____
[C] This section describes steps for heatup and pressurization to enter MODE 3. 5.3.1 Verify at least two groups of pressurizer heaters have a capacity of at least 150KW each.(TS SR 3.4.9.2)  A. Energize each group of heaters, as required, to measure current.                        _____
B. Record voltage and current AND calculate power for each group of heaters.                    (Voltage x current x 0.001732 = power)
B. Record voltage and current AND calculate power for each group of heaters.                    (Voltage x current x 0.001732 = power)
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Initial License Exam                      03/2005 Job Performance Measure JPM: RO A1.b KEY  Page 6 of 8 Rev Date: 1/24/05 CPSES ABNORMAL CONDITIONS PROCEDURES MANUAL UNIT 1 AND 2 PROCEDURE NO.
Initial License Exam                      03/2005 Job Performance Measure JPM: RO A1.b KEY  Page 6 of 8 Rev Date: 1/24/05 CPSES ABNORMAL CONDITIONS PROCEDURES MANUAL UNIT 1 AND 2 PROCEDURE NO.
ABN-103  EXCESSIVE REACTOR COOLANT LEAKAGE REVISION NO 8 PAGE 22 OF 28 ATTACHMENT 1 PAGE 2 OF 2 PARAMETER INITIAL VALUE FINAL VALUE AVERAGE VALUE TIME  (-) ___1258___ + ____1312____ = ____14___ t
ABN-103  EXCESSIVE REACTOR COOLANT LEAKAGE REVISION NO 8 PAGE 22 OF 28 ATTACHMENT 1 PAGE 2 OF 2 PARAMETER INITIAL VALUE FINAL VALUE AVERAGE VALUE TIME  (-) ___1258___ + ____1312____ = ____14___ t
* CHRG FLO (F6138A)  ___141.5____ + ___131.2____  
* CHRG FLO (F6138A)  ___141.5____ + ___131.2____
(____________286.6____________) 2  = __143.3__ GPM
(____________286.6____________) 2  = __143.3__ GPM
* LTDN HX OUT FLOW (F6134A) ____130.89___ + ___130.93___  
* LTDN HX OUT FLOW (F6134A) ____130.89___ + ___130.93___
(___________261.82____________) 2  = __130.91__ GPM
(___________261.82____________) 2  = __130.91__ GPM
* RCP SEAL LKOFF FLO (FR-157, 156, 155  
* RCP SEAL LKOFF FLO (FR-157, 156, 155  
& 154) __2.8____ + ____2.8___  
& 154) __2.8____ + ____2.8___
(____________5.6______________.) 2  = ____2.8__ GPM
(____________5.6______________.) 2  = ____2.8__ GPM
* VCT LVL (L6112A)  (________ - ________)(19.4gal/%)  
* VCT LVL (L6112A)  (________ - ________)(19.4gal/%)
(________________________________) (__________)t in MIN)  
(________________________________) (__________)t in MIN)  
   = _________ GPM RC LOOP 1-4 TAVE (T0400A,T0420A,T0440A OR T0460A)  
   = _________ GPM RC LOOP 1-4 TAVE (T0400A,T0420A,T0440A OR T0460A)
(__589.2__ - __588.6__)(93gal/°F)  
(__589.2__ - __588.6__)(93gal/°F)
(________55.8________________) (___14___)t in MIN)  
(________55.8________________) (___14___)t in MIN)  
   = ___3.98__ GPM PRZR LVL (L6480A,L6481A OR L6482A)  (_59.58___ - __56.6___)(65gal/%)  
   = ___3.98__ GPM PRZR LVL (L6480A,L6481A OR L6482A)  (_59.58___ - __56.6___)(65gal/%)
(_________193.7_______________) (__14____)t in MIN)  
(_________193.7_______________) (__14____)t in MIN)  
   = __13.84__ GPM CALCULATION FORMULA Flow adjust method: (+) _143.3__
   = __13.84__ GPM CALCULATION FORMULA Flow adjust method: (+) _143.3__
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Initial License Exam                      03/2005 Job Performance Measure JPM: RO A1.b KEY  Page 8 of 8 Rev Date: 1/24/05 CPSES ABNORMAL CONDITIONS PROCEDURES MANUAL UNIT 1 AND 2 PROCEDURE NO.
Initial License Exam                      03/2005 Job Performance Measure JPM: RO A1.b KEY  Page 8 of 8 Rev Date: 1/24/05 CPSES ABNORMAL CONDITIONS PROCEDURES MANUAL UNIT 1 AND 2 PROCEDURE NO.
ABN-103  EXCESSIVE REACTOR COOLANT LEAKAGE REVISION NO 8 PAGE 22 OF 28 ATTACHMENT 1 PAGE 2 OF 2 PARAMETER INITIAL VALUE FINAL VALUE AVERAGE VALUE TIME  (-) __1429____ + __1446____ = ____17___ t
ABN-103  EXCESSIVE REACTOR COOLANT LEAKAGE REVISION NO 8 PAGE 22 OF 28 ATTACHMENT 1 PAGE 2 OF 2 PARAMETER INITIAL VALUE FINAL VALUE AVERAGE VALUE TIME  (-) __1429____ + __1446____ = ____17___ t
* CHRG FLO (F6138A)  __140.7____ + ___143.8___  
* CHRG FLO (F6138A)  __140.7____ + ___143.8___
(__________284.5____________) 2  = __142.25___ GPM
(__________284.5____________) 2  = __142.25___ GPM
* LTDN HX OUT FLOW (F6134A) ___130.9__ + ___130.9___  
* LTDN HX OUT FLOW (F6134A) ___130.9__ + ___130.9___
(__________261.8______________) 2  = __130.9__ GPM
(__________261.8______________) 2  = __130.9__ GPM
* RCP SEAL LKOFF FLO (FR-157, 156, 155  
* RCP SEAL LKOFF FLO (FR-157, 156, 155  
& 154) ___2.8______ + ____2.8____  
& 154) ___2.8______ + ____2.8____
(___________5.6______________
(___________5.6______________
.) 2  = ___2.8___ GPM
.) 2  = ___2.8___ GPM
* VCT LVL (L6112A)  (_52.8___ - __50.4___)(19.4gal/%)  
* VCT LVL (L6112A)  (_52.8___ - __50.4___)(19.4gal/%)
(_________46.56__________________) (__17____)t in MIN)  
(_________46.56__________________) (__17____)t in MIN)  
   = __2.74___ GPM RC LOOP 1-4 TAVE (T0400A,T0420A,T0440A OR T0460A)  
   = __2.74___ GPM RC LOOP 1-4 TAVE (T0400A,T0420A,T0440A OR T0460A)
(________ - ________)(93gal/°F)  
(________ - ________)(93gal/°F)
(_____________0__________________) (_____17_____)t in MIN)  
(_____________0__________________) (_____17_____)t in MIN)  
   = ____0___ GPM PRZR LVL (L6480A,L6481A OR L6482A)  (_60___ - ___59.5__)(65gal/%)  
   = ____0___ GPM PRZR LVL (L6480A,L6481A OR L6482A)  (_60___ - ___59.5__)(65gal/%)
(_________32.5___________________) (__17_____)t in MIN)  
(_________32.5___________________) (__17_____)t in MIN)  
   = ___1.9___ GPM Shaded areas NOT REQUIRED CALCULATION FORMULA Flow adjust method: (+) ________
   = ___1.9___ GPM Shaded areas NOT REQUIRED CALCULATION FORMULA Flow adjust method: (+) ________
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  -KEY-  Page 4 of 5 Rev Date: 2/7/05 INITIATING CUE:
  -KEY-  Page 4 of 5 Rev Date: 2/7/05 INITIATING CUE:
You are on tour in the Safeguards Building. The US directs you to isolate the air to HV-8152. You are to evaluate the radiological condition in the area and provide the requested information.
You are on tour in the Safeguards Building. The US directs you to isolate the air to HV-8152. You are to evaluate the radiological condition in the area and provide the requested information.
NOTE: Circle the correct answers to the following questions and provide the evaluator with your completed paperwork.  
NOTE: Circle the correct answers to the following questions and provide the evaluator with your completed paperwork.
: 1. The area where the valve is located is a:
: 1. The area where the valve is located is a:
A) Locked High Radiation Area B) Contaminated Area C) Posted High Radiation Area D) General Radiation Area  
A) Locked High Radiation Area B) Contaminated Area C) Posted High Radiation Area D) General Radiation Area
: 2. If the area where the air isolation valve is located is a 60 mr/hr field, how long before your dosimeter will alarm if it is at the lower setting allowed by the GAP.
: 2. If the area where the air isolation valve is located is a 60 mr/hr field, how long before your dosimeter will alarm if it is at the lower setting allowed by the GAP.
A) Immediately B) 5 minutes C) 25 minutes D) 2.5 minutes  
A) Immediately B) 5 minutes C) 25 minutes D) 2.5 minutes
: 3. Circle three areas on the Survey Map that require contact with RP prior to entry.  
: 3. Circle three areas on the Survey Map that require contact with RP prior to entry.  


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-KEY-  INITIATING CUE:
-KEY-  INITIATING CUE:
You are on tour in the Safeguards Building. The US directs you to isolate the air to HV-8152. You are to evaluate the radiological condition in the area and provide the requested information.
You are on tour in the Safeguards Building. The US directs you to isolate the air to HV-8152. You are to evaluate the radiological condition in the area and provide the requested information.
NOTE: Circle the correct answers to the following questions and provide the evaluator with your completed paperwork.  
NOTE: Circle the correct answers to the following questions and provide the evaluator with your completed paperwork.
: 1. The area where the valve is located is a:
: 1. The area where the valve is located is a:
E) Locked High Radiation Area F) Contaminated Area G) Posted High Radiation Area H) General Radiation Area  
E) Locked High Radiation Area F) Contaminated Area G) Posted High Radiation Area H) General Radiation Area
: 2. If the area where the air isolation valve is located is a 60 mr/hr field, how long before your dosimeter will alarm if it is at the lower setting allowed by the GAP.
: 2. If the area where the air isolation valve is located is a 60 mr/hr field, how long before your dosimeter will alarm if it is at the lower setting allowed by the GAP.
E) Immediately F) 5 minutes G) 25 minutes H) 2.5 minutes  
E) Immediately F) 5 minutes G) 25 minutes H) 2.5 minutes
: 3. Circle three areas on the Survey Map that require contact with RP prior to entry.  
: 3. Circle three areas on the Survey Map that require contact with RP prior to entry.
: 1) High Radiation area where the valve to be operated is. 2) The CA I/S Pit 3) Platform on the south end of the room.  
: 1) High Radiation area where the valve to be operated is. 2) The CA I/S Pit 3) Platform on the south end of the room.  


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Current Value 1/1-PCPR1 Amps 580 580 1/1-PCPR Amps 0 200 1/1-PCPR2 Amps 565 565 1/1P-CPR3 Amps 0 176 1B1 Volts 474 468 1B2 Volts 483 476 1B3 Volts 476 470 1B4 Volts 485 480 PC point V6303A 487.2 486.9 PC point V6302A 488.1 487.1 PC point V6301A 487.2 486.9 PC point V6304A 488.3 487.1 PC point A6801A 571.2 570.1 PC point A6802A 0 193 PC point A6803A 559.8 560 PC point A6804A 0 176 1EA1 Amps 282.7 261.4 1EA2 Amps 358.5 423.7  NOTE: The candidate can use either the MCB meter amperages or the plant computer values for heater amperages. The IPO allows both and there is no significant difference.
Current Value 1/1-PCPR1 Amps 580 580 1/1-PCPR Amps 0 200 1/1-PCPR2 Amps 565 565 1/1P-CPR3 Amps 0 176 1B1 Volts 474 468 1B2 Volts 483 476 1B3 Volts 476 470 1B4 Volts 485 480 PC point V6303A 487.2 486.9 PC point V6302A 488.1 487.1 PC point V6301A 487.2 486.9 PC point V6304A 488.3 487.1 PC point A6801A 571.2 570.1 PC point A6802A 0 193 PC point A6803A 559.8 560 PC point A6804A 0 176 1EA1 Amps 282.7 261.4 1EA2 Amps 358.5 423.7  NOTE: The candidate can use either the MCB meter amperages or the plant computer values for heater amperages. The IPO allows both and there is no significant difference.
NOTE:  The shaded parameters should NOT be used. The following problems exist with the shaded data:  1. The pressurizer heaters are supplied by 1EB1-4, NOT 1B1-4 2. 1EA1/2 amperage is not necessary to complete the calculations. 3. Data from the last set of logs should NOT be used for the Operability determination. Plant conditions could have changed significantly si nce the readings were taken. The IPO wants current plant data to determine Operability.
NOTE:  The shaded parameters should NOT be used. The following problems exist with the shaded data:  1. The pressurizer heaters are supplied by 1EB1-4, NOT 1B1-4 2. 1EA1/2 amperage is not necessary to complete the calculations. 3. Data from the last set of logs should NOT be used for the Operability determination. Plant conditions could have changed significantly si nce the readings were taken. The IPO wants current plant data to determine Operability.
Initial License Exam                      03/2005 Job Performance Measure JPM: SRO/RO A1.a KEY  Page 5 of 5 Rev Date: 1/19/05 Circle the correct status for each Bank of Pressurizer Heaters Heater Bank Status Status B/U Heater Grp. A Operable Inoperable B/U Heater Grp. B Operable Inoperable Control Grp. C Operable Inoperable B/U Heater Grp. D Operable Inoperable Example of the completed procedure:  
Initial License Exam                      03/2005 Job Performance Measure JPM: SRO/RO A1.a KEY  Page 5 of 5 Rev Date: 1/19/05 Circle the correct status for each Bank of Pressurizer Heaters Heater Bank Status Status B/U Heater Grp. A Operable Inoperable B/U Heater Grp. B Operable Inoperable Control Grp. C Operable Inoperable B/U Heater Grp. D Operable Inoperable Example of the completed procedure:
 
5.3 Heatup And Pressurization For MODE 3 Entry
===5.3 Heatup===
And Pressurization For MODE 3 Entry  
[C] This section describes steps for heatup and pressurization to enter MODE 3. 5.3.1 Verify at least two groups of pressurizer heaters have a capacity of at least 150KW each.(TS SR 3.4.9.2)  A. Energize each group of heaters, as required, to measure current.                        _____
[C] This section describes steps for heatup and pressurization to enter MODE 3. 5.3.1 Verify at least two groups of pressurizer heaters have a capacity of at least 150KW each.(TS SR 3.4.9.2)  A. Energize each group of heaters, as required, to measure current.                        _____
B. Record voltage and current AND calculate power for each group of heaters.                    (Voltage x current x 0.001732 = power)
B. Record voltage and current AND calculate power for each group of heaters.                    (Voltage x current x 0.001732 = power)
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Pass criteria is 4 of the 5 ROs work hour status being correctly determined No - cannot work Yes - can work Note Completion time.
Pass criteria is 4 of the 5 ROs work hour status being correctly determined No - cannot work Yes - can work Note Completion time.
Initial License Exam                      03/2005 Job Performance Measure JPM: SRO A1.b Page 4 of 4 Rev Date: 1/19/05 INITIATING CUE:
Initial License Exam                      03/2005 Job Performance Measure JPM: SRO A1.b Page 4 of 4 Rev Date: 1/19/05 INITIATING CUE:
You are the Unit Supervisor and one of the assigned ROs called in sick. You need to find a replacement RO. Assuming today is March 23 (0630), based on the work hour history evaluate whether any of the following 5 ROs could perform safety-related functions until 1830 without advanced approval. For each candidate indicate whether the answer is yes or no.  
You are the Unit Supervisor and one of the assigned ROs called in sick. You need to find a replacement RO. Assuming today is March 23 (0630), based on the work hour history evaluate whether any of the following 5 ROs could perform safety-related functions until 1830 without advanced approval. For each candidate indicate whether the answer is yes or no.
: 1. RO1 has been on-shift since 0200 (March 23). 2. On March 22, RO2 worked from 0630 until 1900 (includes a 1/2 hour shift turnover). 3. RO3 worked from 1430 on March 22 to 0030 on March 23. 4. RO4 has been on vacation for the past two days (March 21 and 22), but worked 12 hours on March 17, 16 hours on March 18, 16 hours on March 19, and 14 hours on March 20. 5. On March 22, RO5 worked from 0630 until 1930 (includes a 1/2 hour shift turnover).  
: 1. RO1 has been on-shift since 0200 (March 23). 2. On March 22, RO2 worked from 0630 until 1900 (includes a 1/2 hour shift turnover). 3. RO3 worked from 1430 on March 22 to 0030 on March 23. 4. RO4 has been on vacation for the past two days (March 21 and 22), but worked 12 hours on March 17, 16 hours on March 18, 16 hours on March 19, and 14 hours on March 20. 5. On March 22, RO5 worked from 0630 until 1930 (includes a 1/2 hour shift turnover).  


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The SM has called the Prompt team and they will call with the LOCAR number when it is generated.
The SM has called the Prompt team and they will call with the LOCAR number when it is generated.
Page 4 of 4 Rev Date:
Page 4 of 4 Rev Date:
2/7/05 Pressurizer  
2/7/05 Pressurizer 3.4.9 SURVEILLANCE SR 3.4.9.1 Verify pressurizer water ievel is 592%. ACTIONS (continued)
 
====3.4.9 SURVEILLANCE====
 
SR 3.4.9.1 Verify pressurizer water ievel is 592%. ACTIONS (continued)
FREQUENCY 12 hours CONDITION SR 3.4.9.2 Verify capacity of each required group of pressurizer heaters is 2 150 kW. B. One required group of pressurizer heaters inoperable.
FREQUENCY 12 hours CONDITION SR 3.4.9.2 Verify capacity of each required group of pressurizer heaters is 2 150 kW. B. One required group of pressurizer heaters inoperable.
18 months C. Required Action and associated Completion Time of Condition B not met. REQUIRED ACTION B. 1 Restore required group of pressurizer heaters to OPERABLE status. c. 1 Be in MODE 3. c.2 Be in MODE 4. COMPLETION TIME 72 hours 6 hours 12 hours COMANCHE PEAK - UNITS 1 AND 2 3.4-20 Amendment No. 64 Pressurizer 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.9 Pressurizer LCO 3.4.9 The pressurizer shall be OPERABLE with: a. Pressurizer water level 592%; and b. Two groups of pressurizer heaters OPERABLE with the capacity of each group 2 150 kW. APPLICABILITY:
18 months C. Required Action and associated Completion Time of Condition B not met. REQUIRED ACTION B. 1 Restore required group of pressurizer heaters to OPERABLE status. c. 1 Be in MODE 3. c.2 Be in MODE 4. COMPLETION TIME 72 hours 6 hours 12 hours COMANCHE PEAK - UNITS 1 AND 2 3.4-20 Amendment No. 64 Pressurizer 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.9 Pressurizer LCO 3.4.9 The pressurizer shall be OPERABLE with: a. Pressurizer water level 592%; and b. Two groups of pressurizer heaters OPERABLE with the capacity of each group 2 150 kW. APPLICABILITY:
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   -KEY-  Page 4 of 4 Rev Date: 2/7/05 INITIATING CUE:
   -KEY-  Page 4 of 4 Rev Date: 2/7/05 INITIATING CUE:
You are on tour in the Safeguards Building. The US directs you to isolate the air to HV-8152. You are to evaluate the radiological condition in the area and provide the requested information.
You are on tour in the Safeguards Building. The US directs you to isolate the air to HV-8152. You are to evaluate the radiological condition in the area and provide the requested information.
NOTE: Circle the correct answers to the following questions and provide the evaluator with your completed paperwork.  
NOTE: Circle the correct answers to the following questions and provide the evaluator with your completed paperwork.
: 1. The area where the valve is located is a:
: 1. The area where the valve is located is a:
A) Locked High Radiation Area B) Contaminated Area C) Posted High Radiation Area D) General Radiation Area  
A) Locked High Radiation Area B) Contaminated Area C) Posted High Radiation Area D) General Radiation Area
: 2. If the area where the air isolation valve is located is a 60 mr/hr field, how long before your dosimeter will alarm if it is at the lower setting allowed by the GAP.
: 2. If the area where the air isolation valve is located is a 60 mr/hr field, how long before your dosimeter will alarm if it is at the lower setting allowed by the GAP.
A) Immediately B) 5 minutes C) 25 minutes D) 2.5 minutes  
A) Immediately B) 5 minutes C) 25 minutes D) 2.5 minutes
: 3. Circle three areas on the Survey Map that require contact with RP prior to entry.  
: 3. Circle three areas on the Survey Map that require contact with RP prior to entry.  


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  -KEY-  INITIATING CUE:
  -KEY-  INITIATING CUE:
You are on tour in the Safeguards Building. The US directs you to isolate the air to HV-8152. You are to evaluate the radiological condition in the area and provide the requested information.
You are on tour in the Safeguards Building. The US directs you to isolate the air to HV-8152. You are to evaluate the radiological condition in the area and provide the requested information.
NOTE: Circle the correct answers to the following questions and provide the evaluator with your completed paperwork.  
NOTE: Circle the correct answers to the following questions and provide the evaluator with your completed paperwork.
: 1. The area where the valve is located is a:
: 1. The area where the valve is located is a:
E) Locked High Radiation Area F) Contaminated Area G) Posted High Radiation Area H) General Radiation Area  
E) Locked High Radiation Area F) Contaminated Area G) Posted High Radiation Area H) General Radiation Area
: 2. If the area where the air isolation valve is located is a 60 mr/hr field, how long before your dosimeter will alarm if it is at the lower setting allowed by the GAP.
: 2. If the area where the air isolation valve is located is a 60 mr/hr field, how long before your dosimeter will alarm if it is at the lower setting allowed by the GAP.
E) Immediately F) 5 minutes G) 25 minutes H) 2.5 minutes  
E) Immediately F) 5 minutes G) 25 minutes H) 2.5 minutes
: 3. Circle three areas on the Survey Map that require contact with RP prior to entry.  
: 3. Circle three areas on the Survey Map that require contact with RP prior to entry.
: 1) High Radiation area where the valve to be operated is. 2) The CA I/S Pit 3) Platform on the south end of the room.  
: 1) High Radiation area where the valve to be operated is. 2) The CA I/S Pit 3) Platform on the south end of the room.  


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A reactor trip, safety injection, and steamline isolation have been initiated. 1-W2452-2 STM SPLY VLV - MSL#1 (TDAFWP Steam Supply) indicates mid position.
A reactor trip, safety injection, and steamline isolation have been initiated. 1-W2452-2 STM SPLY VLV - MSL#1 (TDAFWP Steam Supply) indicates mid position.
The Unit Supervisor directs you to isolate the valve using a manual isolation, and notify the control room when complete.
The Unit Supervisor directs you to isolate the valve using a manual isolation, and notify the control room when complete.
Terminating Conditions  
Terminating Conditions
: The #1 SG has been isolated.
: The #1 SG has been isolated.
Page 2 of 4 Rev Date: 3/15/05 Initial License Exam 03/2005 Job Performance Measure JPM: P3 1 "2 3 Operator identifies alternate Locate alternate valves Note Start time. valves to isolate g-HV-2452-2.
Page 2 of 4 Rev Date: 3/15/05 Initial License Exam 03/2005 Job Performance Measure JPM: P3 1 "2 3 Operator identifies alternate Locate alternate valves Note Start time. valves to isolate g-HV-2452-2.
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IPO-005A, Step 5.1.5 Tools, Equipment, Job Aids, etc:
IPO-005A, Step 5.1.5 Tools, Equipment, Job Aids, etc:
Reset to IC 5 with Tave appx. 557  F, RCS Pressure appx. 2235 psig, and a small cooldown in progress.
Reset to IC 5 with Tave appx. 557  F, RCS Pressure appx. 2235 psig, and a small cooldown in progress.
Provide working copy of IPO-005A, steps 5.1.5 and  
Provide working copy of IPO-005A, steps 5.1.5 and 5.1.6 Initial License Exam                      03/2005 Job Performance Measure JPM: S2  Page 2 of 8 Rev Date: 1/27/05 Safety Considerations:
 
====5.1.6 Initial====
License Exam                      03/2005 Job Performance Measure JPM: S2  Page 2 of 8 Rev Date: 1/27/05 Safety Considerations:
If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:
If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:
During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:
During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:
Line 923: Line 912:
Speed Control Handswitch (65-1EG1) taken to RAISE and synchroscope checked until rotating SLOWLY in FAST  
Speed Control Handswitch (65-1EG1) taken to RAISE and synchroscope checked until rotating SLOWLY in FAST  


direction (2-4 RPM_.  
direction (2-4 RPM_.
(65-u EG1 taken to LOWER if speed too fast.) Handswitch (65-1EG1) is a 3-POSITION SPRING RETURN TO OFF type switch  
(65-u EG1 taken to LOWER if speed too fast.) Handswitch (65-1EG1) is a 3-POSITION SPRING RETURN TO OFF type switch  


Line 972: Line 961:
Handswitch (90-1EG1) taken to RAISE to increase KVARS or LOWER to decrease  
Handswitch (90-1EG1) taken to RAISE to increase KVARS or LOWER to decrease  


KVARS as on DG1 KILOVAR Meter (VAR-1EG1) checked.  
KVARS as on DG1 KILOVAR Meter (VAR-1EG1) checked.
(This step should be  
(This step should be  


repeated as the DG is loaded.)
repeated as the DG is loaded.)
Initial License Exam                      03/2005 Job Performance Measure JPM: S6  Page 6 of 7 Rev Date: 1/26/05 STEP# *Critical ELEMENT  STANDARD  NOTES SAT/ UNSAT 11 Load the selected DG to  6.0 MW over a 20 minute period.
Initial License Exam                      03/2005 Job Performance Measure JPM: S6  Page 6 of 7 Rev Date: 1/26/05 STEP# *Critical ELEMENT  STANDARD  NOTES SAT/ UNSAT 11 Load the selected DG to  6.0 MW over a 20 minute period.
CUE:    When switch is taken to RAISE and W-uEG2 is observed, give reading indication incr easing MW or for Lower, decreasing MW. DG1 loaded to 6.0 MW over a 20 minute period  
CUE:    When switch is taken to RAISE and W-uEG2 is observed, give reading indication incr easing MW or for Lower, decreasing MW. DG1 loaded to 6.0 MW over a 20 minute period
( .3 MW/min) by moving the Speed Control Handswitch (65-1EG1) to RAISE direction and observing the DG1 MW Meter (W-1EG1).
( .3 MW/min) by moving the Speed Control Handswitch (65-1EG1) to RAISE direction and observing the DG1 MW Meter (W-1EG1).
Speed Control  
Speed Control  
Line 1,039: Line 1,028:


SOP-502A, "CCW System" ABN-502, "Component Cooling Water System Malfunction" Tools, Equipment, Job Aids, etc:
SOP-502A, "CCW System" ABN-502, "Component Cooling Water System Malfunction" Tools, Equipment, Job Aids, etc:
Simulator:  
Simulator:
: 1) Any IC above Mode 4. 2) Insert and activate MALF-CC03B 3) Insert MALF-CC02B on a key. When CCW pump 1-01 is stopped, activate malfunction.  
: 1) Any IC above Mode 4. 2) Insert and activate MALF-CC03B 3) Insert MALF-CC02B on a key. When CCW pump 1-01 is stopped, activate malfunction.  


Line 1,161: Line 1,150:
NOTE: 1-PI-2328, MSL 4 PRESS is failed high.
NOTE: 1-PI-2328, MSL 4 PRESS is failed high.
Step 2. Verify Steam Generator At mospheric Relief Valves - CLOSED:
Step 2. Verify Steam Generator At mospheric Relief Valves - CLOSED:
NO Step 2, RNO. Perform following:  
NO Step 2, RNO. Perform following:
: a. IF pressure is less than 1125 psig, THEN manually close affected atmospheric relief valve.  
: a. IF pressure is less than 1125 psig, THEN manually close affected atmospheric relief valve.
: b. Notify Chemistry that a release has occurred and for Chemistry to determine if a release permit is required per STA-603.  
: b. Notify Chemistry that a release has occurred and for Chemistry to determine if a release permit is required per STA-603.
: c. GO TO Step 11.
: c. GO TO Step 11.
Step 11. Refer to Techni cal Specifications per Attachment 6.
Step 11. Refer to Techni cal Specifications per Attachment 6.
Line 1,175: Line 1,164:


PZR Spray valve fails open.
PZR Spray valve fails open.
Time  RO  BOP  SRO  Applicant's Actions or Behavior  
Time  RO  BOP  SRO  Applicant's Actions or Behavior 3.1 Symptoms
 
: a. Annunciator Alarms
===3.1 Symptoms===
: a. Annunciator Alarms  
: b. Plant Indication Spray valve indicated open when not called for by master controller.
: b. Plant Indication Spray valve indicated open when not called for by master controller.
 
3.2 Automatic Actions
===3.2 Automatic===
: a. Control response for failed open spray valve(s)
Actions  
: 1) Control and backup heaters come on.
: a. Control response for failed open spray valve(s)  
: 2) Reactor trip at 1880 psig.
: 1) Control and backup heaters come on.  
: 2) Reactor trip at 1880 psig.  
: 3) Safety Injection at 1820 psig.
: 3) Safety Injection at 1820 psig.
NOTE to Examiner: If there is delay in putting the spray valve to manual an OTN16 turbine runback may occur.
NOTE to Examiner: If there is delay in putting the spray valve to manual an OTN16 turbine runback may occur.
Line 1,202: Line 1,187:
== Description:==
== Description:==


LOR on 1EA2  (Bus will be powered by the EDG) and TDAFWP Overspeed Time  RO  BOP  SRO  Applicant's Actions or Behavior  
LOR on 1EA2  (Bus will be powered by the EDG) and TDAFWP Overspeed Time  RO  BOP  SRO  Applicant's Actions or Behavior 2.1 Symptoms
 
: a. Annunciator Alarms
===2.1 Symptoms===
: a. Annunciator Alarms  
: b. Plant Indications Lockout relay (LOR) trip of any 6.9 KV safeguard bus A 6.9 KV bus de-energized with no apparent causes.
: b. Plant Indications Lockout relay (LOR) trip of any 6.9 KV safeguard bus A 6.9 KV bus de-energized with no apparent causes.
NOTE:  It is probable that the crew will decrease Turbine Load approx. 50 MW in response the AFW pump start.
NOTE:  It is probable that the crew will decrease Turbine Load approx. 50 MW in response the AFW pump start.
Line 1,218: Line 1,201:
== Description:==
== Description:==


LOR on 1EA2  (Bus will be powered by the EDG) and TDAFWP Overspeed Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 3 Check 6.9 KV safeguard buses - BOTH ENERGIZED  
LOR on 1EA2  (Bus will be powered by the EDG) and TDAFWP Overspeed Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 3 Check 6.9 KV safeguard buses - BOTH ENERGIZED
: a. Bus voltage, 6500-7100 volts  
: a. Bus voltage, 6500-7100 volts
: b. Bus frequency, 59.5-60.5 Hz  
: b. Bus frequency, 59.5-60.5 Hz
: c. GO TO Step 5.
: c. GO TO Step 5.
Step 5 Monitor blackout sequencer status:  
Step 5 Monitor blackout sequencer status:
: a. Affected bus - ENERGIZED  
: a. Affected bus - ENERGIZED
: b. Verify Blackout Sequencer -OPERATED OUTPUT-STEP TIME lights -ALL LIT OR Automatic lockouts AL light -LIT  
: b. Verify Blackout Sequencer -OPERATED OUTPUT-STEP TIME lights -ALL LIT OR Automatic lockouts AL light -LIT
: c. Verify all required equipment actuated per Attachment 2.  
: c. Verify all required equipment actuated per Attachment 2.
: d. Recover from blackout sequencer operation per Section 8 while continuing.
: d. Recover from blackout sequencer operation per Section 8 while continuing.
EXAMINER NOTE:  After crew completes Att 2, the Booth Operator calls US as Shift Manager and informs the crew that the CPC RO will take over the ABN. The crew should focus on the determination of the TDAFWP status.
EXAMINER NOTE:  After crew completes Att 2, the Booth Operator calls US as Shift Manager and informs the crew that the CPC RO will take over the ABN. The crew should focus on the determination of the TDAFWP status.
Line 1,238: Line 1,221:
== Description:==
== Description:==


LOR on 1EA2  (Bus will be powered by the EDG) and TDAFWP Overspeed Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 2 RNO. Perform the following:  
LOR on 1EA2  (Bus will be powered by the EDG) and TDAFWP Overspeed Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 2 RNO. Perform the following:
: a. Ensure at least one steam supply valve open: u-HS-2452-1, AFWPT STM SPLYVLV-MSL 4 u-HS-2452-2, AFWPT STM SPLYVLV-MSL 1  
: a. Ensure at least one steam supply valve open: u-HS-2452-1, AFWPT STM SPLYVLV-MSL 4 u-HS-2452-2, AFWPT STM SPLYVLV-MSL 1
: b. Lower u-SK-2452A, AFWPT SPD CTRL to 0% output.  
: b. Lower u-SK-2452A, AFWPT SPD CTRL to 0% output.
: c. Direct Plant Equipment Operator to perform the following per Attachment 1      1) Reset overspeed trip linkage.
: c. Direct Plant Equipment Operator to perform the following per Attachment 1      1) Reset overspeed trip linkage.
The PEO reports that the overspeed tr ip linkage is galled and will not move enough to reset.
The PEO reports that the overspeed tr ip linkage is galled and will not move enough to reset.
Line 1,262: Line 1,245:


Feedline Break Outside Containment/Loss of  1EA2 Time  RO  BOP  SRO  Applicant's Actions or Behavior Annunciators Plant Indications Tave decreasing MFP speed increasing SG Level decreasing Enters EOP-0.0A.
Feedline Break Outside Containment/Loss of  1EA2 Time  RO  BOP  SRO  Applicant's Actions or Behavior Annunciators Plant Indications Tave decreasing MFP speed increasing SG Level decreasing Enters EOP-0.0A.
Step 1. Verify Reactor Trip  
Step 1. Verify Reactor Trip
: a. Verify the following: Reactor Trip and bypass breakers- OPEN, AND Neutron Flux- DECREASING  
: a. Verify the following: Reactor Trip and bypass breakers- OPEN, AND Neutron Flux- DECREASING
: b. All control position rod bottom lights-ON Step 2. Verify Turbine Trip:  
: b. All control position rod bottom lights-ON Step 2. Verify Turbine Trip:
: a. All turbine stop valves - CLOSED Step 3. Verify Power to AC Safeguards Busses:  
: a. All turbine stop valves - CLOSED Step 3. Verify Power to AC Safeguards Busses:
: a. AC safeguards busses - AT LEAST ONE ENERGIZED AC safeguards bus voltage _ 6900 Volts (6500-7100 volts)  
: a. AC safeguards busses - AT LEAST ONE ENERGIZED AC safeguards bus voltage _ 6900 Volts (6500-7100 volts)
: b. AC safeguards busses - BOTH ENERGIZED Step b. RNO Restore power to de-energized AC Safeguards bus per ABN-601 or 602, when time permits.
: b. AC safeguards busses - BOTH ENERGIZED Step b. RNO Restore power to de-energized AC Safeguards bus per ABN-601 or 602, when time permits.
NOTE: It is probable that the crew will place the B EDG in Pull Out.  
NOTE: It is probable that the crew will place the B EDG in Pull Out.  
Line 1,276: Line 1,259:
== Description:==
== Description:==


Feedline Break Outside Containment/Loss of  1EA2 Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 4. Check SI Status:  
Feedline Break Outside Containment/Loss of  1EA2 Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 4. Check SI Status:
: a. Check If SI is Actuated:
: a. Check If SI is Actuated:
SI actuation as indicated on the First Out Ann 1-ALB-6C SI Actuated blue status light - ON  
SI actuation as indicated on the First Out Ann 1-ALB-6C SI Actuated blue status light - ON
: b. Verify Both Trains SI Actuated:
: b. Verify Both Trains SI Actuated:
SI Actuated blue status light - ON NOT FLASHING Step 4, RNO.
SI Actuated blue status light - ON NOT FLASHING Step 4, RNO.
Line 1,290: Line 1,273:


Feedline Break Outside Containment/Loss of 1EA2 Time  RO  BOP  SRO  Applicant's Actions or Behavior Transitions to EOS-0.1A, Reactor Trip Response Step 1. Check RCS Average Temperature - STABLE AT OR TRENDING TO 557° F.
Feedline Break Outside Containment/Loss of 1EA2 Time  RO  BOP  SRO  Applicant's Actions or Behavior Transitions to EOS-0.1A, Reactor Trip Response Step 1. Check RCS Average Temperature - STABLE AT OR TRENDING TO 557° F.
Step 2. Check FW Status:  
Step 2. Check FW Status:
: a. Verify reactor trip and bypass breaker - OPEN  
: a. Verify reactor trip and bypass breaker - OPEN
: b. Check RCS average temperatures - LESS THAN 564° F.  
: b. Check RCS average temperatures - LESS THAN 564° F.
: c. Verify Feedwater Isolation - ISOLATION COMPLETE  
: c. Verify Feedwater Isolation - ISOLATION COMPLETE
: d. Verify total AFW to SGs - GREATER THAN 460 GPM.
: d. Verify total AFW to SGs - GREATER THAN 460 GPM.
Step 3. Check PRZR Level Control:  
Step 3. Check PRZR Level Control:
: a. Level - GREATER THAN 17%  
: a. Level - GREATER THAN 17%
: b. Verify charging - IN SERVICE c. Verify letdown - IN SERVICE  
: b. Verify charging - IN SERVICE c. Verify letdown - IN SERVICE
: d. Level - TRENDING TO 25%
: d. Level - TRENDING TO 25%
Step 4. Check PRZR Pressure Control:  
Step 4. Check PRZR Pressure Control:
: a. Pressure - GREATER THAN 1820 PSIG  
: a. Pressure - GREATER THAN 1820 PSIG
: b. Pressure - STABLE AT OR TRENDING TO 2235 Step 5. Check SG Levels:  
: b. Pressure - STABLE AT OR TRENDING TO 2235 Step 5. Check SG Levels:
: a. Narrow Range Level - GREATER THAN 5%  
: a. Narrow Range Level - GREATER THAN 5%
: b. Control Feed flow to maintain narrow range level between 5% and 50%.
: b. Control Feed flow to maintain narrow range level between 5% and 50%.
NOTE:  The crew may get to this point or even further before the Heat Sink Red Path becomes required...
NOTE:  The crew may get to this point or even further before the Heat Sink Red Path becomes required...
Line 1,315: Line 1,298:


Loss of Heat Sink ( with SI Pump Failure)
Loss of Heat Sink ( with SI Pump Failure)
Time  RO  BOP  SRO  Applicant's Actions or Behavior Enter FRH-0.1A Loss of Heat Sink Step 1 Check If Se condary Heat Sink is Required:  
Time  RO  BOP  SRO  Applicant's Actions or Behavior Enter FRH-0.1A Loss of Heat Sink Step 1 Check If Se condary Heat Sink is Required:
: a. RCS pressure - GREATER THAN ANY NON_FAULTED SG PRESSURE  b. RCS temperature - GREATER THAN 320°F Yes, continue to step 2.
: a. RCS pressure - GREATER THAN ANY NON_FAULTED SG PRESSURE  b. RCS temperature - GREATER THAN 320°F Yes, continue to step 2.
Step 2. Check CCP Status - BOTH AVAILABLE Step 2, RNO. Immediately perform the following:  
Step 2. Check CCP Status - BOTH AVAILABLE Step 2, RNO. Immediately perform the following:
: a. STOP ALL RCP's  
: a. STOP ALL RCP's
: b. Got to Step 11. OBSERVE CAUTION PRIOR TO STEP 11.
: b. Got to Step 11. OBSERVE CAUTION PRIOR TO STEP 11.
CAUTION:  Steps 11 through 20 must be performed quickly in order to establish RCS heat removal by RCS bleed and feed.
CAUTION:  Steps 11 through 20 must be performed quickly in order to establish RCS heat removal by RCS bleed and feed.
Step 11. Actuate SI.
Step 11. Actuate SI.
Step 12. Verify RCS Feed Path:  
Step 12. Verify RCS Feed Path:
: a. Check Pump Status: CCP's BOTH RUNNING OR AT LEAST ON CCP AND AT LEAST ONE SI PUMP-RUNNING  
: a. Check Pump Status: CCP's BOTH RUNNING OR AT LEAST ON CCP AND AT LEAST ONE SI PUMP-RUNNING
: b. Check valve alignment for operating pumps - PROPER EMERGENCY ALIGNMENT PER ATTACHMENT 3.
: b. Check valve alignment for operating pumps - PROPER EMERGENCY ALIGNMENT PER ATTACHMENT 3.
Step 12, RNO. Manually start pumps.  
Step 12, RNO. Manually start pumps.  
Line 1,332: Line 1,315:


Loss of Heat Sink ( with SI Pump Failure) Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 14. Reset SI Step 15. Reset SI Sequencers Step 16. Reset Containment Isolation Phase A and B.
Loss of Heat Sink ( with SI Pump Failure) Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 14. Reset SI Step 15. Reset SI Sequencers Step 16. Reset Containment Isolation Phase A and B.
Step 17. Reset Containment Spray Signal Step 18. Establish Instrument Air And Nitrogen to Containment.  
Step 17. Reset Containment Spray Signal Step 18. Establish Instrument Air And Nitrogen to Containment.
: a. Establish instrument air:  
: a. Establish instrument air:
: 1) Verify air compressor running and establish instrument air to containment.  
: 1) Verify air compressor running and establish instrument air to containment.
: b. Establish nitrogen  
: b. Establish nitrogen
: 1) Verify ACCUM 1-4 VENT CTRL, 1-HC-943 - CLOSED 2) Open SI/PORV ACCUM N2 ISOL VLV, 1/1-8880.
: 1) Verify ACCUM 1-4 VENT CTRL, 1-HC-943 - CLOSED 2) Open SI/PORV ACCUM N2 ISOL VLV, 1/1-8880.
Step 19. Establish RCS Bleed Path:  
Step 19. Establish RCS Bleed Path:
: a. Verify power to PRZR PORV block valves - AVAILABLE (NOTE: There is power to train A only, train B open, but without power) b. Verify PRZR PORV block valves - BOTH OPEN  
: a. Verify power to PRZR PORV block valves - AVAILABLE (NOTE: There is power to train A only, train B open, but without power) b. Verify PRZR PORV block valves - BOTH OPEN
: c. Open both - PRZR PORV's.
: c. Open both - PRZR PORV's.
Step 20. Verify Adequate RCS Bleed Path:
Step 20. Verify Adequate RCS Bleed Path:
Line 1,344: Line 1,327:
                                                       *BOLD INDICATES CRITICAL STEP
                                                       *BOLD INDICATES CRITICAL STEP


SHIFT TURNOVER INFORMATION
SHIFT TURNOVER INFORMATION 1.0 INITIAL CONDTIONS:
 
===1.0 INITIAL===
CONDTIONS:
Time in Core Life: BOL Tavg: 589 o F Reactor Power: 100%
Time in Core Life: BOL Tavg: 589 o F Reactor Power: 100%
RCS Pressure: 2235 psig Turbine Load:1200 MWe Xenon: Equil Boron Concentration:1263 ppm Rod Control:        AUTO Rod Height: CB D @ 215steps 2.0 LCOAR/TECHNICAL SPECIFICATION ACTIONS IN EFFECT:
RCS Pressure: 2235 psig Turbine Load:1200 MWe Xenon: Equil Boron Concentration:1263 ppm Rod Control:        AUTO Rod Height: CB D @ 215steps 2.0 LCOAR/TECHNICAL SPECIFICATION ACTIONS IN EFFECT:
TS# Description Reason    3.7.5  AFW                  AFW Pump 1-01 OOS for Oil change  
TS# Description Reason    3.7.5  AFW                  AFW Pump 1-01 OOS for Oil change 3.0 CLEARANCES IN EFFECT:
 
AFW Pump 1-01 OOS for Oil change 4.0 SAFETY SYSTEM SETTING BYPASS/MALFUNCTIONS None    5.0  DEGRADED EQUIPMENT 6.0 PLANNED EVOLUTIONS:
===3.0 CLEARANCES===
Return AFW Pump 1-01 to service when the oil change is complete.
IN EFFECT:
7.0 TURNOVER INFORMATION:
AFW Pump 1-01 OOS for Oil change  
 
===4.0 SAFETY===
SYSTEM SETTING BYPASS/MALFUNCTIONS None    5.0  DEGRADED EQUIPMENT
 
===6.0 PLANNED===
EVOLUTIONS:
Return AFW Pump 1-01 to service when the oil change is complete.  
 
===7.0 TURNOVER===
INFORMATION:
Unit 1 and Unit 2 are at 100% power. U1 has been at 100% for the last 15 days following refueling. The "A" MDAFWP is OOS due to contamination in the oil. Maintenance is in the process of changing the oil and the pump should be ready for test in the next 6 hours. The Generation Controller has declared an ALERT due to the loss of several peaking plants and all of the Big Brown units due to a common mode failure. There are no surveillance's planned for this shift and the orders are to maintain current load and unit availability.  
Unit 1 and Unit 2 are at 100% power. U1 has been at 100% for the last 15 days following refueling. The "A" MDAFWP is OOS due to contamination in the oil. Maintenance is in the process of changing the oil and the pump should be ready for test in the next 6 hours. The Generation Controller has declared an ALERT due to the loss of several peaking plants and all of the Big Brown units due to a common mode failure. There are no surveillance's planned for this shift and the orders are to maintain current load and unit availability.  


Line 1,435: Line 1,404:
== Description:==
== Description:==


SG Level Transmitter LT-552 Fails High Time  RO  BOP  SRO  Applicant's Actions or Behavior  
SG Level Transmitter LT-552 Fails High Time  RO  BOP  SRO  Applicant's Actions or Behavior 2.1 Symptoms
 
: a. Annunciator Alarms
===2.1 Symptoms===
: b. Plant Indications
: a. Annunciator Alarms  
: b. Plant Indications  
: 1) One steam generator level instrument indicating higher or lower than the other steam generators level instruments.
: 1) One steam generator level instrument indicating higher or lower than the other steam generators level instruments.
Diagnose Failed SG Level Controller and Enter ABN-710.
Diagnose Failed SG Level Controller and Enter ABN-710.
Line 1,455: Line 1,422:
== Description:==
== Description:==


SG Level Transmitter LT-552 Fails High (cont) Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 5 Verify automatic SG level control - DESIRED  
SG Level Transmitter LT-552 Fails High (cont) Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 5 Verify automatic SG level control - DESIRED
: a. Alternate level control channel responding normally. b. Automatic level control desired, as determined by Unit Supervisor.
: a. Alternate level control channel responding normally. b. Automatic level control desired, as determined by Unit Supervisor.
Step 6 Select alternate channel:
Step 6 Select alternate channel:
Line 1,473: Line 1,440:
== Description:==
== Description:==


Trip of Running CCP Time  RO  BOP  SRO  Applicant's Actions or Behavior  
Trip of Running CCP Time  RO  BOP  SRO  Applicant's Actions or Behavior 3.1 Symptoms
 
: a. Annunciator Alarms
===3.1 Symptoms===
: b. Plant Indications
: a. Annunciator Alarms  
: b. Plant Indications  
: 1. Amber MISMATCH or trip light(s) ON at the charging pump control switch.
: 1. Amber MISMATCH or trip light(s) ON at the charging pump control switch.
: 2. Pressurizer level indicating lower than program level during steady state conditions.  
: 2. Pressurizer level indicating lower than program level during steady state conditions.
: 3. Charging Flow will indicate 0 gpm  
: 3. Charging Flow will indicate 0 gpm 3.2 Automatic Actions
 
===3.2 Automatic===
Actions  
: a. Letdown line isolation occurs at 17% pressurizer level AND pressurizer heaters will deenergize.
: a. Letdown line isolation occurs at 17% pressurizer level AND pressurizer heaters will deenergize.
Diagnose CCP Trip and Enter ABN-105 NOTE: Step 1 and 2 may be performed concurrently.          Step 1.  (Initial Operator Action ) Verify Component Cooling Water flow to RCP Thermal Barrier HX(s)-GREATER THAN 35 GPM:  
Diagnose CCP Trip and Enter ABN-105 NOTE: Step 1 and 2 may be performed concurrently.          Step 1.  (Initial Operator Action ) Verify Component Cooling Water flow to RCP Thermal Barrier HX(s)-GREATER THAN 35 GPM:  
Line 1,497: Line 1,459:
Start a Charging Pump.
Start a Charging Pump.
Step 4 Verify Seal Injection Flow to each RCP - BETWEEN 6 GPM AND 13 GPM          Step 5 Verify RCP Parameters in - NORMAL OPERATING RANGE:
Step 4 Verify Seal Injection Flow to each RCP - BETWEEN 6 GPM AND 13 GPM          Step 5 Verify RCP Parameters in - NORMAL OPERATING RANGE:
6 Verify PRZR level-GREATER THAN 17% AND INCREASING Step 7 Establish normal Letdown:  
6 Verify PRZR level-GREATER THAN 17% AND INCREASING Step 7 Establish normal Letdown:
: a. OPEN Letdown Isolation Valves: 1/u-LCV-460, LTDN ISOL VLV 1/u-LCV-459, LTDN ISOL VLV 1/u-8152, LTDN CNTMT ISOL VLV ORC 1/u-8160, LTDN CNTMT ISOL VLV IRC  
: a. OPEN Letdown Isolation Valves: 1/u-LCV-460, LTDN ISOL VLV 1/u-LCV-459, LTDN ISOL VLV 1/u-8152, LTDN CNTMT ISOL VLV ORC 1/u-8160, LTDN CNTMT ISOL VLV IRC  
           *BOLD INDICATES CRITICAL STEP
           *BOLD INDICATES CRITICAL STEP
Line 1,507: Line 1,469:
== Description:==
== Description:==


Trip of Running CCP Time  RO  BOP  SRO  Applicant's Actions or Behavior  
Trip of Running CCP Time  RO  BOP  SRO  Applicant's Actions or Behavior
: b. Manually OPEN u-PK-131, LTDN HX OUT PRESS CTRL to 30% DEMAND (50% if restori ng two orifice valves).  
: b. Manually OPEN u-PK-131, LTDN HX OUT PRESS CTRL to 30% DEMAND (50% if restori ng two orifice valves).
: c. Manually OPEN u-TK-130, LTDN HX OUT TEMP CTRL to 50%
: c. Manually OPEN u-TK-130, LTDN HX OUT TEMP CTRL to 50%
DEMAND. d. Adjust charging to desired flow WH ILE maintaining seal injection flow between 6 and 13 gpm.
DEMAND. d. Adjust charging to desired flow WH ILE maintaining seal injection flow between 6 and 13 gpm.
Line 1,518: Line 1,480:


95°F AND place in AUTO.
95°F AND place in AUTO.
Step 8 Verify RCS leakage - NORMAL  
Step 8 Verify RCS leakage - NORMAL
: a. PRZR level stable at OR trending to program.  
: a. PRZR level stable at OR trending to program.
: b. Charging flow less than 15 GPM above letdown flow.
: b. Charging flow less than 15 GPM above letdown flow.
Step 9 Refer to Technical Specifications listed in Section 9.1, this procedure.  
Step 9 Refer to Technical Specifications listed in Section 9.1, this procedure.
 
9.1 Technical Specifications/Requirements 3.4.13, RCS Operational Leakage 3.4.14, RCS Pressure Is olation Valve (PIV) Leakage 3.4.15, RCS Leakage Detect ion Instrumentation 3.5.2, ECCS - Operating 3.5.3, ECCS - Shutdown 13.1.31, Boration Injection System - Operating 13.1.32, Boration Inject ion System - Shutdown  
===9.1 Technical===
Specifications/Requirements 3.4.13, RCS Operational Leakage 3.4.14, RCS Pressure Is olation Valve (PIV) Leakage 3.4.15, RCS Leakage Detect ion Instrumentation 3.5.2, ECCS - Operating 3.5.3, ECCS - Shutdown 13.1.31, Boration Injection System - Operating 13.1.32, Boration Inject ion System - Shutdown  
  *BOLD INDICATES CRITICAL STEP
  *BOLD INDICATES CRITICAL STEP


Line 1,533: Line 1,493:
== Description:==
== Description:==


Letdown Leak Inside Containment Time  RO  BOP  SRO  Applicant's Actions or Behavior  
Letdown Leak Inside Containment Time  RO  BOP  SRO  Applicant's Actions or Behavior 2.1 Symptoms
 
===2.1 Symptoms===
: a. Annunciator Alarms 2.1 b. Plant Indications Containment humidity high or increasing Containment radiation levels high or increasing Incore instrument leakage alarm Containment temperature high or increasing Containment pressure high or increasing Containment dew point increasing Increased reactor coolant make-up frequency VCT level decreasing Charging flow increasing Pressurizer relief and safety valve temperature high Pressurizer level decreasing Condenser off gas radiation level increasing Enters ABN-103, RCS Leak Step 1 Verify charging pump - AT LEAST ONE RUNNING  
: a. Annunciator Alarms 2.1 b. Plant Indications Containment humidity high or increasing Containment radiation levels high or increasing Incore instrument leakage alarm Containment temperature high or increasing Containment pressure high or increasing Containment dew point increasing Increased reactor coolant make-up frequency VCT level decreasing Charging flow increasing Pressurizer relief and safety valve temperature high Pressurizer level decreasing Condenser off gas radiation level increasing Enters ABN-103, RCS Leak Step 1 Verify charging pump - AT LEAST ONE RUNNING  
           *BOLD INDICATES CRITICAL STEP
           *BOLD INDICATES CRITICAL STEP
Line 1,545: Line 1,503:
== Description:==
== Description:==


Letdown Leak Inside Containment Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 2 Ensure Pressurizer level - AT OR TRENDING TO PROGRAM LEVEL SETPOINT a. Verify running charging pump cont roller automatically maintaining Pressurizer level at program setpoint u-FK-121, CCP CHRG FLOCTRL u-SK-459A, PDP SPD CTRL Step 3 Check PRZR Status a. PRZR PORVs - CLOSED 1/u-PCV-455A, PRZR PORV 1/u-PCV-456, PRZR PORV b. PRZR Safety Valves - CLOSED u-ZL-8010A, PRZR SFTY VLV A u-ZL-8010B, PRZR SFTY VLV B u-ZL-8010C, PRZR SFTY VLV C c. PRZR Spray Valves - RESPONDING NORMALLY TO CONTROL PRESSURE u-ZL-455B, RC LOOP 1 PRZRSPR VLV u-ZL-455C, RC LOOP 4 PRZR SPR VLV  
Letdown Leak Inside Containment Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 2 Ensure Pressurizer level - AT OR TRENDING TO PROGRAM LEVEL SETPOINT a. Verify running charging pump cont roller automatically maintaining Pressurizer level at program setpoint u-FK-121, CCP CHRG FLOCTRL u-SK-459A, PDP SPD CTRL Step 3 Check PRZR Status a. PRZR PORVs - CLOSED 1/u-PCV-455A, PRZR PORV 1/u-PCV-456, PRZR PORV b. PRZR Safety Valves - CLOSED u-ZL-8010A, PRZR SFTY VLV A u-ZL-8010B, PRZR SFTY VLV B u-ZL-8010C, PRZR SFTY VLV C c. PRZR Spray Valves - RESPONDING NORMALLY TO CONTROL PRESSURE u-ZL-455B, RC LOOP 1 PRZRSPR VLV u-ZL-455C, RC LOOP 4 PRZR SPR VLV
: d. Pressurizer Relief Tank level AND temperature - NO SIGNIFICANT INCREASE  u-TI-468, PRT TEMP u-LI-470, PRT LVL u-PI-469, PRT PRESS  
: d. Pressurizer Relief Tank level AND temperature - NO SIGNIFICANT INCREASE  u-TI-468, PRT TEMP u-LI-470, PRT LVL u-PI-469, PRT PRESS
: d. Check PRZR PORV AND Safety Valves for indication of leakage: u-TI-463, PRZR PORV OUT TEMP u-TI-464, PRZR SFTY VLV C OUT TEMP u-TI-465, PRZR SFTY VLV B OUT TEMP Step 4 Verify AUTO makeup in service 1/u-MU, RCS MU MAN ACT -START 43/u-MU, RCS MU MODE SELECT- AUTO Step 5 Verify 1/u-LCV-112A, VCT LVL CTRL VLV - ALIGNED TO VCT.
: d. Check PRZR PORV AND Safety Valves for indication of leakage: u-TI-463, PRZR PORV OUT TEMP u-TI-464, PRZR SFTY VLV C OUT TEMP u-TI-465, PRZR SFTY VLV B OUT TEMP Step 4 Verify AUTO makeup in service 1/u-MU, RCS MU MAN ACT -START 43/u-MU, RCS MU MODE SELECT- AUTO Step 5 Verify 1/u-LCV-112A, VCT LVL CTRL VLV - ALIGNED TO VCT.
Step 6 Check Steam Generator status:  
Step 6 Check Steam Generator status:
: a. All Steam Generator levels - NORMAL  
: a. All Steam Generator levels - NORMAL
: b. Verify SG feedwater/steam flow - NO SIGNIFICANT MISMATCH  
: b. Verify SG feedwater/steam flow - NO SIGNIFICANT MISMATCH
: c. Monitor PC-11 trends on affected Steam Generators for increased  
: c. Monitor PC-11 trends on affected Steam Generators for increased  


Line 1,574: Line 1,532:
== Description:==
== Description:==


RCP Seized Shaft Time  RO  BOP  SRO  Applicant's Actions or Behavior  
RCP Seized Shaft Time  RO  BOP  SRO  Applicant's Actions or Behavior 2.1 Symptoms
 
: a. Annunciators Alarm
===2.1 Symptoms===
: b. Plant Indications Low flow indication on any reactor coolant loop. Breaker TRIP or MISMATCH light illuminated on any RCP handswitch. Motor amps on any RCP motor reading zero.
: a. Annunciators Alarm  
2.2 Automatic Actions  
: b. Plant Indications Low flow indication on any reactor coolant loop. Breaker TRIP or MISMATCH light illuminated on any RCP handswitch. Motor amps on any RCP motor reading zero.  
 
===2.2 Automatic===
Actions  
                   *BOLD INDICATES CRITICAL STEP Revision 0 Appendix D Op-Test No:
                   *BOLD INDICATES CRITICAL STEP Revision 0 Appendix D Op-Test No:
1 Scenario No:
1 Scenario No:
Line 1,588: Line 1,542:
== Description:==
== Description:==


RCP Seized Shaft  Time  RO  BOP  SRO  Applicant's Actions or Behavior  
RCP Seized Shaft  Time  RO  BOP  SRO  Applicant's Actions or Behavior 2.1 Symptoms
 
: a. Annunciators Alarm Plant Indications Automatic Actions Enters EOP-0.0A, Reactor Trip Response Step 1. Verify Reactor Trip
===2.1 Symptoms===
: a. Verify the following: Reactor Trip and bypass breakers- OPEN, AND Neutron Flux- DECREASING
: a. Annunciators Alarm Plant Indications Automatic Actions Enters EOP-0.0A, Reactor Trip Response Step 1. Verify Reactor Trip  
: b. All control position rod bottom lights-ON Step 2. Verify Turbine Trip:
: a. Verify the following: Reactor Trip and bypass breakers- OPEN, AND Neutron Flux- DECREASING  
: a. All turbine stop valves - CLOSED Step 3. Verify Power to AC Safeguards Busses:
: b. All control position rod bottom lights-ON Step 2. Verify Turbine Trip:  
: a. All turbine stop valves - CLOSED Step 3. Verify Power to AC Safeguards Busses:  
: a. AC safeguards busses -
: a. AC safeguards busses -
AT LEAST ONE ENERGIXED AC safeguards bus voltage _ 6900 Volts (6500-7100 volts)  
AT LEAST ONE ENERGIXED AC safeguards bus voltage _ 6900 Volts (6500-7100 volts)
: b. AC safeguards busses - BOTH ENERGIZED Step 4. Check SI Status:  
: b. AC safeguards busses - BOTH ENERGIZED Step 4. Check SI Status:
: a. Check If SI is Actuated:
: a. Check If SI is Actuated:
SI actuation as indicated on the First Out Ann 1-ALB-6C SI Actuated blue status light - ON  
SI actuation as indicated on the First Out Ann 1-ALB-6C SI Actuated blue status light - ON
: b. Verify Both Trains SI Actuated:
: b. Verify Both Trains SI Actuated:
SI Actuated blue status light - ON NOT FLASHING Step 4, RNO.
SI Actuated blue status light - ON NOT FLASHING Step 4, RNO.
Line 1,610: Line 1,562:


Reactor Trip Response Time  RO  BOP  SRO  Applicant's Actions or Behavior Transitions to EOS-0.1A, Reactor Trip Response Step 1. Check RCS Average Temperature - STABLE AT OR TRENDING TO 557° F.
Reactor Trip Response Time  RO  BOP  SRO  Applicant's Actions or Behavior Transitions to EOS-0.1A, Reactor Trip Response Step 1. Check RCS Average Temperature - STABLE AT OR TRENDING TO 557° F.
Step 2. Check FW Status:  
Step 2. Check FW Status:
: a. Verify reactor trip and bypass breaker - OPEN  
: a. Verify reactor trip and bypass breaker - OPEN
: b. Check RCS average temperatures - LESS THAN 564° F.  
: b. Check RCS average temperatures - LESS THAN 564° F.
: c. Verify Feedwater Isolation - ISOLATION COMPLETE  
: c. Verify Feedwater Isolation - ISOLATION COMPLETE
: d. Verify total AFW to SGs - GREATER THAN 460 GPM.
: d. Verify total AFW to SGs - GREATER THAN 460 GPM.
Step 3. Check PRZR Level Control:  
Step 3. Check PRZR Level Control:
: a. Level - GREATER THAN 17%  
: a. Level - GREATER THAN 17%
: b. Verify charging - IN SERVICE c. Verify letdown - IN SERVICE  
: b. Verify charging - IN SERVICE c. Verify letdown - IN SERVICE
: d. Level - TRENDING TO 25%
: d. Level - TRENDING TO 25%
Step 4. Check PRZR Pressure Control:  
Step 4. Check PRZR Pressure Control:
: a. Pressure - GREATER THAN 1820 PSIG  
: a. Pressure - GREATER THAN 1820 PSIG
: b. Pressure - STABLE AT OR TRENDING TO 2235 Step 5. Check SG Levels:  
: b. Pressure - STABLE AT OR TRENDING TO 2235 Step 5. Check SG Levels:
: a. Narrow Range Level - GREATER THAN 5%  
: a. Narrow Range Level - GREATER THAN 5%
: b. Control Feed flow to maintain narrow range level between 5% and 50%.
: b. Control Feed flow to maintain narrow range level between 5% and 50%.
NOTE:  Because of the RCP Trip, the level in the #1 SG will be higher than in the other SGs. The crew should NOT believe that this is indication of a SGTR. If they do, however, it will not effect the outcome of the scenario  
NOTE:  Because of the RCP Trip, the level in the #1 SG will be higher than in the other SGs. The crew should NOT believe that this is indication of a SGTR. If they do, however, it will not effect the outcome of the scenario  
Line 1,631: Line 1,583:
== Description:==
== Description:==


LB LOCA (Auto SI Fails) Time  RO  BOP  SRO  Applicant's Actions or Behavior  
LB LOCA (Auto SI Fails) Time  RO  BOP  SRO  Applicant's Actions or Behavior 2.1 Symptoms
 
===2.1 Symptoms===
: a. Annunciators Alarm Plant Indications RCS pressure and temperature rapidly dropping, Pressurizer level and pressure dropping and Containment Temperature and Pressure increasing rapidly.        NOTE:  It is expected that the operator will initiate Manual SI prior to procedure entry.
: a. Annunciators Alarm Plant Indications RCS pressure and temperature rapidly dropping, Pressurizer level and pressure dropping and Containment Temperature and Pressure increasing rapidly.        NOTE:  It is expected that the operator will initiate Manual SI prior to procedure entry.
Transitions to EOP-0.0A.
Transitions to EOP-0.0A.
Step 1. Verify Reactor Trip  
Step 1. Verify Reactor Trip
: a. Verify the following: Reactor Trip and bypass breakers- OPEN, AND Neutron Flux- DECREASING  
: a. Verify the following: Reactor Trip and bypass breakers- OPEN, AND Neutron Flux- DECREASING
: b. All control position rod bottom lights-ON Step 2. Verify Turbine Trip:  
: b. All control position rod bottom lights-ON Step 2. Verify Turbine Trip:
: a. All turbine stop valves - CLOSED Step 3. Verify Power to AC Safeguards Busses:  
: a. All turbine stop valves - CLOSED Step 3. Verify Power to AC Safeguards Busses:
: a. AC safeguards busses - AT LEAST ONE ENERGIZED AC safeguards bus voltage _ 6900 Volts (6500-7100 volts)  
: a. AC safeguards busses - AT LEAST ONE ENERGIZED AC safeguards bus voltage _ 6900 Volts (6500-7100 volts)
: b. AC safeguards busses - BOTH ENERGIZED Step 4. Check SI Status:  
: b. AC safeguards busses - BOTH ENERGIZED Step 4. Check SI Status:
: a. Check If SI is Actuated:
: a. Check If SI is Actuated:
SI actuation as indicated on the First Out Ann 1-ALB-6C SI Actuated blue status light - ON  
SI actuation as indicated on the First Out Ann 1-ALB-6C SI Actuated blue status light - ON
: b. Verify Both Trains DI Actuated:
: b. Verify Both Trains DI Actuated:
SI Actuated blue status light - ON NOT FLASHING Step 4 RNO. Check if SI required (YES) Manually Initiate SI.  
SI Actuated blue status light - ON NOT FLASHING Step 4 RNO. Check if SI required (YES) Manually Initiate SI.  
Line 1,654: Line 1,604:
LB LOCA (Auto SI Fails) Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 5. Ensure Proper Saf eguards Equipment Operation Per Attachment 2.
LB LOCA (Auto SI Fails) Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 5. Ensure Proper Saf eguards Equipment Operation Per Attachment 2.
NOTE: It is expected that the RHR pump trip will be noticed and documented during the performance of Attachment 2.
NOTE: It is expected that the RHR pump trip will be noticed and documented during the performance of Attachment 2.
Step 6. Verify AFW Alignment  
Step 6. Verify AFW Alignment
: a. MDAFWP - RUNNING  
: a. MDAFWP - RUNNING
: b. Turbine Driven AFW Pump - RUNNING IF NECESSARY  
: b. Turbine Driven AFW Pump - RUNNING IF NECESSARY
: c. AFW total flow - GREATER THAN 460 GPM  
: c. AFW total flow - GREATER THAN 460 GPM
: d. AFW Valves alignment - PROPER ALIGNMENT Step 7. Verify Containment Spray Not Required :  
: d. AFW Valves alignment - PROPER ALIGNMENT Step 7. Verify Containment Spray Not Required :
: a. Containment Pressure - HAS REMAINED LESS THAN 18 PSIG (NO)
: a. Containment Pressure - HAS REMAINED LESS THAN 18 PSIG (NO)
Step a RNO. Perform the following:  
Step a RNO. Perform the following:
: 1) Verify Containment Spray initiated. 2) Verify appropriated MLB indication for CNTMT SPRAY (BLUE WINDOWS) AND PHASE B  (ORANGE WINDOWS) 3) Verify containment spray flow 4) Ensure CHEM ADD TK DISCH VLVs - OPEN  
: 1) Verify Containment Spray initiated. 2) Verify appropriated MLB indication for CNTMT SPRAY (BLUE WINDOWS) AND PHASE B  (ORANGE WINDOWS) 3) Verify containment spray flow 4) Ensure CHEM ADD TK DISCH VLVs - OPEN
: 5) Stop all RCPs. (NOTE:  The crew will stop RCPs at this point instead of waiting until step 11. They may also have stopped the RCPs per the fold out page for this procedure.) 6) Go to step 8.
: 5) Stop all RCPs. (NOTE:  The crew will stop RCPs at this point instead of waiting until step 11. They may also have stopped the RCPs per the fold out page for this procedure.) 6) Go to step 8.
Step 8. Check if Main Steamlines should be Isolated:  
Step 8. Check if Main Steamlines should be Isolated:
: a. Verify the following: Containment Pressure - GR EATER THAN 6 PSIG (YES)  
: a. Verify the following: Containment Pressure - GR EATER THAN 6 PSIG (YES)
: b. Verify main steam isolation complete.
: b. Verify main steam isolation complete.
Step 9. Check RCS Average Temperature - STABLE AT OR TRENDING TO 557°F.
Step 9. Check RCS Average Temperature - STABLE AT OR TRENDING TO 557°F.
Step 9 RNO. Throttle AFW and stop dumping steam.
Step 9 RNO. Throttle AFW and stop dumping steam.
Step 10. Check PRZR Valve Status:  
Step 10. Check PRZR Valve Status:
: a. PRZR Safeties - CLOSED  
: a. PRZR Safeties - CLOSED
: b. Normal PRZR Spray valves - CLOSED c. PORVs - CLOSED  
: b. Normal PRZR Spray valves - CLOSED c. PORVs - CLOSED
: d. Power to at least one block valve - AVAILABLE e. Block valves - AT LEAST ONE OPEN  
: d. Power to at least one block valve - AVAILABLE e. Block valves - AT LEAST ONE OPEN  
*BOLD INDICATES CRITICAL STEP
*BOLD INDICATES CRITICAL STEP
Line 1,680: Line 1,630:
== Description:==
== Description:==


LB LOCA (Auto SI Fails) Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 11. Check if RCPs should be stopped:  
LB LOCA (Auto SI Fails) Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 11. Check if RCPs should be stopped:
: a. ECCS pumps - AT LEAST ONE RUNNING CCP                        -OR- SI pump  b. RCS subcooling - LESS THAN 25° F (55° F FOR ADVERSE CONTAINMENT)  
: a. ECCS pumps - AT LEAST ONE RUNNING CCP                        -OR- SI pump  b. RCS subcooling - LESS THAN 25° F (55° F FOR ADVERSE CONTAINMENT)
: c. Stop all RCPs.
: c. Stop all RCPs.
Step 12. Check if any SG is Faulted:  
Step 12. Check if any SG is Faulted:
: a. Check pressures in all SGs: ANY SG DECREASING IN AN UNCONTROLLED MANNER   
: a. Check pressures in all SGs: ANY SG DECREASING IN AN UNCONTROLLED MANNER   
                                 -OR- ANY SG COMPLETELY DEPRESSURIZED Step 13.Check if SG Tubes Are Not Ruptured:
                                 -OR- ANY SG COMPLETELY DEPRESSURIZED Step 13.Check if SG Tubes Are Not Ruptured:
Line 1,699: Line 1,649:
LB LOCA (Auto SI Fails)  EOP 1.0A Loss of Reactor or Secondary Coolant Time  RO  BOP  SRO  Applicant's Actions or Behavior NOTE:  It is expected that the RWST level will be at 45% within 17 minutes of the LBLOCA. The progress through EOP-1.0A will vary with each crew dependent upon how fast they proceed.
LB LOCA (Auto SI Fails)  EOP 1.0A Loss of Reactor or Secondary Coolant Time  RO  BOP  SRO  Applicant's Actions or Behavior NOTE:  It is expected that the RWST level will be at 45% within 17 minutes of the LBLOCA. The progress through EOP-1.0A will vary with each crew dependent upon how fast they proceed.
Actual progress is not important, but the transition to EOS-1.3 A, Trans fer to Cold Leg Recirculation, when plant conditions require, is.
Actual progress is not important, but the transition to EOS-1.3 A, Trans fer to Cold Leg Recirculation, when plant conditions require, is.
Transitions to EOP-1.0A, Loss of Reactor or Secondary Coolant Step 1. Check if RCPs should be stopped:  
Transitions to EOP-1.0A, Loss of Reactor or Secondary Coolant Step 1. Check if RCPs should be stopped:
: a. ECCS pumps - AT LEAST ONE RUNNING CCP                        -OR- SI pump  b. RCS subcooling - LESS THAN 25° F (55° F FOR ADVERSE CONTAINMENT)  
: a. ECCS pumps - AT LEAST ONE RUNNING CCP                        -OR- SI pump  b. RCS subcooling - LESS THAN 25° F (55° F FOR ADVERSE CONTAINMENT)
: c. Stop all RCPs.
: c. Stop all RCPs.
NOTE: ALL RCPs SHOULD BE ST OPPED AT THIS POINT.
NOTE: ALL RCPs SHOULD BE ST OPPED AT THIS POINT.
Step 2. Check if any SG is Faulted:  
Step 2. Check if any SG is Faulted:
: a. Check pressures in all SGs: ANY SG DECREASING IN AN UNCONTROLLED MANNER   
: a. Check pressures in all SGs: ANY SG DECREASING IN AN UNCONTROLLED MANNER   
                                 -OR- ANY SG COMPLETELY DEPRESSURIZED Step 3. Check SG Levels:  
                                 -OR- ANY SG COMPLETELY DEPRESSURIZED Step 3. Check SG Levels:
: a. Narrow Range Level - GREATER THAN 26%  
: a. Narrow Range Level - GREATER THAN 26%
: b. Control Feed flow to maintain narrow range level between 26% and 50%.
: b. Control Feed flow to maintain narrow range level between 26% and 50%.
Step 4.Check Secondary Radiation - NORMAL Condenser off gas radiation  
Step 4.Check Secondary Radiation - NORMAL Condenser off gas radiation  
Line 1,726: Line 1,676:
Caution:  Any ECCS or Containment Spray pump that loses suction or shows indication of cavitation should be stopped.
Caution:  Any ECCS or Containment Spray pump that loses suction or shows indication of cavitation should be stopped.
Caution:  SI pumps should be stopped if RCS pressure is greater than their shutoff head pressure.
Caution:  SI pumps should be stopped if RCS pressure is greater than their shutoff head pressure.
Step 3. Align ECCS For Cold Leg Recirculation  
Step 3. Align ECCS For Cold Leg Recirculation
: a. Check open CNTMT SMP TO RHRP 1 AND 2 SUCT ISOL VLVS: 1/1-8811A 1/1-8811B  
: a. Check open CNTMT SMP TO RHRP 1 AND 2 SUCT ISOL VLVS: 1/1-8811A 1/1-8811B
: b. Close RWST TO RHRP 1 AND RHRP 2 SUCT VLVS 1/1-8812A 1/1-8812B  
: b. Close RWST TO RHRP 1 AND RHRP 2 SUCT VLVS 1/1-8812A 1/1-8812B
: c. Close SIP 1 AND SIP 2 MINIFLO VLVS:
: c. Close SIP 1 AND SIP 2 MINIFLO VLVS:
1/1-8814A 1/1-8814B 1/1-8813  d. Close RHRP 1 AND RHRP 2 XTIE VLVS:
1/1-8814A 1/1-8814B 1/1-8813  d. Close RHRP 1 AND RHRP 2 XTIE VLVS:
Line 1,740: Line 1,690:
== Description:==
== Description:==


LB LOCA (Auto SI Fails)  EOS 1.3A Transfer to Cold Leg Recirculation Time  RO  BOP  SRO  Applicant's Actions or Behavior  
LB LOCA (Auto SI Fails)  EOS 1.3A Transfer to Cold Leg Recirculation Time  RO  BOP  SRO  Applicant's Actions or Behavior
: e. Close the CCP ALT MINIFLO ISOL VLVS:
: e. Close the CCP ALT MINIFLO ISOL VLVS:
1/1-8511A 1/1-8512B 1/1-8511B 1/1-8512A  
1/1-8511A 1/1-8512B 1/1-8511B 1/1-8512A
: f. Open SI < -- > CHRG SUCT HDR XTIE VLVS:
: f. Open SI < -- > CHRG SUCT HDR XTIE VLVS:
1/1-8807A 1/1-8807B  
1/1-8807A 1/1-8807B
: g. Open RHRPs TO CCP/SIP SUCT VLVS:
: g. Open RHRPs TO CCP/SIP SUCT VLVS:
1/1-8804A 1/1-8804B NOTE: Due to the RHR pump trip, only one train will be lined up for Cold Leg Recirculation.
1/1-8804A 1/1-8804B NOTE: Due to the RHR pump trip, only one train will be lined up for Cold Leg Recirculation.
Step 4. Align Containment Spray System for Recirculation:  
Step 4. Align Containment Spray System for Recirculation:
: a. Check RWST level - LESS THAN 24%.
: a. Check RWST level - LESS THAN 24%.
Step a RNO. If Containment Spray ACTUATED, then continue with step 5. When RWST level is < 24%, continue with step 4b.  
Step a RNO. If Containment Spray ACTUATED, then continue with step 5. When RWST level is < 24%, continue with step 4b.
: b. Realign Containment Spray System as follows:  
: b. Realign Containment Spray System as follows:
: 1) Open CNTMT SMP TO CSP 1 & 3 AND 2 & 4 SUCT ISOL VLVS:
: 1) Open CNTMT SMP TO CSP 1 & 3 AND 2 & 4 SUCT ISOL VLVS:
1-HS-4782 1-HS-4783  
1-HS-4782 1-HS-4783
: 2) Close RWST TO CSP 1 & 3 AND 2 & 4 SUCT VLVS 1-HS-4758 1-HS-4759 The scenario may be terminated at the discretion of the Lead Examiner. *BOLD INDICATES CRITICAL STEP
: 2) Close RWST TO CSP 1 & 3 AND 2 & 4 SUCT VLVS 1-HS-4758 1-HS-4759 The scenario may be terminated at the discretion of the Lead Examiner. *BOLD INDICATES CRITICAL STEP


SHIFT TURNOVER INFORMATION
SHIFT TURNOVER INFORMATION 1.0 INITIAL CONDTIONS:
 
===1.0 INITIAL===
CONDTIONS:
Time in Core Life: BOL Tavg: 571 o F Reactor Power: 42%
Time in Core Life: BOL Tavg: 571 o F Reactor Power: 42%
RCS Pressure: 2250 psig Turbine Load: 429 MWe Xenon: Equil Boron Concentration:    1442 ppm Rod Control:        MAN Rod Height: CB D @ 189 steps 2.0 LCOAR/TECHNICAL SPECIFICATION ACTIONS IN EFFECT:
RCS Pressure: 2250 psig Turbine Load: 429 MWe Xenon: Equil Boron Concentration:    1442 ppm Rod Control:        MAN Rod Height: CB D @ 189 steps 2.0 LCOAR/TECHNICAL SPECIFICATION ACTIONS IN EFFECT:
 
3.0 CLEARANCES IN EFFECT:
===3.0 CLEARANCES===
TS# Description Reason    3.7.5  AFW                  AFW Pump 1-01 OOS for oil change 3.0 CLEARANCES IN EFFECT:
IN EFFECT:
AFW Pump 1-01 OOS for oil change 4.0 SAFETY SYSTEM SETTING BYPASS/MALFUNCTIONS 5.0 DEGRADED EQUIPMENT 6.0 PLANNED EVOLUTIONS:
TS# Description Reason    3.7.5  AFW                  AFW Pump 1-01 OOS for oil change  
Return AFW Pump 1-01 to service when the oil change is complete.
 
7.0 TURNOVER INFORMATION:
===3.0 CLEARANCES===
IN EFFECT:
AFW Pump 1-01 OOS for oil change  
 
===4.0 SAFETY===
SYSTEM SETTING BYPASS/MALFUNCTIONS
 
===5.0 DEGRADED===
EQUIPMENT
 
===6.0 PLANNED===
EVOLUTIONS:
Return AFW Pump 1-01 to service when the oil change is complete.  
 
===7.0 TURNOVER===
INFORMATION:
Unit 1 is at 40% power and increasing per IPO-003A, step 5.4.19. Shift orders are to increase reactor power during the shift. The normal reactivity brief will be held, but an extensive pre job brief will not, due to the ALERT. The "A" MDAFWP is OOS due to contamination in t he oil. Maintenance is in the process of changing the oil and the pump should be ready for test in the next 6 hours.
Unit 1 is at 40% power and increasing per IPO-003A, step 5.4.19. Shift orders are to increase reactor power during the shift. The normal reactivity brief will be held, but an extensive pre job brief will not, due to the ALERT. The "A" MDAFWP is OOS due to contamination in t he oil. Maintenance is in the process of changing the oil and the pump should be ready for test in the next 6 hours.
The Generation Controller has declared an ALERT due to the loss of several peaking plants and all of the Big Brown units due to a common mode failure.
The Generation Controller has declared an ALERT due to the loss of several peaking plants and all of the Big Brown units due to a common mode failure.
Line 1,868: Line 1,799:
== Description:==
== Description:==


Steam Generator Tube Leak on #3 SG Time  RO  BOP  SRO  Applicant's Actions or Behavior  
Steam Generator Tube Leak on #3 SG Time  RO  BOP  SRO  Applicant's Actions or Behavior 2.1 Symptoms
 
===2.1 Symptoms===
: a. Annunciator Alarms None
: a. Annunciator Alarms None
: b. Plant Indications An abnormal increase in steam gener ator specific activity as reported by Chemistry. An abnormal increase in steam generator sampling radiation as indicated by u-RE-4200 (SGS-u64). An abnormal increase in condenser off-gas radiation as indicated by u-RE-2959(COG-u82). An abnormal increase in main steamline leak rate as indicated on u-RE-2325A (N16-u74), u-RE-2326A (N16-u75), u-RE-2327A (N16-u76), and u-RE-2328A (N16-u77). Computer points R7749A (R7753A) thru R7752A (R7756A).
: b. Plant Indications An abnormal increase in steam gener ator specific activity as reported by Chemistry. An abnormal increase in steam generator sampling radiation as indicated by u-RE-4200 (SGS-u64). An abnormal increase in condenser off-gas radiation as indicated by u-RE-2959(COG-u82). An abnormal increase in main steamline leak rate as indicated on u-RE-2325A (N16-u74), u-RE-2326A (N16-u75), u-RE-2327A (N16-u76), and u-RE-2328A (N16-u77). Computer points R7749A (R7753A) thru R7752A (R7756A).
Enters ABN-106, Steam Generator Tube Leak Step 1. Verify main steamline radiation alarms - CLEAR NOTE: u-RE-2327 (MSL-u80) will be in alarm on the PC-11 Step 1 RNO. Go to Section 3 of this procedure.
Enters ABN-106, Steam Generator Tube Leak Step 1. Verify main steamline radiation alarms - CLEAR NOTE: u-RE-2327 (MSL-u80) will be in alarm on the PC-11 Step 1 RNO. Go to Section 3 of this procedure.
Section 3 Step 1. Verify main steamline radiation alarms - CLEAR Step 1 RNO.
Section 3 Step 1. Verify main steamline radiation alarms - CLEAR Step 1 RNO.
: a. Reduce power to 50% in 1 hour AND Be in MODE 3 in the next 2 hours.  
: a. Reduce power to 50% in 1 hour AND Be in MODE 3 in the next 2 hours.
: b. GO TO Step 5.  
: b. GO TO Step 5.  
         *BOLD INDICATES CRITICAL STEP Revision 0 Appendix D Op-Test No:
         *BOLD INDICATES CRITICAL STEP Revision 0 Appendix D Op-Test No:
Line 1,883: Line 1,812:
== Description:==
== Description:==


Steam Generator Tube Leak on #3 SG Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 5 Check plant conditions:  
Steam Generator Tube Leak on #3 SG Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 5 Check plant conditions:
: a. Turbine-Generator load - STEADY AT DESIRED POWER  
: a. Turbine-Generator load - STEADY AT DESIRED POWER
: b. Verify charging flow within 15 gpm of letdown flow AND both flows STABLE  c. Verify PRZR level - STABLE OR TRENDING TO NORMAL LEVEL Step 6. Adjust affected Steam Gener ator Atmospheric Relief Controller setpoint to 1160 PSIG per TDM-501A/B.
: b. Verify charging flow within 15 gpm of letdown flow AND both flows STABLE  c. Verify PRZR level - STABLE OR TRENDING TO NORMAL LEVEL Step 6. Adjust affected Steam Gener ator Atmospheric Relief Controller setpoint to 1160 PSIG per TDM-501A/B.
Step 7. Verify affected Steam Generator - NOT SG #1 or SG #4 Step 8. Isolate Auxiliary Steam supplied from the affected unit by closing the applicable valves:
Step 7. Verify affected Steam Generator - NOT SG #1 or SG #4 Step 8. Isolate Auxiliary Steam supplied from the affected unit by closing the applicable valves:
NOTE: The US will call the PEO to isolate the appropriate valves.
NOTE: The US will call the PEO to isolate the appropriate valves.
Step 9 Verify NO significant increase exists, as indicated on PC-11, from system(s) drains that discharge to the LVW:
Step 9 Verify NO significant increase exists, as indicated on PC-11, from system(s) drains that discharge to the LVW:
Step 10 Monitor position of Steam Generator Atmospheric Relief AND Safety Valves during perfo rmance of this procedure:  
Step 10 Monitor position of Steam Generator Atmospheric Relief AND Safety Valves during perfo rmance of this procedure:
: a. Verify relief AND safety valves remain - CLOSED
: a. Verify relief AND safety valves remain - CLOSED
           *BOLD INDICATES CRITICAL STEP
           *BOLD INDICATES CRITICAL STEP
Line 1,912: Line 1,841:
== Description:==
== Description:==


Loop 4 N-16 Instrument Fails High and Rods move the wrong way Time  RO  BOP  SRO  Applicant's Actions or Behavior  
Loop 4 N-16 Instrument Fails High and Rods move the wrong way Time  RO  BOP  SRO  Applicant's Actions or Behavior 2.1 Symptoms
 
: a. Annunciator Alarms
===2.1 Symptoms===
: b. Plant Indications:
: a. Annunciator Alarms  
: 3) One N-16 channel higher or lower than the other three.
: b. Plant Indications:  
2.2 Automatic Actions NOTE:  This should alert the crew that rods moving OUT is a malfunction and action should be taken.
: 3) One N-16 channel higher or lower than the other three.  
 
===2.2 Automatic===
Actions NOTE:  This should alert the crew that rods moving OUT is a malfunction and action should be taken.
Enters ABN-704A, TC N16 Failure NOTE:  Rod Control should remain in MANUAL until all channels are operable. This does not preclude placing rods in AUTO during rapidly changing transient conditions such as runbacks, etc. as long as rod control is returned to MA NUAL when the plant is stabilized.  
Enters ABN-704A, TC N16 Failure NOTE:  Rod Control should remain in MANUAL until all channels are operable. This does not preclude placing rods in AUTO during rapidly changing transient conditions such as runbacks, etc. as long as rod control is returned to MA NUAL when the plant is stabilized.  
  *BOLD INDICATES CRITICAL STEP
  *BOLD INDICATES CRITICAL STEP
Line 1,948: Line 1,873:


Loop 4 N-16 Instrument Fails High and Rods move the wrong way Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 10 Verify appropriate alarms and trip status lights ON per Attachment 3 AND note verification in Unit Log.
Loop 4 N-16 Instrument Fails High and Rods move the wrong way Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 10 Verify appropriate alarms and trip status lights ON per Attachment 3 AND note verification in Unit Log.
Step 11 Refer to Technical Specificati ons listed in Section 3.1 of this procedure to determine applicable LCOAR conditions.  
Step 11 Refer to Technical Specificati ons listed in Section 3.1 of this procedure to determine applicable LCOAR conditions.
 
3.1 Technical Specifications/Requirements 3.3.1, Reactor Trip Syst em (RTS) Instrumentation 13.1.38, Control Bank Insertion Limits  
===3.1 Technical===
Specifications/Requirements 3.3.1, Reactor Trip Syst em (RTS) Instrumentation 13.1.38, Control Bank Insertion Limits  
  *BOLD INDICATES CRITICAL STEP
  *BOLD INDICATES CRITICAL STEP


Line 1,960: Line 1,883:
== Description:==
== Description:==


Two dropped rods (Manual Reactor Trip Required) Time  RO  BOP  SRO  Applicant's Actions or Behavior  
Two dropped rods (Manual Reactor Trip Required) Time  RO  BOP  SRO  Applicant's Actions or Behavior 3.1 Symptoms
 
: a. Annunciator Alarms
===3.1 Symptoms===
: a. Annunciator Alarms  
: b. Plant Indications Plant parameters changing abnormally during rod position changes NIS Power Range instruments power or AFD indications disagree DRPI Rod Bottom Light(s) lit for rods which should be withdrawn DRPIs in a bank disagree by greater than 12 steps DRPI disagrees with its group step counter by greater than 12 steps Enter ABN-712 Rod Control Malfunction ExaminerNote: The crew may not reference the procedure but based on the procedure, take conservative action and trip the plant immediately.  
: b. Plant Indications Plant parameters changing abnormally during rod position changes NIS Power Range instruments power or AFD indications disagree DRPI Rod Bottom Light(s) lit for rods which should be withdrawn DRPIs in a bank disagree by greater than 12 steps DRPI disagrees with its group step counter by greater than 12 steps Enter ABN-712 Rod Control Malfunction ExaminerNote: The crew may not reference the procedure but based on the procedure, take conservative action and trip the plant immediately.  
  *BOLD INDICATES CRITICAL STEP
  *BOLD INDICATES CRITICAL STEP
Line 1,973: Line 1,894:
== Description:==
== Description:==


Two dropped rods (Manual Reactor Trip Required) EOP-0.0A Time  RO  BOP  SRO  Applicant's Actions or Behavior  
Two dropped rods (Manual Reactor Trip Required) EOP-0.0A Time  RO  BOP  SRO  Applicant's Actions or Behavior 2.1 Symptoms
 
: a. Annunciators Alarm Plant Indications Various First Out Annunciator al arms and changing plant conditions Manual reactor trip and enter EO P-0.0A, Reactor Trip Response Step 1. Verify Reactor Trip
===2.1 Symptoms===
: a. Verify the following: Reactor Trip and bypass breakers- OPEN, AND Neutron Flux- DECREASING
: a. Annunciators Alarm Plant Indications Various First Out Annunciator al arms and changing plant conditions Manual reactor trip and enter EO P-0.0A, Reactor Trip Response Step 1. Verify Reactor Trip  
: b. All control position rod bottom lights-ON Step 2. Verify Turbine Trip:
: a. Verify the following: Reactor Trip and bypass breakers- OPEN, AND Neutron Flux- DECREASING  
: a. All turbine stop valves - CLOSED Step 3. Verify Power to AC Safeguards Busses:
: b. All control position rod bottom lights-ON Step 2. Verify Turbine Trip:  
: a. AC safeguards busses - AT LEAST ONE ENERGIZED AC safeguards bus voltage _ 6900 Volts (6500-7100 volts)
: a. All turbine stop valves - CLOSED Step 3. Verify Power to AC Safeguards Busses:  
: b. AC safeguards busses - BOTH ENERGIZED Step 4. Check SI Status:
: a. AC safeguards busses - AT LEAST ONE ENERGIZED AC safeguards bus voltage _ 6900 Volts (6500-7100 volts)  
: b. AC safeguards busses - BOTH ENERGIZED Step 4. Check SI Status:  
: a. Check If SI is Actuated:
: a. Check If SI is Actuated:
SI actuation as indicated on the First Out Ann 1-ALB-6C SI Actuated blue status light - ON  
SI actuation as indicated on the First Out Ann 1-ALB-6C SI Actuated blue status light - ON
: b. Verify Both Trains SI Actuated:
: b. Verify Both Trains SI Actuated:
SI Actuated blue status light - ON NOT FLASHING Step 4, RNO.
SI Actuated blue status light - ON NOT FLASHING Step 4, RNO.
Line 1,996: Line 1,915:


EOS-0.1 A, REACTOR TRIP RESPONSE Time  RO  BOP  SRO  Applicant's Actions or Behavior Transitions to EOS-0.1A, Reactor Trip Response Step 1. Check RCS Average Temperature - STABLE AT OR TRENDING TO 557&deg; F.
EOS-0.1 A, REACTOR TRIP RESPONSE Time  RO  BOP  SRO  Applicant's Actions or Behavior Transitions to EOS-0.1A, Reactor Trip Response Step 1. Check RCS Average Temperature - STABLE AT OR TRENDING TO 557&deg; F.
Step 2. Check FW Status:  
Step 2. Check FW Status:
: a. Verify reactor trip and bypass breaker - OPEN  
: a. Verify reactor trip and bypass breaker - OPEN
: b. Check RCS average temperatures - LESS THAN 564&deg; F.  
: b. Check RCS average temperatures - LESS THAN 564&deg; F.
: c. Verify Feedwater Isolation - ISOLATION COMPLETE  
: c. Verify Feedwater Isolation - ISOLATION COMPLETE
: d. Verify total AFW to SGs - GREATER THAN 460 GPM.
: d. Verify total AFW to SGs - GREATER THAN 460 GPM.
Step 3. Check PRZR Level Control:  
Step 3. Check PRZR Level Control:
: a. Level - GREATER THAN 17%  
: a. Level - GREATER THAN 17%
: b. Verify charging - IN SERVICE c. Verify letdown - IN SERVICE  
: b. Verify charging - IN SERVICE c. Verify letdown - IN SERVICE
: d. Level - TRENDING TO 25%
: d. Level - TRENDING TO 25%
Step 4. Check PRZR Pressure Control:  
Step 4. Check PRZR Pressure Control:
: a. Pressure - GREATER THAN 1820 PSIG  
: a. Pressure - GREATER THAN 1820 PSIG
: b. Pressure - STABLE AT OR TRENDING TO 2235 Step 5. Check SG Levels:  
: b. Pressure - STABLE AT OR TRENDING TO 2235 Step 5. Check SG Levels:
: a. Narrow Range Level - GREATER THAN 5%  
: a. Narrow Range Level - GREATER THAN 5%
: b. Control Feed flow to maintain narrow range level between 5% and 50%.
: b. Control Feed flow to maintain narrow range level between 5% and 50%.
NOTE: 4 minutes after the manual RX Trip, the SGTR becomes active at 675 GPM. If not done automatically, the crew should Initiate a Safety Injection and transition to EOP-0.0A, step 1.  
NOTE: 4 minutes after the manual RX Trip, the SGTR becomes active at 675 GPM. If not done automatically, the crew should Initiate a Safety Injection and transition to EOP-0.0A, step 1.  
Line 2,017: Line 1,936:
== Description:==
== Description:==


SGTR with failure of Phase A to auto actuate Time  RO  BOP  SRO  Applicant's Actions or Behavior  
SGTR with failure of Phase A to auto actuate Time  RO  BOP  SRO  Applicant's Actions or Behavior 2.1 Symptoms
 
===2.1 Symptoms===
: a. Annunciators Alarm PRZR PRESS LO SI ACT  (6C-2.7)
: a. Annunciators Alarm PRZR PRESS LO SI ACT  (6C-2.7)
Plant Indications Various First Out Annunciator al arms and changing plant conditions Automatic Actions Safety Injection and ECCS actuations Step 1. Verify Reactor Trip  
Plant Indications Various First Out Annunciator al arms and changing plant conditions Automatic Actions Safety Injection and ECCS actuations Step 1. Verify Reactor Trip
: a. Verify the following: Reactor Trip and bypass breakers- OPEN, AND Neutron Flux- DECREASING  
: a. Verify the following: Reactor Trip and bypass breakers- OPEN, AND Neutron Flux- DECREASING
: b. All control position rod bottom lights-ON Step 2. Verify Turbine Trip:  
: b. All control position rod bottom lights-ON Step 2. Verify Turbine Trip:
: a. All turbine stop valves - CLOSED Step 3. Verify Power to AC Safeguards Busses:  
: a. All turbine stop valves - CLOSED Step 3. Verify Power to AC Safeguards Busses:
: a. AC safeguards busses - AT LEAST ONE ENERGIZED AC safeguards bus voltage _ 6900 Volts (6500-7100 volts)  
: a. AC safeguards busses - AT LEAST ONE ENERGIZED AC safeguards bus voltage _ 6900 Volts (6500-7100 volts)
: b. AC safeguards busses - BOTH ENERGIZED Step 4. Check SI Status:  
: b. AC safeguards busses - BOTH ENERGIZED Step 4. Check SI Status:
: a. Check If SI is Actuated:
: a. Check If SI is Actuated:
SI actuation as indicated on the First Out Ann 1-ALB-6C SI Actuated blue status light - ON  
SI actuation as indicated on the First Out Ann 1-ALB-6C SI Actuated blue status light - ON
: b. Verify Both Trains SI Actuated:
: b. Verify Both Trains SI Actuated:
SI Actuated blue status light - ON NOT FLASHING  
SI Actuated blue status light - ON NOT FLASHING  
Line 2,041: Line 1,958:
SGTR with failure of Phase A to auto actuate Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 5. Ensure Proper Safeguards Equipment Operation Per  .
SGTR with failure of Phase A to auto actuate Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 5. Ensure Proper Safeguards Equipment Operation Per  .
NOTE: It is expected that the failure of Phase A to actuate will be noted and a manual Phase A initiated while  is being performed.
NOTE: It is expected that the failure of Phase A to actuate will be noted and a manual Phase A initiated while  is being performed.
Step 6. Verify AFW Alignment  
Step 6. Verify AFW Alignment
: a. MDAFWP - RUNNING  
: a. MDAFWP - RUNNING
: b. Turbine Driven AFW Pump - RUNNING IF NECESSARY  
: b. Turbine Driven AFW Pump - RUNNING IF NECESSARY
: c. AFW total flow - GREATER THAN 460 GPM  
: c. AFW total flow - GREATER THAN 460 GPM
: d. AFW Valves alignment - PROPER ALIGNMENT Step 7. Verify Containment Spray Not Required :  
: d. AFW Valves alignment - PROPER ALIGNMENT Step 7. Verify Containment Spray Not Required :
: 1) a. Containment Pressure -
: 1) a. Containment Pressure -
HAS REMAINED LESS THAN 18 PSIG Step 8. Check if Main Steamlines should be Isolated:  
HAS REMAINED LESS THAN 18 PSIG Step 8. Check if Main Steamlines should be Isolated:
: a. verify the following: Containment Pressure - GR EATER THAN 6 PSIG (YES)  
: a. verify the following: Containment Pressure - GR EATER THAN 6 PSIG (YES)
: b. Verify main steam isolation complete.
: b. Verify main steam isolation complete.
Step 9. Check RCS Average Temperature - STABLE AT OR TRENDING TO 557&deg;F.
Step 9. Check RCS Average Temperature - STABLE AT OR TRENDING TO 557&deg;F.
Step 10. Check PRZR Valve Status:  
Step 10. Check PRZR Valve Status:
: a. PRZR Safeties - CLOSED  
: a. PRZR Safeties - CLOSED
: b. Normal PRZR Spray valves - CLOSED c. PORVs - CLOSED  
: b. Normal PRZR Spray valves - CLOSED c. PORVs - CLOSED
: d. Power to at least one block valve - AVAILABLE e. Block valves - AT LEAST ONE OPEN  
: d. Power to at least one block valve - AVAILABLE e. Block valves - AT LEAST ONE OPEN  
*BOLD INDICATES CRITICAL STEP
*BOLD INDICATES CRITICAL STEP
Line 2,063: Line 1,980:
== Description:==
== Description:==


SGTR with failure of Phase A to auto actuate Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 11. Check if RCPs should be stopped:  
SGTR with failure of Phase A to auto actuate Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 11. Check if RCPs should be stopped:
: a. ECCS pumps - AT LEAST ONE RUNNING CCP                        -OR- SI pump  b. RCS subcooling - LESS THAN 25&deg; F (55&deg; F FOR ADVERSE CONTAINMENT)
: a. ECCS pumps - AT LEAST ONE RUNNING CCP                        -OR- SI pump  b. RCS subcooling - LESS THAN 25&deg; F (55&deg; F FOR ADVERSE CONTAINMENT)
Step 12. Check if any SG is Faulted:  
Step 12. Check if any SG is Faulted:
: a. Check pressures in all SGs: ANY SG DECREASING IN AN UNCONTROLLED MANNER   
: a. Check pressures in all SGs: ANY SG DECREASING IN AN UNCONTROLLED MANNER   
                                 -OR- ANY SG COMPLETELY DEPRESSURIZED Step a RNO, Go to Step 13.  
                                 -OR- ANY SG COMPLETELY DEPRESSURIZED Step a RNO, Go to Step 13.
: b. Go to EOP-2.0A, FAULTED STEAM GENERATOR ISOLATION, Step 1.
: b. Go to EOP-2.0A, FAULTED STEAM GENERATOR ISOLATION, Step 1.
Step 13.Check if SG Tubes Are Not Ruptured:
Step 13.Check if SG Tubes Are Not Ruptured:
Line 2,082: Line 1,999:
== Description:==
== Description:==


SGTR EOP-3.0A Steam Generator Tube Rupture Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 1. Check if RCPs should be stopped:  
SGTR EOP-3.0A Steam Generator Tube Rupture Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 1. Check if RCPs should be stopped:
: a. ECCS pumps - AT LEAST ONE RUNNING CCP                        -OR- SI pump  b. RCS subcooling - LESS THAN 25&deg; F (55&deg; F FOR ADVERSE CONTAINMENT)
: a. ECCS pumps - AT LEAST ONE RUNNING CCP                        -OR- SI pump  b. RCS subcooling - LESS THAN 25&deg; F (55&deg; F FOR ADVERSE CONTAINMENT)
Step 2. Identify Ruptured SG (s):
Step 2. Identify Ruptured SG (s):
Line 2,091: Line 2,008:


2325-2328)
2325-2328)
Step 3  Isolate Flow From Ruptured SG(s):  
Step 3  Isolate Flow From Ruptured SG(s):
: a. Adjust ruptured SG(s) atmospheric controller setpoint to 1160 PSIG.
: a. Adjust ruptured SG(s) atmospheric controller setpoint to 1160 PSIG.
: b. Check ruptured SG(s) atmospheric - CLOSED  
: b. Check ruptured SG(s) atmospheric - CLOSED
: c. Close ruptured SG(s) main steamline isolation and ensure bypass valve closed.  
: c. Close ruptured SG(s) main steamline isolation and ensure bypass valve closed.
: d. Pull-Out steam supply valve handswitch from ruptured SG(s) to Turbine Driven AFW pump.  
: d. Pull-Out steam supply valve handswitch from ruptured SG(s) to Turbine Driven AFW pump.
: e. Close ruptured SG drippot isolation valve.  
: e. Close ruptured SG drippot isolation valve.
: f. Verify blowdown isolation valves from ruptured SG(s) - CLOSED EXAMINER NOTE: Ensure the booth operator inserts Malfunction to fail ARV open, NOW.
: f. Verify blowdown isolation valves from ruptured SG(s) - CLOSED EXAMINER NOTE: Ensure the booth operator inserts Malfunction to fail ARV open, NOW.
Notes that the #3 ARV is open. Verify the SG pressure is less than 1160, places the controller in manual, and closes the ARV.  
Notes that the #3 ARV is open. Verify the SG pressure is less than 1160, places the controller in manual, and closes the ARV.  
Line 2,108: Line 2,025:


SGTR EOP-3.0A Steam Generator Tube Rupture Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 5 Check Ruptured SG(s) Pressure - GREATER THAN 420 PSIG.
SGTR EOP-3.0A Steam Generator Tube Rupture Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 5 Check Ruptured SG(s) Pressure - GREATER THAN 420 PSIG.
Step 6  Initiate RCS Cooldown:  
Step 6  Initiate RCS Cooldown:
: a. When PRZR pressure decreases to less than 1960 psig, block the low steamline pressure SI signal.  
: a. When PRZR pressure decreases to less than 1960 psig, block the low steamline pressure SI signal.
: b. Determine required core exit temperature from Table 1.
: b. Determine required core exit temperature from Table 1.
NOTE:  It is probable that the temperature selected from the Table will be 485&deg;F. c. Dump steam to condenser from intact SG(s) at maximum rate and avoid main steam isolation.  
NOTE:  It is probable that the temperature selected from the Table will be 485&deg;F. c. Dump steam to condenser from intact SG(s) at maximum rate and avoid main steam isolation.
: 1) Transfer Steam Dump to steam pressure mode. 2) Place the steam pressure controller in manual increase demand. 3) When P-12 (553&deg;F TAVG is reached, select bypass interlock on Steam Dumps and continue cooldown.  
: 1) Transfer Steam Dump to steam pressure mode. 2) Place the steam pressure controller in manual increase demand. 3) When P-12 (553&deg;F TAVG is reached, select bypass interlock on Steam Dumps and continue cooldown.
: d. Core exit TCs - LESS TH AN REQUIRED TEMPERATURE Step 6d RNO Continue with step 7.
: d. Core exit TCs - LESS TH AN REQUIRED TEMPERATURE Step 6d RNO Continue with step 7.
WHEN core exit TCs less than required temperature, THEN do step 6e and 6f.
WHEN core exit TCs less than required temperature, THEN do step 6e and 6f.
Step 7. Check Intact SG Levels:  
Step 7. Check Intact SG Levels:
: a. Narrow Range Level - GREAT ER THAN 5%(26% FOR ADVERSE CONTAINMENT)  
: a. Narrow Range Level - GREAT ER THAN 5%(26% FOR ADVERSE CONTAINMENT)
: b. Control Feed flow to maintain narrow range level between 5% and 50%.
: b. Control Feed flow to maintain narrow range level between 5% and 50%.
Step 8. Check PRZR PORVs and Block Valves:  
Step 8. Check PRZR PORVs and Block Valves:
: a. Power to block valves - AVAILABLE  
: a. Power to block valves - AVAILABLE
: b. PORVs - CLOSED  
: b. PORVs - CLOSED
: c. Block valves - AT LEAST ONE OPEN Step 9. IF the Diesels Are Running, THEN Place Both DG EMER STOP/START Handswitches in START.
: c. Block valves - AT LEAST ONE OPEN Step 9. IF the Diesels Are Running, THEN Place Both DG EMER STOP/START Handswitches in START.
Step 10. Reset SI.
Step 10. Reset SI.
Line 2,134: Line 2,051:
== Description:==
== Description:==


SGTR EOP-3.0A Steam Generator Tube Rupture Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 14. Establish Instrument Air And Nitrogen to Containment.  
SGTR EOP-3.0A Steam Generator Tube Rupture Time  RO  BOP  SRO  Applicant's Actions or Behavior Step 14. Establish Instrument Air And Nitrogen to Containment.
: a. Establish instrument air:  
: a. Establish instrument air:
: 1) Verify air compressor running and establish instrument air to containment.  
: 1) Verify air compressor running and establish instrument air to containment.
: b. Establish nitrogen  
: b. Establish nitrogen
: 1) Verify ACCUM 1-4 VENT CTRL, 1-HC-943 - CLOSED 2) Open SI/PORV ACCUM N2 ISOL VLV, 1/1-8880.
: 1) Verify ACCUM 1-4 VENT CTRL, 1-HC-943 - CLOSED 2) Open SI/PORV ACCUM N2 ISOL VLV, 1/1-8880.
Step 15. Check if RHR Pumps Should be Stopped:  
Step 15. Check if RHR Pumps Should be Stopped:
: a. RCS pressure - GREATER THAN 325 PSIG (425 PSIG FOR ADVERSE CONTAINMENT) b. Stop RHR Pumps and place in standby c. Reset RHR auto switchover.
: a. RCS pressure - GREATER THAN 325 PSIG (425 PSIG FOR ADVERSE CONTAINMENT) b. Stop RHR Pumps and place in standby c. Reset RHR auto switchover.
Step 16. Check If RCS Cooldown Should Be Stopped:  
Step 16. Check If RCS Cooldown Should Be Stopped:
: a. Core exit TC's - LESS THAN REQUIRED TEMPERATURE  
: a. Core exit TC's - LESS THAN REQUIRED TEMPERATURE
: b. Verify Steps 6 e and 6 f are complete.
: b. Verify Steps 6 e and 6 f are complete.
Step 17. Check Ruptured SG(s) Pressure -  STABLE OR INCREASING Step 18. Check RCS subcooling - GREATER THAN 45&deg;F (75&deg;F FOR ADVERSE CONTAINMENT)
Step 17. Check Ruptured SG(s) Pressure -  STABLE OR INCREASING Step 18. Check RCS subcooling - GREATER THAN 45&deg;F (75&deg;F FOR ADVERSE CONTAINMENT)
Step 19. Depressurize the RCS to Minimize Break Flow and Refill PRZR:
Step 19. Depressurize the RCS to Minimize Break Flow and Refill PRZR:
: a. Normal Spray - AVAILABLE b. Place all PRZR heater sw itches in OFF position. c. Spray PRZR with maximum available spray until ANY of the following conditions satisfied: 1) RCS pressure - LESS THAN RUPTURED SG(s)  
: a. Normal Spray - AVAILABLE b. Place all PRZR heater sw itches in OFF position. c. Spray PRZR with maximum available spray until ANY of the following conditions satisfied: 1) RCS pressure - LESS THAN RUPTURED SG(s)  


Line 2,156: Line 2,073:
         *BOLD INDICATES CRITICAL STEP
         *BOLD INDICATES CRITICAL STEP


SHIFT TURNOVER INFORMATION
SHIFT TURNOVER INFORMATION 1.0 INITIAL CONDTIONS:
 
===1.0 INITIAL===
CONDTIONS:
Time in Core Life: BOL Tavg: 589 o F Reactor Power: 100% RCS Pressure: 2235 psig Turbine Load:1200 Mwe Xenon: Equil Boron Concentration:1263 ppm Rod Control:        AUTO Rod Height: CB D @ 215steps 2.0 LCOAR/TECHNICAL SPECIFICATION ACTIONS IN EFFECT:
Time in Core Life: BOL Tavg: 589 o F Reactor Power: 100% RCS Pressure: 2235 psig Turbine Load:1200 Mwe Xenon: Equil Boron Concentration:1263 ppm Rod Control:        AUTO Rod Height: CB D @ 215steps 2.0 LCOAR/TECHNICAL SPECIFICATION ACTIONS IN EFFECT:
TS# Description Reason    3.7.5  AFW                  AFW Pump 1-01 OOS for oil change  
TS# Description Reason    3.7.5  AFW                  AFW Pump 1-01 OOS for oil change 3.0 CLEARANCES IN EFFECT:
 
AFW Pump 1-01 OOS for Oil Change 4.0 SAFETY SYSTEM SETTING BYPASS/MALFUNCTIONS None    5.0  DEGRADED EQUIPMENT 6.0 PLANNED EVOLUTIONS:
===3.0 CLEARANCES===
Return AFW Pump 1-01 to service when the oil change is complete.
IN EFFECT:
7.0 TURNOVER INFORMATION:
AFW Pump 1-01 OOS for Oil Change  
 
===4.0 SAFETY===
SYSTEM SETTING BYPASS/MALFUNCTIONS None    5.0  DEGRADED EQUIPMENT
 
===6.0 PLANNED===
EVOLUTIONS:
Return AFW Pump 1-01 to service when the oil change is complete.  
 
===7.0 TURNOVER===
INFORMATION:
Unit 1 and Unit 2 are at 100% power. U1 has been at 100% for the last 15 days following refueling. The "A" MDAFWP is OOS due to contamination in the oil.
Unit 1 and Unit 2 are at 100% power. U1 has been at 100% for the last 15 days following refueling. The "A" MDAFWP is OOS due to contamination in the oil.
Maintenance is in the process of c hanging the oil and the pump should be ready for test in the next 6 hours. The G eneration Controller has declared an ALERT due to the loss of several peaking plants and all of the Big Brown units due to a common mode failure. There are no surveillance's planned for this shift and the  
Maintenance is in the process of c hanging the oil and the pump should be ready for test in the next 6 hours. The G eneration Controller has declared an ALERT due to the loss of several peaking plants and all of the Big Brown units due to a common mode failure. There are no surveillance's planned for this shift and the  


orders are to maintain current load and unit availability.}}
orders are to maintain current load and unit availability.}}

Revision as of 02:32, 14 July 2019

03-2005-Final-Operating Exam
ML051230435
Person / Time
Site: Comanche Peak  Luminant icon.png
Issue date: 03/25/2005
From:
Operations Branch IV
To:
TXU Power
References
50-445/05-301, 50-446/05-301 50-445/05-301, 50-446/05-301
Download: ML051230435 (178)
v • d • e


Text

Initial License Exam 03/2005 Job Performance Measure JPM: SRO/RO A1.a KEY Page 1 of 5 Rev Date: 1/19/05 System: Conduct of Operations JTA Task #: (New) Task Title: Determine Pressurizer Heater Operability KSA Ref: 2.1.33 PEO: RO: 3.4 SRO: 4.0 Operator's Name:

Performance Environment:

CLASSROOM CONTROL ROOM SIMULATOR Performance Method:

PERFORMED SIMULATED DISCUSSED Time to complete JPM: Estimated 15 minutes Actual The operator's performance was evalua ted against the standards contained in this JPM and was determined to be: SATISFACTORY UNSATISFACTORY Reason, if unsatisfactory:

Evaluator's Signature:

Date: Comments (list all steps not satisfactorily completed):

References:

IPO-001A "Plant Heatup from Cold Shutdown to Hot Standby" Tools, Equipment, Job Aids, etc:

Selected parameters from the plant, captured on of this JPM, and a calculator.

Initial License Exam 03/2005 Job Performance Measure JPM: SRO/RO A1.a KEY Page 2 of 5 Rev Date: 1/19/05 Safety Considerations:

If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:

During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:

Peer checking Three-way communications Phonetic alphabet Self checking ALM use Unit designators Conservative decision making Procedure place keeping Procedure rules of usage Comments:

Instructions:

You may use any approved reference materials, including logs. Make or simulate all written/oral reports as if the evolution is actually being performed. You are expected to discuss all steps you would take, including identifying what switches/i ndications you would use Initiating Cue:

The plant is ready to enter Mode 3. The Unit Supervisor has directed you to determine the operability of the Pressurizer Heaters by performing step 5.3.1 of IPO-001A, "Plant Heatup from Cold Shutdown to Hot Standby". Plant data is provided. Terminating Conditions:

Calculations are complete and an Operability determination has been made.

Initial License Exam 03/2005 Job Performance Measure JPM: SRO/RO A1.a KEY Page 3 of 5 Rev Date: 1/19/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 1 Provide the candidate with the initiating cue, the plant data sheet, and a copy of IPO-001A step 5.3.1.

Note Start time.

2 Candidate correctly transfers data to the procedure.

See Attached Key 3 Candidate performs calculations.

See Attached Key

  • 4 Candidate determines operability TASK COMPLETE. B/U Heater Groups A, B and Control Heater Group C are OPERABLE. B/U Heater Group D is INOPERABLE Note Completion time.

Initial License Exam 03/2005 Job Performance Measure JPM: SRO/RO A1.a KEY Page 4 of 5 Rev Date: 1/19/05 INITIATING CUE:

The plant is ready to enter Mode 3. The Unit Superv isor has directed you to determine the operability of the Pressurizer Heaters by performing step 5.3.1 of IPO-001A, "Plant Heatup from Cold Shutdown to Hot Standby". Plant data is provided.

Plant Data Parameter Value from Last Reading Sheets (OPT-XXX)

Current Value 1/1-PCPR1 Amps 580 580 1/1-PCPR Amps 0 200 1/1-PCPR2 Amps 565 565 1/1P-CPR3 Amps 0 176 1B1 Volts 474 468 1B2 Volts 483 476 1B3 Volts 476 470 1B4 Volts 485 480 PC point V6303A 487.2 486.9 PC point V6302A 488.1 487.1 PC point V6301A 487.2 486.9 PC point V6304A 488.3 487.1 PC point A6801A 571.2 570.1 PC point A6802A 0 193 PC point A6803A 559.8 560 PC point A6804A 0 176 1EA1 Amps 282.7 261.4 1EA2 Amps 358.5 423.7 NOTE: The candidate can use either the MCB meter amperages or the plant computer values for heater amperages. The IPO allows both and there is no significant difference.

NOTE: The shaded parameters should NOT be used. The following problems exist with the shaded data: 1. The pressurizer heaters are supplied by 1EB1-4, NOT 1B1-4 2. 1EA1/2 amperage is not necessary to complete the calculations. 3. Data from the last set of logs should NOT be used for the Operability determination. Plant conditions could have changed significantly si nce the readings were taken. The IPO wants current plant data to determine Operability.

Initial License Exam 03/2005 Job Performance Measure JPM: SRO/RO A1.a KEY Page 5 of 5 Rev Date: 1/19/05 Circle the correct status for each Bank of Pressurizer Heaters Heater Bank Status Status B/U Heater Grp. A Operable Inoperable B/U Heater Grp. B Operable Inoperable Control Grp. C Operable Inoperable B/U Heater Grp. D Operable Inoperable Example of the completed procedure:

5.3 Heatup And Pressurization For MODE 3 Entry

[C] This section describes steps for heatup and pressurization to enter MODE 3. 5.3.1 Verify at least two groups of pressurizer heaters have a capacity of at least 150KW each.(TS SR 3.4.9.2) A. Energize each group of heaters, as required, to measure current. _____

B. Record voltage and current AND calculate power for each group of heaters. (Voltage x current x 0.001732 = power)

Backup Heater Group A 1EB3 1-II-PCPR1or Or 486.9__x or _570.1 _

x 0.001732 =

480.77 KW _____

V6303A A6801A Backup Heater Group B 1EB2- 1-II-PCPR2 or 487.1 x or _193 _

x 0.001732 =

162.8 KW _____

V6302A A6803A  ! Control Heater Group C 1EB1 1-II-PCPR or 486.9 x or __560 x 0.001732 =

_472.54_ KW _____

V6301A A6803A  ! Backup Heater Group D 1EB4 1-II-PCPR3 or 487.1 x or _176 x 0.001732 =

__148.5__ KW _____

V6304A A6804A C. Operate pressurizer heaters as needed for plant conditions. _____

D. IF any group(s) of pressurizer heaters does NOT have a capacity of > 150KW, THEN initiate a LCOAR per ODA-308. _____

Initial License Exam 03/2005 Job Performance Measure JPM: RO A1.b KEY Page 1 of 8 Rev Date: 1/24/05 System: Conduct of Operations JTA Task #: (New) Task Title: Calculate RCS Leakrate KSA Ref: 2.1.23 PEO: RO: 3.9 SRO: 4.0 Operator's Name:

Performance Environment:

CLASSROOM CONTROL ROOM SIMULATOR Performance Method:

PERFORMED SIMULATED DISCUSSED Time to complete JPM: Estimated 15 minutes Actual The operator's performance was evalua ted against the standards contained in this JPM and was determined to be: SATISFACTORY UNSATISFACTORY Reason, if unsatisfactory:

Evaluator's Signature:

Date: Comments (list all steps not satisfactorily completed):

References:

ABN-103 "Excessive Reactor Coolant Leakage" Tools, Equipment, Job Aids, etc:

Selected parameters from the plant, captured on of this JPM, and a calculator.

Initial License Exam 03/2005 Job Performance Measure JPM: RO A1.b KEY Page 2 of 8 Rev Date: 1/24/05 Safety Considerations:

If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:

During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:

Peer checking Three-way communications Phonetic alphabet Self checking ALM use Unit designators Conservative decision making Procedure place keeping Procedure rules of usage Comments:

Instructions:

You may use any approved reference materials, including logs. Make or simulate all written/oral reports as if the evolution is actually being performed. You are expected to discuss all steps you would take, including identifying what switches/i ndications you would use Initiating Cue:

The plant is operating at 100% pow er, BOL. The crew is resp onding to the indications of a Reactor Coolant System leak. The Unit Supervisor has directed you to determine the size of the leak by performing Attachment 1 of ABN-103, "Excessive Reactor Coolant Leakage". Plant data is provided. Terminating Conditions:

Calculations are complete and a RCS Leak Rate determination has been made.

Initial License Exam 03/2005 Job Performance Measure JPM: RO A1.b KEY Page 3 of 8 Rev Date: 1/24/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 1 Provide the candidate with the initiating cue, the plant data sheet, and a copy of ABN-103 Attachment 1.

Note Start time.

2 Candidate correctly transfers data to the procedure.

See Attached Key 3 Candidate performs calculations.

See Attached Key

  • 4 Candidate determines operability TASK COMPLETE. Leak rate is determined to be approx 5 gpm.

See key for allowed variances in parameters Note Completion time.

Initial License Exam 03/2005 Job Performance Measure JPM: RO A1.b KEY Page 4 of 8 Rev Date: 1/24/05 INITIATING CUE:

Parameter Value at 1258:15 Value at 1312:15 CHG FLO (F6138A) 141.5 145.1 LTDN FLO (F6134A) 130.89 130.93 FR-157 (RCP 1 Leak Off) 2.8 2.8 FR-156 (RCP 1 Leak Off) 2.8 2.8 FR-155 (RCP 1 Leak Off) 2.8 2.8 FR-154 (RCP 1 Leak Off) 2.8 2.8 VCT LVL (L6112A) 46.5 53.3 T0400A (Loop 1 Tave) 589.8 589.2 T0420A (Loop 2 Tave) 588.6 587.9 T0440A (Loop 3 Tave) 589.7 589.1 T0460A (Loop 4 Tave) 588.7 588.1 L6480A (PZR Level 1) 59.58 56.6 L6481A (PZR Level 2) 59.58 56.6 L6482A (PZR Level 3) 59.58 56.6 NOTE: The VCT was filled by Automatic make-up at 1302. There we no diversions of letdown flow during this period.

Initial License Exam 03/2005 Job Performance Measure JPM: RO A1.b KEY Page 5 of 8 Rev Date: 1/24/05 Example of the completed procedure:

Alternative #1 RCS Leak at 16 gpm Parameter Value at 1258:15 Value at 1312:15 CHG FLO (F6138A) 141.5 145.1 LTDN FLO (F6134A) 130.89 130.93 FR-157 (RCP 1 Leak Off) 2.8 2.8 FR-156 (RCP 1 Leak Off) 2.8 2.8 FR-155 (RCP 1 Leak Off) 2.8 2.8 FR-154 (RCP 1 Leak Off) 2.8 2.8 VCT LVL (L6112A) 46.5 53.3 T0400A (Loop 1 Tave) 589.8 589.2 T0420A (Loop 2 Tave) 588.6 587.9 T0440A (Loop 3 Tave) 589.7 589.1 T0460A (Loop 4 Tave) 588.7 588.1 L6480A (PZR Level 1) 59.58 56.6 L6481A (PZR Level 2) 59.58 56.6 L6482A (PZR Level 3) 59.58 56.6 NOTE: The VCT was filled by Automatic make-up at 1302. There we no diversions of letdown flow during this period.

Initial License Exam 03/2005 Job Performance Measure JPM: RO A1.b KEY Page 6 of 8 Rev Date: 1/24/05 CPSES ABNORMAL CONDITIONS PROCEDURES MANUAL UNIT 1 AND 2 PROCEDURE NO.

ABN-103 EXCESSIVE REACTOR COOLANT LEAKAGE REVISION NO 8 PAGE 22 OF 28 ATTACHMENT 1 PAGE 2 OF 2 PARAMETER INITIAL VALUE FINAL VALUE AVERAGE VALUE TIME (-) ___1258___ + ____1312____ = ____14___ t

  • CHRG FLO (F6138A) ___141.5____ + ___131.2____

(____________286.6____________) 2 = __143.3__ GPM

  • LTDN HX OUT FLOW (F6134A) ____130.89___ + ___130.93___

(___________261.82____________) 2 = __130.91__ GPM

  • RCP SEAL LKOFF FLO (FR-157, 156, 155

& 154) __2.8____ + ____2.8___

(____________5.6______________.) 2 = ____2.8__ GPM

  • VCT LVL (L6112A) (________ - ________)(19.4gal/%)

(________________________________) (__________)t in MIN)

= _________ GPM RC LOOP 1-4 TAVE (T0400A,T0420A,T0440A OR T0460A)

(__589.2__ - __588.6__)(93gal/°F)

(________55.8________________) (___14___)t in MIN)

= ___3.98__ GPM PRZR LVL (L6480A,L6481A OR L6482A) (_59.58___ - __56.6___)(65gal/%)

(_________193.7_______________) (__14____)t in MIN)

= __13.84__ GPM CALCULATION FORMULA Flow adjust method: (+) _143.3__

CHRG FLO -_130.91_

LTDN FLOW -__2.8__ SEAL LKOFF FLO -(+ )_3.98__

TAVG ADJUST

+( )13.84__

PRZR LVL ADJUST = _27.41_GPM RCS LEAKAGE OR VCT level adjust method ( )_________ VCT LVL ADJUST

-( )______ TAVG ADJUST +( )________

PRZR LVL ADJUST = ______GPM RCS LEAKAGE

  • Either Chrg Flo, Ltdn Flow, and RCP Seal Lkoff Flo (Flow adjust method) OR VCT Lvl (VCT level adjust method) should be used, but NOT both.

Attachment 1 Initial License Exam 03/2005 Job Performance Measure JPM: RO A1.b KEY Page 7 of 8 Rev Date: 1/24/05 Alternative #2 RCS Leak at 5 gpm Parameter Value at 1258:15 Value at 1312:15 CHG FLO (F6138A) 140.7 143.8 LTDN FLO (F6134A) 130.9 130.9 FR-157 (RCP 1 Leak Off) 2.8 2.8 FR-156 (RCP 1 Leak Off) 2.8 2.8 FR-155 (RCP 1 Leak Off) 2.8 2.8 FR-154 (RCP 1 Leak Off) 2.8 2.8 VCT LVL (L6112A) 52.8 50.4 T0400A (Loop 1 Tave) 589.8 589.8 T0420A (Loop 2 Tave) 588.6 588.6 T0440A (Loop 3 Tave) 589.7 589.7 T0460A (Loop 4 Tave) 588.7 588.7 L6480A (PZR Level 1) 60 59.5 L6481A (PZR Level 2) 60 59.5 L6482A (PZR Level 3) 60 59.5 NOTE: There was no VCT auto make-up. There we no diversions of letdown flow during this period.

Initial License Exam 03/2005 Job Performance Measure JPM: RO A1.b KEY Page 8 of 8 Rev Date: 1/24/05 CPSES ABNORMAL CONDITIONS PROCEDURES MANUAL UNIT 1 AND 2 PROCEDURE NO.

ABN-103 EXCESSIVE REACTOR COOLANT LEAKAGE REVISION NO 8 PAGE 22 OF 28 ATTACHMENT 1 PAGE 2 OF 2 PARAMETER INITIAL VALUE FINAL VALUE AVERAGE VALUE TIME (-) __1429____ + __1446____ = ____17___ t

  • CHRG FLO (F6138A) __140.7____ + ___143.8___

(__________284.5____________) 2 = __142.25___ GPM

  • LTDN HX OUT FLOW (F6134A) ___130.9__ + ___130.9___

(__________261.8______________) 2 = __130.9__ GPM

  • RCP SEAL LKOFF FLO (FR-157, 156, 155

& 154) ___2.8______ + ____2.8____

(___________5.6______________

.) 2 = ___2.8___ GPM

  • VCT LVL (L6112A) (_52.8___ - __50.4___)(19.4gal/%)

(_________46.56__________________) (__17____)t in MIN)

= __2.74___ GPM RC LOOP 1-4 TAVE (T0400A,T0420A,T0440A OR T0460A)

(________ - ________)(93gal/°F)

(_____________0__________________) (_____17_____)t in MIN)

= ____0___ GPM PRZR LVL (L6480A,L6481A OR L6482A) (_60___ - ___59.5__)(65gal/%)

(_________32.5___________________) (__17_____)t in MIN)

= ___1.9___ GPM Shaded areas NOT REQUIRED CALCULATION FORMULA Flow adjust method: (+) ________

CHRG FLO -________

LTDN FLOW -________

SEAL LKOFF FLO -( )_________

TAVG ADJUST

+( )________

PRZR LVL ADJUST = ______GPM RCS LEAKAGE OR VCT level adjust method ( )__2.74___ VCT LVL ADJUST

-( )_0___ TAVG ADJUST +(+ )__1.9__

PRZR LVL ADJUST = __4.65_GPM RCS LEAKAGE

  • Either Chrg Flo, Ltdn Flow, and RCP Seal Lkoff Flo (Flow adjust method) OR VCT Lvl (VCT level adjust method) should be used, but NOT both.

Attachment 1

Initial License Exam 03/2005 Job Performance Measure JPM: RO A3

-KEY- Page 1 of 5 Rev Date: 2/7/05 System: Radiation Control JTA Task #: (New) Task Title: Evaluate Radiological Condition for Task Performance KSA Ref: 2.3.10 PEO: RO: 2.9 SRO: 3.3 Operator's Name:

Performance Environment:

CLASSROOM CONTROL ROOM SIMULATOR Performance Method:

PERFORMED SIMULATED DISCUSSED Time to complete JPM: Estimated 15 minutes Actual The operator's performance was evalua ted against the standards contained in this JPM and was determined to be: SATISFACTORY UNSATISFACTORY Reason, if unsatisfactory:

Evaluator's Signature:

Date: Comments (list all steps not satisfactorily completed):

References:

GAP# 2005-01 STA-656 RPI-606 Tools, Equipment, Job Aids, etc:

Copy of the GAP and the applicable Survey Map for the task.

Initial License Exam 03/2005 Job Performance Measure JPM: RO A3

-KEY- Page 2 of 5 Rev Date: 2/7/05 Safety Considerations:

If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:

During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:

Peer checking Three-way communications Phonetic alphabet Self checking ALM use Unit designators Conservative decision making Procedure place keeping Procedure rules of usage Comments:

Instructions:

You may use any approved reference materials, including logs. Make or simulate all written/oral reports as if the evolution is actually being performed. You are expected to discuss all steps you would take, including identifying what switches/i ndications you would use Initiating Cue:

You are on tour in the Safeguards Building. The US directs you to isolate the air to HV-8152.

You are to evaluate the radiolog ical condition in the area and provide the requested information. Terminating Conditions:

Answers to questions are pr ovided to the evaluator.

Initial License Exam 03/2005 Job Performance Measure JPM: RO A3

-KEY- Page 3 of 5 Rev Date: 2/7/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 1 Provide the candidate with the initiating cue, the GAP and the Survey Map.

Note Start time.

  • 2 Candidate correctly answers two of the three questions.

TASK COMPLETE. See Attached Key Note Completion time

Initial License Exam 03/2005 Job Performance Measure JPM: RO A3

-KEY- Page 4 of 5 Rev Date: 2/7/05 INITIATING CUE:

You are on tour in the Safeguards Building. The US directs you to isolate the air to HV-8152. You are to evaluate the radiological condition in the area and provide the requested information.

NOTE: Circle the correct answers to the following questions and provide the evaluator with your completed paperwork.

1. The area where the valve is located is a:

A) Locked High Radiation Area B) Contaminated Area C) Posted High Radiation Area D) General Radiation Area

2. If the area where the air isolation valve is located is a 60 mr/hr field, how long before your dosimeter will alarm if it is at the lower setting allowed by the GAP.

A) Immediately B) 5 minutes C) 25 minutes D) 2.5 minutes

3. Circle three areas on the Survey Map that require contact with RP prior to entry.

Initial License Exam 03/2005 Job Performance Measure JPM: RO A3

-KEY- Page 5 of 5 Rev Date: 2/7/05

-KEY- INITIATING CUE:

You are on tour in the Safeguards Building. The US directs you to isolate the air to HV-8152. You are to evaluate the radiological condition in the area and provide the requested information.

NOTE: Circle the correct answers to the following questions and provide the evaluator with your completed paperwork.

1. The area where the valve is located is a:

E) Locked High Radiation Area F) Contaminated Area G) Posted High Radiation Area H) General Radiation Area

2. If the area where the air isolation valve is located is a 60 mr/hr field, how long before your dosimeter will alarm if it is at the lower setting allowed by the GAP.

E) Immediately F) 5 minutes G) 25 minutes H) 2.5 minutes

3. Circle three areas on the Survey Map that require contact with RP prior to entry.
1) High Radiation area where the valve to be operated is. 2) The CA I/S Pit 3) Platform on the south end of the room.

The RWP map was removed from this page of the exam by the chief examiner because it was considered potential SUNSI material due to the equipment locations on the map.

Initial License Exam 03/2005 Job Performance Measure JPM: SRO/RO A1.a KEY Page 1 of 5 Rev Date: 1/19/05 System: Conduct of Operations JTA Task #: (New) Task Title: Determine Pressurizer Heater Operability KSA Ref: 2.1.33 PEO: RO: 3.4 SRO: 4.0 Operator's Name:

Performance Environment:

CLASSROOM CONTROL ROOM SIMULATOR Performance Method:

PERFORMED SIMULATED DISCUSSED Time to complete JPM: Estimated 15 minutes Actual The operator's performance was evalua ted against the standards contained in this JPM and was determined to be: SATISFACTORY UNSATISFACTORY Reason, if unsatisfactory:

Evaluator's Signature:

Date: Comments (list all steps not satisfactorily completed):

References:

IPO-001A "Plant Heatup from Cold Shutdown to Hot Standby" Tools, Equipment, Job Aids, etc:

Selected parameters from the plant, captured on of this JPM, and a calculator.

Initial License Exam 03/2005 Job Performance Measure JPM: SRO/RO A1.a KEY Page 2 of 5 Rev Date: 1/19/05 Safety Considerations:

If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:

During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:

Peer checking Three-way communications Phonetic alphabet Self checking ALM use Unit designators Conservative decision making Procedure place keeping Procedure rules of usage Comments:

Instructions:

You may use any approved reference materials, including logs. Make or simulate all written/oral reports as if the evolution is actually being performed. You are expected to discuss all steps you would take, including identifying what switches/i ndications you would use Initiating Cue:

The plant is ready to enter Mode 3. The Unit Supervisor has directed you to determine the operability of the Pressurizer Heaters by performing step 5.3.1 of IPO-001A, "Plant Heatup from Cold Shutdown to Hot Standby". Plant data is provided. Terminating Conditions:

Calculations are complete and an Operability determination has been made.

Initial License Exam 03/2005 Job Performance Measure JPM: SRO/RO A1.a KEY Page 3 of 5 Rev Date: 1/19/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 1 Provide the candidate with the initiating cue, the plant data sheet, and a copy of IPO-001A step 5.3.1.

Note Start time.

2 Candidate correctly transfers data to the procedure.

See Attached Key 3 Candidate performs calculations.

See Attached Key

  • 4 Candidate determines operability TASK COMPLETE. B/U Heater Groups A, B and Control Heater Group C are OPERABLE. B/U Heater Group D is INOPERABLE Note Completion time.

Initial License Exam 03/2005 Job Performance Measure JPM: SRO/RO A1.a KEY Page 4 of 5 Rev Date: 1/19/05 INITIATING CUE:

The plant is ready to enter Mode 3. The Unit Superv isor has directed you to determine the operability of the Pressurizer Heaters by performing step 5.3.1 of IPO-001A, "Plant Heatup from Cold Shutdown to Hot Standby". Plant data is provided.

Plant Data Parameter Value from Last Reading Sheets (OPT-XXX)

Current Value 1/1-PCPR1 Amps 580 580 1/1-PCPR Amps 0 200 1/1-PCPR2 Amps 565 565 1/1P-CPR3 Amps 0 176 1B1 Volts 474 468 1B2 Volts 483 476 1B3 Volts 476 470 1B4 Volts 485 480 PC point V6303A 487.2 486.9 PC point V6302A 488.1 487.1 PC point V6301A 487.2 486.9 PC point V6304A 488.3 487.1 PC point A6801A 571.2 570.1 PC point A6802A 0 193 PC point A6803A 559.8 560 PC point A6804A 0 176 1EA1 Amps 282.7 261.4 1EA2 Amps 358.5 423.7 NOTE: The candidate can use either the MCB meter amperages or the plant computer values for heater amperages. The IPO allows both and there is no significant difference.

NOTE: The shaded parameters should NOT be used. The following problems exist with the shaded data: 1. The pressurizer heaters are supplied by 1EB1-4, NOT 1B1-4 2. 1EA1/2 amperage is not necessary to complete the calculations. 3. Data from the last set of logs should NOT be used for the Operability determination. Plant conditions could have changed significantly si nce the readings were taken. The IPO wants current plant data to determine Operability.

Initial License Exam 03/2005 Job Performance Measure JPM: SRO/RO A1.a KEY Page 5 of 5 Rev Date: 1/19/05 Circle the correct status for each Bank of Pressurizer Heaters Heater Bank Status Status B/U Heater Grp. A Operable Inoperable B/U Heater Grp. B Operable Inoperable Control Grp. C Operable Inoperable B/U Heater Grp. D Operable Inoperable Example of the completed procedure:

5.3 Heatup And Pressurization For MODE 3 Entry

[C] This section describes steps for heatup and pressurization to enter MODE 3. 5.3.1 Verify at least two groups of pressurizer heaters have a capacity of at least 150KW each.(TS SR 3.4.9.2) A. Energize each group of heaters, as required, to measure current. _____

B. Record voltage and current AND calculate power for each group of heaters. (Voltage x current x 0.001732 = power)

Backup Heater Group A 1EB3 1-II-PCPR1or Or 486.9__x or _570.1 _

x 0.001732 =

480.77 KW _____

V6303A A6801A Backup Heater Group B 1EB2- 1-II-PCPR2 or 487.1 x or _193 _

x 0.001732 =

162.8 KW _____

V6302A A6803A  ! Control Heater Group C 1EB1 1-II-PCPR or 486.9 x or __560 x 0.001732 =

_472.54_ KW _____

V6301A A6803A  ! Backup Heater Group D 1EB4 1-II-PCPR3 or 487.1 x or _176 x 0.001732 =

__148.5__ KW _____

V6304A A6804A C. Operate pressurizer heaters as needed for plant conditions. _____

D. IF any group(s) of pressurizer heaters does NOT have a capacity of > 150KW, THEN initiate a LCOAR per ODA-308. _____

Initial License Exam 03/2005 Job Performance Measure JPM: SRO A1.b Page 1 of 4 Rev Date: 1/19/05 System: Administrative Procedures JTA Task #: (Bank 2001) Task Title:

Determine Staff Working Hours KSA Ref: 2.1.5 PEO: RO: 2.3 SRO: 3.4 Operator's Name:

Performance Environment:

CLASSROOM CONTROL ROOM SIMULATOR Performance Method:

PERFORMED SIMULATED DISCUSSED Time to complete JPM: Estimated 10 minutes Actual The operator's performance was evalua ted against the standards contained in this JPM and was determined to be: SATISFACTORY UNSATISFACTORY Reason, if unsatisfactory:

Evaluator's Signature:

Date: Comments (list all steps not satisfactorily completed):

References:

Technical Specifications STA-615, "Staff Work Hours" Tools, Equipment, Job Aids, etc:

Technical Specifications STA-615, "Staff Work Hours"

Initial License Exam 03/2005 Job Performance Measure JPM: SRO A1.b Page 2 of 4 Rev Date: 1/19/05 Safety Considerations:

If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:

During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:

Peer checking Three-way communications Phonetic alphabet Self checking ALM use Unit designators Conservative decision making Procedure place keeping Procedure rules of usage Comments:

Instructions:

You may use any approved reference materials, including logs with the exeption of the Plant Computer. Make or simulate all written/oral reports as if th e evolution is actually being performed. You are expected to discuss all steps you would ta ke, including identifying what switches/indications you would use Initiating Cue:

You are the Unit Supervisor and one of the assigned ROs called in sick. You need to find a replacement RO. Assuming today is March 23 (0630), based on the work hour history evaluate whether any of the following 5 ROs could perform safety-related functions until 1830 without advanced approval. For each candidate indicate whether the answer is yes or no. 1. RO1 has been on-shift since 0200 (March 23). 2. On March 22, RO2 worked from 0630 until 1900 (includes a 1/2 hour shift turnover). 3. RO3 worked from 1430 on March 22 to 0030 on March 23. 4. RO4 has been on vacation for the past two days (March 21 and 22), but worked 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> on March 17, 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> on March 18, 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> on March 19, and 14 hours1.62037e-4 days <br />0.00389 hours <br />2.314815e-5 weeks <br />5.327e-6 months <br /> on March 20. 5. On March 22, RO5 worked from 0630 until 1930 (includes a 1/2 hour shift turnover).

Terminating Conditions:

Determine that 2 out of the 5 ROs available meet the work hour requirement to relieve the shift.

Initial License Exam 03/2005 Job Performance Measure JPM: SRO A1.b Page 3 of 4 Rev Date: 1/19/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 1 Provide candidate with completed copy of the initiating cue Candidate should review Admin JPM and initiating cue Note Start time.

  • 2 Review work hour history and determine that only 2 of the 5 ROs could work without advanced approval.

TASK COMPLETE RO1 - no, would work

16.5 hrs straight RO2 - Yes, would work

24 hrs in 48 hrs RO3 - No, less than 8

hours between work periods RO4 -Yes, would work 70 hrs in 7 days RO5 - No, would work

24.5 hrs in 48 hrs.

Pass criteria is 4 of the 5 ROs work hour status being correctly determined No - cannot work Yes - can work Note Completion time.

Initial License Exam 03/2005 Job Performance Measure JPM: SRO A1.b Page 4 of 4 Rev Date: 1/19/05 INITIATING CUE:

You are the Unit Supervisor and one of the assigned ROs called in sick. You need to find a replacement RO. Assuming today is March 23 (0630), based on the work hour history evaluate whether any of the following 5 ROs could perform safety-related functions until 1830 without advanced approval. For each candidate indicate whether the answer is yes or no.

1. RO1 has been on-shift since 0200 (March 23). 2. On March 22, RO2 worked from 0630 until 1900 (includes a 1/2 hour shift turnover). 3. RO3 worked from 1430 on March 22 to 0030 on March 23. 4. RO4 has been on vacation for the past two days (March 21 and 22), but worked 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> on March 17, 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> on March 18, 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> on March 19, and 14 hours1.62037e-4 days <br />0.00389 hours <br />2.314815e-5 weeks <br />5.327e-6 months <br /> on March 20. 5. On March 22, RO5 worked from 0630 until 1930 (includes a 1/2 hour shift turnover).

Initial License Exam JPM: SROA2 0312005 KEY Job Performance Measure system: Equipment Control JTA Task #: (New) Task Title: Complete Technical Specification Paperwork for INOP PZR Heaters (Tracking LOCAR)

KSA Ref: 2.2-23 PEO: RO: 2.6 SRO: 3.8 Operator's Name: Performance Environment:

CLASSROOM CONTROL ROOM SIMULATOR Performance Method: PERFORMED SIMULATED DISCUSSED Time to complete JPM: Estimated 15 minutes Actual The operator's performance was evaluated against the standards contained in this JPM and was determined to be: SATISFACTORY UNSATISFACTORY Reason, if unsatisfactory: Evaluator's Signature: Date: Comments (list steps not satisfactorily completed):

References:

ODA-308 Technical Specification 3.4.9 Tools, Equipment, Job Aids, etc:

Blank LOCAR Form. Page 1 of 4 Rev Date: 2/7/05 Initial License Exam Job Performance Measure PM: SROA2 Safety Considerations:

If this JPM is to be performed in the planthontrol room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor.

Human Performance Measures: During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:

Peer checking Three-way communications Phonetic alphabet Self checking ALM use Unit designators Conservative decision making Procedure place keeping Procedure rules of usage Comments:

Instructions:

You may use any approved reference materials, including logs. Make or simulate all writtedoral reports as if the evolution is actually being performed.

You are expected to discuss all steps you would take, including identifying what switcheshdications you would use Initiating Cue:

Bank D of the Pressurizer Heaters was declared INOPERABLE today at 083 1 due to KW output less than minimum. You have been directed to fill out the Tracking LOCAR.

Because of a server problem, the electronic LOCAR system is unavailable.

The SM has called the Prompt team and they will call with the LOCAR number when it is generated. Terminating Conditions: Completed Tracking LOCAR provided to the evaluator.

Page 2 of 4 Rev Date: 2/7/05 Initial License Exam JPM: SROA2 P STEP# *Critical 1 "2 03/2005 Job Performance Measure ELEMENT Provide the candidate with the initiating cue, the applicable Technical specification and the blank LOCAR form.. Candidate correctly fills out the form. The KEY indicates the required minimum fields. Three of the four minimum fields must be correct to pass the JPM. TASK COMPLETE.

STANDARD See Attached Key Note Completion time NOTES Note Start time.

SAT/ IJNSAT Page 3 of 4 Rev Date: 2/7/05 Initial License Exam 03/2005 Job Performance Measure JPM: SROA2 INITIATING CUE: Bank D of the Pressurizer Heaters was declared INOPERABLE today at 083 1 due to KW output less than minimum.

You have been directed to fill out the Tracking LOCAR. Because of a server problem, the electronic LOCAR system is unavailable.

The SM has called the Prompt team and they will call with the LOCAR number when it is generated.

Page 4 of 4 Rev Date:

2/7/05 Pressurizer 3.4.9 SURVEILLANCE SR 3.4.9.1 Verify pressurizer water ievel is 592%. ACTIONS (continued)

FREQUENCY 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> CONDITION SR 3.4.9.2 Verify capacity of each required group of pressurizer heaters is 2 150 kW. B. One required group of pressurizer heaters inoperable.

18 months C. Required Action and associated Completion Time of Condition B not met. REQUIRED ACTION B. 1 Restore required group of pressurizer heaters to OPERABLE status. c. 1 Be in MODE 3. c.2 Be in MODE 4. COMPLETION TIME 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> 6 hours 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> COMANCHE PEAK - UNITS 1 AND 2 3.4-20 Amendment No. 64 Pressurizer 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.9 Pressurizer LCO 3.4.9 The pressurizer shall be OPERABLE with: a. Pressurizer water level 592%; and b. Two groups of pressurizer heaters OPERABLE with the capacity of each group 2 150 kW. APPLICABILITY:

MODES 1, 2, and 3 ACT IONS CONDITION A. Pressurizer water level not within limit. REQUIRED ACTION A. 1 Be in MODE 3. A.2 Fully insert all rods. A.3 Place Rod Control System in a condition incapable of rod withdrawal.

A.4 Be in MODE 4. COMANCHE PEAK - UNITS 1 AND 2 3.4-1 9 COMPLETION TIME 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 6 hours 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 12 hours (con tin ued) Amendment No. 64 a 0 0 a 8 Y s P ol In .- 01 E I=- 3 \ 0" s C 0 aJ .- Y - n U . i v) E l-c a, a, 6 IIIIIIIII IIIIIIIII IIIIIIIII IIIIIIIII 11111111I IIIIIIIII IIIIIIIII IIIIIIIII iiiiiiiii IIIIIIIII IIIIIIIII IIIIIIIII IIIIIIIII . . . . . . . . . QI I I I I I I I I AI I I I I I I I I *IlIIIIIII I I .I .I .I .I .I .I . I IIIIIIIII 81 . \ I I I I I I I I 4 I I I I I I I I YJl I I I I I I I \I,* I I It I I I II~IIIII 31IIIIIII IIIIIIII 4 I I I I I I I I 4IIIIIIII 3 PI I I I I I I I I IIIIIIIII rn m - .- .- c - 0 ? 5 E d i= . a, c D 1 - E u P El 0 a D E! 8 >. El .. D a, .K 0 2 c a, .K 0) K 0 3 K .- c .- c s 0 I- z w 5 E 2 B a: 3 CY z I- 0 w I- . . E 5 d 3 a, E $28 BBd czc mam cv LL TO . ... i: a, m m r" .. a, z E . c .- 5 E a D 0 g! . ! f d

  • 2 a, c K 0 m .- c .- a, I- 0 4-s .= .= 55 c ; -0 m a, -1 .. 0 z E b U T! 0 .. 0 z .. a, c d rnrn 56 .. .. a,a, cc zz .. cc .- .- KK 33 .. D a, m D c 9 rn g 0 m Initial License Exam 03/2005 Job Performance Measure JPM: SRO A3

-KEY- Page 1 of 4 Rev Date: 2/7/05 System: Radiation Control JTA Task #: (New) Task Title: Evaluate Radiological Condition for Task Performance KSA Ref: 2.3.10 PEO: RO: 2.9 SRO: 3.3 Operator's Name:

Performance Environment:

CLASSROOM CONTROL ROOM SIMULATOR Performance Method:

PERFORMED SIMULATED DISCUSSED Time to complete JPM: Estimated 15 minutes Actual The operator's performance was evalua ted against the standards contained in this JPM and was determined to be: SATISFACTORY UNSATISFACTORY Reason, if unsatisfactory:

Evaluator's Signature:

Date: Comments (list all steps not satisfactorily completed):

References:

GAP# 2005-01 STA-656 RPI-606 Tools, Equipment, Job Aids, etc:

Copy of the GAP and the applicable Survey Map for the task.

Initial License Exam 03/2005 Job Performance Measure JPM: SRO A3

-KEY- Page 2 of 4 Rev Date: 2/7/05 Safety Considerations:

If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:

During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:

Peer checking Three-way communications Phonetic alphabet Self checking ALM use Unit designators Conservative decision making Procedure place keeping Procedure rules of usage Comments:

Instructions:

You may use any approved reference materials, including logs. Make or simulate all written/oral reports as if the evolution is actually being performed. You are expected to discuss all steps you would take, including identifying what switches/i ndications you would use Initiating Cue:

You are on tour in the Safeguards Building. The US directs you to isolate the air to HV-8152.

You are to evaluate the radiolog ical condition in the area and provide the requested information. Terminating Conditions:

Answers to questions are pr ovided to the evaluator.

Initial License Exam 03/2005 Job Performance Measure JPM: SRO A3

-KEY- Page 3 of 4 Rev Date: 2/7/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 1 Provide the candidate with the initiating cue, the GAP and the Survey Map.

Note Start time.

  • 2 Candidate correctly answers two of the three questions.

TASK COMPLETE. See Attached Key Note Completion time

Initial License Exam 03/2005 Job Performance Measure JPM: SRO A3

-KEY- Page 4 of 4 Rev Date: 2/7/05 INITIATING CUE:

You are on tour in the Safeguards Building. The US directs you to isolate the air to HV-8152. You are to evaluate the radiological condition in the area and provide the requested information.

NOTE: Circle the correct answers to the following questions and provide the evaluator with your completed paperwork.

1. The area where the valve is located is a:

A) Locked High Radiation Area B) Contaminated Area C) Posted High Radiation Area D) General Radiation Area

2. If the area where the air isolation valve is located is a 60 mr/hr field, how long before your dosimeter will alarm if it is at the lower setting allowed by the GAP.

A) Immediately B) 5 minutes C) 25 minutes D) 2.5 minutes

3. Circle three areas on the Survey Map that require contact with RP prior to entry.

Initial License Exam 03/2005 Job Performance Measure JPM: SRO A3

-KEY- Page 5 of 4 Rev Date: 2/7/05

-KEY- INITIATING CUE:

You are on tour in the Safeguards Building. The US directs you to isolate the air to HV-8152. You are to evaluate the radiological condition in the area and provide the requested information.

NOTE: Circle the correct answers to the following questions and provide the evaluator with your completed paperwork.

1. The area where the valve is located is a:

E) Locked High Radiation Area F) Contaminated Area G) Posted High Radiation Area H) General Radiation Area

2. If the area where the air isolation valve is located is a 60 mr/hr field, how long before your dosimeter will alarm if it is at the lower setting allowed by the GAP.

E) Immediately F) 5 minutes G) 25 minutes H) 2.5 minutes

3. Circle three areas on the Survey Map that require contact with RP prior to entry.
1) High Radiation area where the valve to be operated is. 2) The CA I/S Pit 3) Platform on the south end of the room.

The RWP map was removed from this page of the exam by the chief examiner because it was considered potential SUNSI material due to the equipment locations on the map.

Initial License Exam 03/2005 Job Performance Measure JPM: A4.1 Page 1 of 4 Rev Date: 1/18/05 System: Emergency Plan JTA Task #:

SRO A4.1 Task Title:

Event Classification KSA Ref: 2.4.41 EAL Classification PEO: RO: 2.3 SRO: 4.1 Operator's Name:

Performance Environment:

PLANT CONTROL ROOM SIMULATOR Performance Method:

PERFORMED SIMULATED DISCUSSED Time to complete JPM: Estimated 10 minutes Actual The operator's performance was evalua ted against the standards contained in this JPM and was determined to be: SATISFACTORY UNSATISFACTORY Reason, if unsatisfactory:

Evaluator's Signature:

Date: Comments (list all steps not satisfactorily completed):

References:

EPP-201 "Assessment of Emergency Action Levels, Emergency Classification, and Plan Activation" Tools, Equipment, Job Aids, etc:

Static simulator at the completion of Scenario #1.

Initial License Exam 03/2005 Job Performance Measure JPM: A4.1 Page 2 of 4 Rev Date: 1/18/05 Safety Considerations:

If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:

During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:

Peer checking Three-way communications Phonetic alphabet Self checking ALM use Unit designators Conservative decision making Procedure place keeping Procedure rules of usage Comments:

Instructions:

You may use any approved reference materials, including logs. Make or simulate all written/oral reports as if the evolution is actually being performed. You are expected to discuss all steps you would take, including identifying what switches/i ndications you would use Initiating Cue:

The simulator is in freeze. Based on current plant conditions and events during the scenario, determine the emergency classification. Terminating Conditions:

Event is classified as a Site Area Emergency.

Initial License Exam 03/2005 Job Performance Measure JPM: A4.1 Page 3 of 4 Rev Date: 1/18/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 1 Candidate diagnoses plant conditions and determines the emergency classification for Safety System Malfunction or Failure Referencing Chart 6 of EPP-201, the candidate determines that 6A is TRUE, 6B is TRUE, 6C is FALSE, 6F is False Note Start time.

  • 2 Candidate declares Site Area Emergency based on Chart 6 TASK COMPLETE Site Area Emergency declared IAW Chart 6 Note Completion

time.

Initial License Exam 03/2005 Job Performance Measure JPM: A4.1 Page 4 of 4 Rev Date: 1/18/05 INITIATING CUE:

The simulator is in freeze. Based on current plant conditions and events during the scenario, determine the emergency classification.

Initial License Exam 03/2005 Job Performance Measure JPM: A4.2 Page 1 of 4 Rev Date: 1/18/05 System: Emergency Plan JTA Task #:

SRO A4.2 Task Title:

Event Classification KSA Ref: 2.4.41 EAL Classification PEO: RO: 2.3 SRO: 4.1 Operator's Name:

Performance Environment:

PLANT CONTROL ROOM SIMULATOR Performance Method:

PERFORMED SIMULATED DISCUSSED Time to complete JPM: Estimated 10 minutes Actual The operator's performance was evalua ted against the standards contained in this JPM and was determined to be: SATISFACTORY UNSATISFACTORY Reason, if unsatisfactory:

Evaluator's Signature:

Date: Comments (list all steps not satisfactorily completed):

References:

EPP-201 "Assessment of Emergency Action Levels, Emergency Classification, and Plan Activation" Tools, Equipment, Job Aids, etc:

Static simulator at the completion of Scenario #2.

Initial License Exam 03/2005 Job Performance Measure JPM: A4.2 Page 2 of 4 Rev Date: 1/18/05 Safety Considerations:

If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:

During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:

Peer checking Three-way communications Phonetic alphabet Self checking ALM use Unit designators Conservative decision making Procedure place keeping Procedure rules of usage Comments:

Instructions:

You may use any approved reference materials, including logs. Make or simulate all written/oral reports as if the evolution is actually being performed. You are expected to discuss all steps you would take, including identifying what switches/i ndications you would use Initiating Cue:

The simulator is in freeze. Based on current plant conditions and events during the scenario, determine the emergency classification. Terminating Conditions:

Event is classified as a Site Area Emergency.

Initial License Exam 03/2005 Job Performance Measure JPM: A4.2 Page 3 of 4 Rev Date: 1/18/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 1 Candidate diagnoses plant conditions and determines the emergency classification for Loss of Reactor or Secondary Coolant Referencing Chart 2 of EPP-201, the candidate determines that 2A is TRUE, 2B is FALSE Note Start time.

2 Candidate declares Notification of Unusual Event based on Chart 2.

NOTE: Depending on the actual scenario times, this classification may not be necessary. If the 12 gpm leak was not present for > 15 min, it is not reasonable to expect the

candidate to recognize this initial classification.

Notification of Unusual Event declared IAW Chart 2 3 Candidate diagnoses plant conditions and determines the emergency classification for Loss of Reactor or Secondary Coolant Referencing Chart 2 of EPP-201, the candidate determines that 2A is TRUE, 2B is TRUE, 2C is TRUE, 2D is FALSE, 2G is FALSE.

  • 4 Candidate declares Site Area Emergency based on Chart 2.

TASK COMPLETE Site Area Emergency declared IAW Chart 2.

Note Completion

time.

Initial License Exam 03/2005 Job Performance Measure JPM: A4.2 Page 4 of 4 Rev Date: 1/18/05 INITIATING CUE:

The simulator is in freeze. Based on current plant conditions and events during the scenario, determine the emergency classification.

Initial License Exam 03/2005 Job Performance Measure JPM: P1 Page 1 of 4 Rev Date: 1/27/05 System: 118 AC Distribution System & Inverters JTA Task #: (NEW) Task Title:

Bypass Inverter KSA Ref: APE.057.EA1.01 PEO: RO: 3.7 SRO: 3.7 Operator's Name:

Performance Environment:

PLANT CONTROL ROOM SIMULATOR Performance Method:

PERFORMED SIMULATED DISCUSSED Time to complete JPM: Estimated 5 minutes Actual The operator's performance was evalua ted against the standards contained in this JPM and was determined to be: SATISFACTORY UNSATISFACTORY Reason, if unsatisfactory:

Evaluator's Signature:

Date: Comments (list all steps not satisfactorily completed):

References:

SOP-607A, "118 VAC Distribution System and Inverters" Tools, Equipment, Job Aids, etc:

Working copy of SOP-607A, Section 5.5.5 (1 page)

Initial License Exam 03/2005 Job Performance Measure JPM: P1 Page 2 of 4 Rev Date: 1/27/05 Safety Considerations:

If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:

During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:

Peer checking Three-way communications Phonetic alphabet Self checking ALM use Unit designators Conservative decision making Procedure place keeping Procedure rules of usage Comments:

Instructions:

You may use any approved reference materials, including logs. Make or simulate all written/oral reports as if the evolution is actually being performed. You are expected to discuss all steps you would take, including identifying what switches/i ndications you would use Initiating Cue:

The Unit Supervisor has directed you to transfer distribution panel 1PC1 to its alternate power supply using SOP-607A, Section 5.5.5. A crew brief has been held and the Reactor Operator is ready to assist you. Terminating Conditions:

Distribution panel 1PC1 is energized from the alternate power supply.

Initial License Exam 03/2005 Job Performance Measure JPM: P1 Page 3 of 4 Rev Date: 1/27/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 1 Ensure 1EC3/2/BKR, 118 VAC INSTRUMENT DISTR PANEL 1PC1 FEEDER BREAKER is ON CUE: Breaker position is ON.

The breaker operator is

pointing to the ON position.

CSR 807' South Wall Note Start time.

  • 2 Perform the following SIMULTANEOUSLY to transfer Panel 1PC1 to the alternate source:

Turn OFF 1PC1/00/BKR-1, IV1PC1 TO 118 VAC INSTRUMENT DISTR PANEL 1PC1 PREFERRED FEEDER BREAKER.

Turn ON 1PC1/00/BKR-2, 1EC3 TO 118 VAC INSTRUMENT DISTR PANEL 1PC1 ALTERNATE FEEDER BREAKER.

CUE : Breaker 1 indicates OFF and Breaker 2 indicates ON At Panel 1PC1:

1PC1/00/BKR-1 is

moved to the OFF position.

1PC1/00/BKR-2 is moved to the ON position.

NOTE: Breakers are interlocked via a slide bar such when BKR 1is opened, BKR 2 closes. 3 Calls the Control Room to inform them to complete step C and that the transfer is complete.

TASK COMPLETE Same as element.

Note Completion time.

Initial License Exam 03/2005 Job Performance Measure JPM: P1 Page 4 of 4 Rev Date: 1/27/05 INITIATING CUE:

The Unit Supervisor has directed you to transfer di stribution panel 1PC1 to its alternate power supply using SOP-607A, Section 5.5.5. A crew brief has been he ld and the Reactor Operat or is ready to assist you.

Initial License Exam 03/2005 Job Performance Measure JPM: P2 Page 1 of 5 Rev Date: 3/1/05 System: Control Room Evacuation JTA Task #: (Modified)AO5412C Task Title:

Transfer Charging Pump Suction and Isolate Dilution Paths KSA Ref: APE.068.AA1.22 PEO: RO: 4.0 SRO: 4.3 Operator's Name:

Performance Environment:

PLANT CONTROL ROOM SIMULATOR Performance Method:

PERFORMED SIMULATED DISCUSSED Time to complete JPM: Estimated 20 minutes Actual The operator's performance was evalua ted against the standards contained in this JPM and was determined to be: SATISFACTORY UNSATISFACTORY Reason, if unsatisfactory:

Evaluator's Signature:

Date: Comments (list all steps not satisfactorily completed):

References:

ABN-905A/B, "Loss of Control Room Habitability", Attachment 4. Tools, Equipment, Job Aids, etc:

Attachment 4 of ABN-905A/B (working copy)

Initial License Exam 03/2005 Job Performance Measure JPM: P2 Page 2 of 5 Rev Date: 3/1/05 Safety Considerations:

If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:

During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:

Peer checking Three-way communications Phonetic alphabet Self checking ALM use Unit designators Conservative decision making Procedure place keeping Procedure rules of usage Comments:

NOTE TO EXAMINER: Review note at step 8 of JPM to ensu re candidate is notified by RSP.

This JPM is designed to work on e ither Unit for ease of scheduling. Note which Unit is used in the comment section.

Instructions:

You may use any approved reference materials, including logs. Make or simulate all written/oral reports as if the evolution is actually being performed. You are expected to discuss all steps you would take, including identifying what switches/i ndications you would use Initiating Cue:

The control room has been evacuated per ABN-905A (B). You are requested to align the charging pump suction to the RWST and isolate RCS dilution paths per Attachment 4.

NOTE: The Control Room has been evacuated and is inaccessible Terminating Conditions:

Charging pump suction has been transferred to the RWST and the RCS dilution paths have been isolated. Attachment 4 is complete.

Initial License Exam 03/2005 Job Performance Measure JPM: P2 Page 3 of 5 Rev Date: 3/1/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 1 Open RWST u-01 to CHRG PMP SUCT VLV u-LCV-112D MOT BKR.

CUE: Breaker indicates in the OFF position.

1-EB3-1/8C/BKR, switch rotated to LEFT (OFF position).

Note Start time.

SFGD 790'-South (North for U2) Hallway West Side. U1-Room 1-070 U2-Room 2-070 2 Open VCT CTRL u-01 to CHRG PMP SUCT VLV u-LCV-112B MOT BKR CUE: Breaker indicates in the OFF position.

1-EB3-1/5F/BKR switch rotated to LEFT (OFF position).

3 Open RWST 1-01 to CHRG PMP SUCT VLV 112E MOT

BKR CUE: Breaker indicates in the OFF position.

1EB4-1/8F/BKR switch rotated to LEFT (OFF position).

AB 790'-By FDT

  1. 3 Door for U1.

U2-810'Room X-207. 4 Open VCT 1-01 to CHRG PMP SUCT VLV 0112C MOT BKR. CUE: Breaker indicates in the OFF position.

1EB4-1/8C/BKR switch rotated to LEFT (OFF position).

  • 5 Manually open valve 1-LCV-0112D RWST 1-01 TO CHRG

PMP SUCT VLV.

CUE: 1-LCV-112D has stopped moving and indicates

in the OPEN position.

1-LCV-112D clutch lever depressed while hand wheel is turned counter clockwise and position indication is checked. NOTE: Either

step 5 or 6 is critical, not both.

AB 810' Southside Corridor about halfway down the corridor outside room. *6 Manually open valve 1-LCV-0112E RWST 1-01 TO CHRG PMP SUCT VLV.

CUE: 1-LCV-112E has stopped moving and indicates

in the OPEN position.

1-LCV-112E clutch lever depressed while hand wheel is turned counter clockwise and position indication is checked. LCV-112E is Southeast of LCV-112D.

Unit 2 next to Room X-207.

Initial License Exam 03/2005 Job Performance Measure JPM: P2 Page 4 of 5 Rev Date: 3/1/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT *7 Manually close valve 1-LCV-0112B VCT 1-01 to CHRG PMP UPSTRM LVL CTRL VLV. CUE: 1-LCV-112B has stopped moving and indicates in the CLOSED position.

1-LCV-112B clutch lever depressed while hand wheel is turned clockwise and position indication is checked NOTE: Either step 7 or 8 is critical, not both.

AB 810' charging pump valve room South end, inside the Contaminated area for Unit 1. Unit 2 - Room X-

207. CUE: Remote Shutdown

Panel reports ZL-8220 and ZL-8221 were verified closed from the Control Room prior to evacuation.

  • 8 Manually close valve 1-LCV-112C VCT 1-01 to CHRG PMP DNSTRM LVL CTRL VLV. CUE: 1-LCV-112C has stopped moving and indicates in the CLOSED position.

1-LCV-112C clutch lever depressed while hand wheel is turned clockwise and position indication is checked.

Next to LCV-112B. . *9 Isolate dilution paths by closing 1 CS-8455 RMUW to CVCS BA BLNDR u-01 UPSTRM ISOL VLV.

CUE: 1 CS-8455 hand wheel has stopped moving and the valve indicates CLOSED.

TASK COMPLETE 1 CS-8455 hand wheel rotated clockwise AUX 822' blender room SE corner 1' above floor Note Completion time.

Initial License Exam 03/2005 Job Performance Measure JPM: P2 Page 5 of 5 Rev Date: 3/1/05 INITIATING CUE:

The Control Room has been evacuated per ABN-905A (B). You are requested to align the charging pump suction to the RWST and isolate RCS dilution paths per Attachment 4.

NOTE: The Control Room has been evacuated and is inaccessible.

Initial License Exam 03/2005 Job Performance Measure JPM: P3 System: Steam Line Rupture JTA Task #: Direct from Bank, A0*6424 Task Title: KSA Ref: APE.040.AA1.03 PEO: RO: 4.3 SRO: 4.3 Operator's Name: Locally Isolate Faulted Steam Generator Performance Environment:

PLANT cz] CONTROLROOM cz] SIMULATOR Performance Method:

PERFORMED H SIMULATED cz] DISCUSSED Time to complete JPM: Estimated 10 minutes Actual SATISFACTORY cz] UNSATISFACTORY Reason, if unsatisfactory: Evaluator's Signature: Date:

Comments (list steps not satisfactorily completed):

References:

EOP-2.0A(B), "Faulted Steam Generator M1-0202, Sh. 0 Isolation" Tools, Equipment, Job Aids, etc:

NONE Page 1 of 4 Rev Date: 311 5/05 Initial License Exam 03/2005 Job Performance Measure Safety Considerations:

If this JPM is to be performed in the plantlcontrol room, the candidate is NOT to manipulate any plant components unless he/she has permission from the ShiftlUnit Supervisor.

Human Performance Measures: During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations depmment guidance: Peer checking 0 Three-way Phonetic alphabet communications 0 Self checking ALMuse 0 Unit designators Conservative 0 Procedure place 0 Procedure rules of usage decision making keeping Comments:

Instructions:

You may use any approved reference materials, including logs. Make or simulate all writterdoral reports as if the evolution is actually being performed.

You are expected to discuss all steps you would take, including identifying what switches/indications you would use Initiating Cue:

A steam line break occurred on #1 SG inside containment.

A reactor trip, safety injection, and steamline isolation have been initiated. 1-W2452-2 STM SPLY VLV - MSL#1 (TDAFWP Steam Supply) indicates mid position.

The Unit Supervisor directs you to isolate the valve using a manual isolation, and notify the control room when complete.

Terminating Conditions

The #1 SG has been isolated.

Page 2 of 4 Rev Date: 3/15/05 Initial License Exam 03/2005 Job Performance Measure JPM: P3 1 "2 3 Operator identifies alternate Locate alternate valves Note Start time. valves to isolate g-HV-2452-2.

to isolate g-HV-2452-2.

&MS-0101 or gMS- Operator may 0144) refer to applicable mint if desired. Operator closes gMS-0101 or - uMS -0 144. CUE: Valve turns until it stops and is in the fully clockwise position.

Notify the Control Room that - u-MS-0101 or EMS-0144 is closed. CUE: Control Room understands that g-HV-2452-2 is isolated.

Turn the handwheel to the closed position (clockwise direction) and verify stem position. Operator uses radio or Gaitronics to notify the Control Room that g- HV-2452-2 is isolated. Valves are located in the MSL #1 Penetration Rm, SFGD. 880' Note Completion time. Page 3 of 4 Rev Date: 3/15/05 Initial License Exam 03/2005 Job Performance Measure JPM: P3 INITIATING CUE: A steam line break occurred on #1 SG inside containment.

A reactor trip, safety injection, and steamline isolation have been initiated.

1- HV2452-2 STM SPLY VLV - MSL#l(TDAFWP Steam Supply) indicates mid position.

The Unit Supervisor directs you to isolate the valve using a manual isolation, and notify the control room when complete.

Page 4 of 4 Rev Date: 3/15/05 Initial License Exam 03/2005 Job Performance Measure JPM: S-1 System: Reactor Coo l ant System JTA Task #:

RO*1111 Task Title: Verify Natural Circula t ion (Altern ate Path)

KSA Ref: EPE.E09.EA1.3 PEO: RO: 3.5 SRO: 3.8 Operator's Name: Performance Environment:

P L A N T CONT ROL ROOM S I M U L A T O R Performance Method:

P E R F O R M E D SIMULATED D I S C U S SE D Time to co mplete JP M: Estim a t e d 1 0 m i n u t e s A c t u a l The operator's perform a nce was evalua ted against the standards contained in this JPM and was determ ined to be: SATISF ACTORY UNS ATISF ACTORY Reason, if unsatisfactory:

Evaluato r's Signatur e: Date: Comm e n t s (l i s t a l l step s not satisfact orily com p leted):

References:

EOS-0.1A Reactor Trip Response (Rev 7)

Tools, Equipm ent, Job Aids, etc:

Reset to IC 20 and then:

Trip the Reactor, Enter Malfunction ED01, Start Em ergency boration, Stop the TDAFW P when SG levels are @

25%, Throttle rem a ining AFW to 120 per SG, m a nually con t ro l ARV's until Auct. CET star t to increase. Ensure the sim u lator rem a ins in FREEZE until righ t b e f o re the ca ndidate sta r ts the task. E n sure Steam Tables are av ailab l e. Page 1 of 5 Rev Date: 03/17/05 Initial License Exam 03/2005 Job Performance Measure JPM: S-1 Saf e ty Considera tions: If this JPM is to be perform e d in the plant/c ontrol room , the candidate is NOT to m a nipulate any plant com ponents unless he/she has perm ission from the Shift/Unit Supervisor.

Hum a n Perform ance Measures

During this Job Performance Measure, MONITOR for de monstrations of the following as outlin ed in Operations departm e nt guidance
Peer check ing Three-way comm unications Phonetic alphabet Self checkin g ALM use Unit designators Conservative decision making Procedure p l ace keep ing Procedure rules of usage Comm e n t s: Evaluato r sh ould ensure the sim u lato r rem a ins in FREEZE until righ t before the candidates starts the ta sk. Instru c t i o n s: You m a y us e any approved reference m a terials, incl uding logs. Make or sim u late all written/oral reports as if the evolution is ac tually being perform e d. You a r e expected to discuss all steps you would take, including id entifying wh at switches/i ndications you would use Initiating Cue:

The crew is responding to a loss of offsite power. Sa fety Injection is not actuated or required. The RCP's cannot be restarted. The US directs you to verify Natural Circulation per EOS 0.1A step 8 and Attachm e nt 3 of the sam e procedure. (Provide candidate a copy of EOS-0.1A)

Term inating Conditions:

Attachm e nt 3 is com p lete and the candidate ha s increas ed steam flow rate from the ARV's.

Page 2 of 5 Rev Date: 03/17/05 Initial License Exam 03/2005 Job Performance Measure JPM: S-1 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNS AT 1 Verify RCS subcooling > 25ºF.

CUE: Subc ooling is 35ºF and stable. Operator v e rifies subcooling using 1-TI-3611/3612-1 on CB-05.

Note Start time.

2 Check Steam Generator Pressures-S T ABLE OR DECR EASI NG CUE: All SG pressures are INCREASING.

Operator ch ecks SG pressures using 1-PI-514/524/534/544A on CB-08 3 Check RCS Hot Leg Tem p eratures- STABLE OR DECR EASI NG CUE: All Hot Leg Tem p eratures are s t able. Operator ch ecks hot leg tem p eratures using 1-TR-433/434A on CB-

06. 4 Check core exit TC's- STABL E OR DEC R EASING CUE: Core Exit TC's are 605º and slowly increasing.

Operator ch ecks core exit TC's on plant com puter, OR 1-TI-3611/3612-2 on CB-05 Note: Candidate m a y i mmediately incre a se s t ea m fl ow fro m ARV's. 5 Check RCS cold leg tem p eratures-AT SATURATI ON TEMPERATURE F O R SG PRESSURE CUE: Cold leg tem p eratures are 551º F and SG pressures are 1050 psig.

Operator ch ecks RCS cold leg temperatu r es using 1-TR-413B/23B and 433B/43B on CB05 and com p ares to SG pressures using 1-PI-514/524/534/544A on CB-08 Page 3 of 5 Rev Date: 03/17/05 Initial License Exam 03/2005 Job Performance Measure JPM: S-1 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNS AT *6 Natural Circulation is N O T verifed, Increase Steam Flow fro m SG AR V's. CUE: Steam Generator pressures are decreasing

. Operator op ens SG ARV's using 1-PK-2325/26/27/28 on CB08. 7 Verify Core Exit Therm o couples are decreasing.

CUE: Core Exit Therm o couples are decreasing.

TASK COM PLETE Operator ch ecks core exit TC's on plant com puter, OR 1-TI-3611/3612-2 on CB-05 . Note Completion time. Page 4 of 5 Rev Date: 03/17/05 Initial License Exam 03/2005 Job Performance Measure JPM: S-1 Page 5 of 5 Rev Date: 03/17/05 INITIATING CUE:

The crew is responding to a loss of offsite power. Sa fety Injection is not actuated or required. The RCP's cannot be restarted. The US directs you to ve rify Natural Circulation per EOS 0.1A step 8 and Attachment 3 of the same procedure.

Initial License Exam 03/2005 Job Performance Measure JPM: S2 Page 1 of 8 Rev Date: 1/27/05 System: Pressurizer Pressure Control System JTA Task #: (Modified) RO*1209 Task Title: Control Pressurizer Pressure KSA Ref: SF3.010.A1.07 PEO: RO: 3.7 SRO: 3.7 Operator's Name:

Performance Environment:

PLANT CONTROL ROOM SIMULATOR Performance Method:

PERFORMED SIMULATED DISCUSSED Time to complete JPM: Estimated 30 minutes Actual The operator's performance was evalua ted against the standards contained in this JPM and was determined to be: SATISFACTORY UNSATISFACTORY Reason, if unsatisfactory:

Evaluator's Signature:

Date: Comments (list all steps not satisfactorily completed):

References:

IPO-005A, Step 5.1.5 Tools, Equipment, Job Aids, etc:

Reset to IC 5 with Tave appx. 557 F, RCS Pressure appx. 2235 psig, and a small cooldown in progress.

Provide working copy of IPO-005A, steps 5.1.5 and 5.1.6 Initial License Exam 03/2005 Job Performance Measure JPM: S2 Page 2 of 8 Rev Date: 1/27/05 Safety Considerations:

If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:

During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:

Peer checking Three-way communications Phonetic alphabet Self checking ALM use Unit designators Conservative decision making Procedure place keeping Procedure rules of usage Comments:

Instructions:

You may use any approved reference materials, including logs. Make or simulate all written/oral reports as if the evolution is actually being performed. You are expected to discuss all steps you would take, including identifying what switches/i ndications you would use Initiating Cue:

A plant shutdown and cooldown for REFUELING is in progress. The RCS is currently at appx.

557 F and 2235 psig. You are currently in IPO-005A, at step 5.1.5 with a 50 F/Hr cooldown in progress. The BOP is controlling the cooldown. The US has instructed you to initiate a reduction of RCS Pressure per step 5.1.5 and 5.1.6 and stabilize pressure at 1925 psig (+ or- 25 psig), and then BLOCK SI, while the RCS Cooldown is continuing. The Extra RO will perform OPT-407 and RCP data monitoring. Terminating Conditions:

Przr Spray Valve Controllers in MANUAL (AMBER & GREEN) Lights with zero (0) output, ZL Lights GREEN, and RCS Pressure at 1925 + or - 25 psig

Initial License Exam 03/2005 Job Performance Measure JPM: S2 Page 3 of 8 Rev Date: 1/27/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT NOTE: 1-PK-455A PZR MASTER PRESS CTRL may be adjusted in MANUAL to energize Group C Pressurizer Heaters and maximize spray flow Depress MANUAL on

1-PK-455A PZR MASTER PRESS CTRL Note Start time

  • 1 Place Pressurizer Spray Valve Controller(s) in MANUAL CUE: Przr Spray Valve Controllers u-PK-455B and u-PK-455C AMBER and ON. Depress "AMBER" P/B on PK-455B and PK-455C and verify controllers are in MANUAL by observing the AMBER

Light ON and the WHITE (Auto) Light OFF. PK-455B and PK-

455C are located on CB-05 (VERTICAL BOARD) *2 THROTTLE OPEN one or both pressurizer spray valve to

begin a slow RCS Pressure reduction.

CUE: The Przr Spray Valve(s) ZL lights are RED and GREEN for the Spray Valve operated.

Depress the RED P/B

on either PK-455B and/or PK-455C and verify controller response by observing the controller output and indicating lights (ZL-455B or ZL-455C)

on Control Board (Vertical Board Section).

When the RED

P/B is depressed the output meter should begin to increase (from 9% toward

100%). As the valve begins to throttle the ZL LIGHTS (ZL-455A or ZL-

455B) will indicate THROTTLED by

having both RED and GREEN LIGHTS ON Initial License Exam 03/2005 Job Performance Measure JPM: S2 Page 4 of 8 Rev Date: 1/27/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 3 Monitor RCS Pressure for DECREASE CUE: RCS pressure is decreasing and when RCS pressure is 2185 psig, ALARMS 1.6 and 2.6 on ALB-5B have annunciated.

Verify RCS Pressure decrease using Narrow Range Pressure Instruments or Recorder. u-PI-455A u-PI-456 u-PI-457 u-PI-458 u-PI-455 RCS Press (NR) instruments u-PI-455A, u-PI-456, u-PI-457, and/or u-PI-458 located on CB-05 OR RCS Press Recorder u-PR-455 located on

CB-05 NOTE: ALB-5B 1.6 & 2.6 annunciate at 2185 psig 4 ACKNOWLEDGE Annunciators 1.6 and 2.6 on ALB-5B. Depress the ACKNOWLEDGE P/B at the Annunciator Controls on CB-05

  • 5 As PRZR PRESS channels approach 1925 psig, adjust pressurizer heaters and spray valves as necessary to maintain RCS pressure between1900 psig and 1950 psig. . CUE: RCS Pressure indicates 1925 psig on u-PI-455A, u-PI-456, 457, 458, and recorder u-PR-455. Verify RCS Pressure

decrease using Narrow Range Pressure Instruments or Recorder. u-PI-455A u-PI-456 u-PI-457 u-PI-458 u-PI-455 Manually controls pressurizer sprays and heaters to stabilize RCS pressure at 1925 psig.

  • If RCS pressure decreases to below 1820 psig, SI will actuate and will result in a failure of the JPM.

The US DIRECTS you to stabilize RCS pressure and Block SI per the IPO step in effect.

Initial License Exam 03/2005 Job Performance Measure JPM: S2 Page 5 of 8 Rev Date: 1/27/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 6 WHEN RCS pressure is below 1960 psig, THEN perform the following:

A. Ensure RCS has been borated to a Shutdown Margin for RCS #350°F(reference Step 5.2.3 A).

CUE: The US informs the RO that the RCS is borated for SDM for 350°F The RCS is borated for SDM for 350°F 7 Verify 1-PCIP, 2.6, PRZR PRESS SI BLK PERM P-11 is ON. CUE: CB-07, PCIP alarm window 2.6 is lit. CB-07, PCIP alarm

window 2.6 is lit (blue). 8 Verify the following status lights are OFF:

1-TSLB-9, 1.3, PRZR PRESS SI PERM PB-455B 1-TSLB-9, 2.3, PRZR PRESS

SI PERM PB-456B 1-TSLB-9, 3.3, PRZR PRESS

SI PERM PB-457B CUE: Windows 1.3, 2.3, and

3.3 on TSLB 9 are dark.

On CB-04, 1-TSLB-9, windows: 1.3 is dark 2.3 is dark 3.3 is dark

Initial License Exam 03/2005 Job Performance Measure JPM: S2 Page 6 of 8 Rev Date: 1/27/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT *9 Turn BOTH MSL ISOL SI RESET/BLOCK switches to BLOCK and release:

1/1-SLSIRBA, MSL ISOL SI RESET/BLOCK 1/1-SLSIRBB, MSL ISOL SI RESET/BLOCK CUE: The handswitch moved

counterclockwise and stopped.

On CB-08, in the MSL

Isolation section:

Turns handswitch 1/1-SLSIRBA counter clockwise to block Turns handswitch 1/1-SLSIRBA counter clockwise to block 10 Verify the following are ON:

1-PCIP, 3.8, MSL PRESS LO TRN A SI BLK 1-PCIP, 4.8, MSL PRESS LO TRN B SI BLK CUE: PCIP windows 3.8 and

4.8 are LIT.

CB-07, PCIP alarm

window: 3.8 is ON.

4.8 is ON.

  • 11 Turn BOTH PRZR PRESS SI RESET/BLOCK switches to BLOCK and release:

1/1-PPSIRBA, PRZR PRESS SI RESET/BLOCK 1/1-PPSIRBB, PRZR PRESS

SI RESET/BLOCK CUE: The handswitch moved

counterclockwise and stopped.

On CB-08, in the SI BLOCK section:

Turns handswitch 1/1-PPSIRBA counter clockwise to block Turns handswitch 1/1-PPSIRBB counter clockwise to block

Initial License Exam 03/2005 Job Performance Measure JPM: S2 Page 7 of 8 Rev Date: 1/27/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 12 Verify the following are ON:

1-PCIP, 3.7, PRZR PRESS LO TRN A SI BLK 1-PCIP, 4.7, PRZR PRESS LO TRN B SI BLK CB-07, PCIP alarm

window: 3.7 is ON.

4.7 is ON.

13 Report that RCS pressure is

stable at 1925 psig and that SI has been blocked. IPO-

005A step 5.1.5 has been completed.

TASK COMPLETE RCS pressure is stable or slightly decreasing at less than 1950 psig.

Note completion time.

Initial License Exam 03/2005 Job Performance Measure JPM: S2 Page 8 of 8 Rev Date: 1/27/05 INITIATING CUE:

A plant shutdown and cooldown for REFUELING is in progress. The RCS is currently at appx. 557 F and 2235 psig. You are currently in IPO-005A, at step 5.1.5 with a 50 F/Hr cooldown in progress.

The BOP is controlling the cooldown.

The US has instructed you to initiate a reduc tion of RCS Pressure per step 5.1.5 and 5.1.6 and stabilize pressure at 1925 psig (+ or- 20 psig), and then BLOCK SI, while the RCS Cooldown is continuing. The Extra RO will perform OPT-407 and RCP data monitoring.

Initial License Exam 03/2005 Job Performance Measure JPM: S3 Page 1 of 5 Rev Date: 1/28/05 System: CVCS JTA Task #: (NEW) Task Title: Emergency Borate Using Chemical And Volume Control System KSA Ref: SF1.004.A4.18 PEO: RO: 4.3 SRO: 4.1 Operator's Name:

Performance Environment:

PLANT CONTROL ROOM SIMULATOR Performance Method:

PERFORMED SIMULATED DISCUSSED Time to complete JPM: Estimated 10 minutes Actual The operator's performance was evalua ted against the standards contained in this JPM and was determined to be: SATISFACTORY UNSATISFACTORY Reason, if unsatisfactory:

Evaluator's Signature:

Date: Comments (list all steps not satisfactorily completed):

References:

ABN-107, "Emergency Boration", Tools, Equipment, Job Aids, etc:

Initialize into any shutdown IC above 550°F Tave. Provide ABN-107, Attachment 2 to candidate.

Initial License Exam 03/2005 Job Performance Measure JPM: S3 Page 2 of 5 Rev Date: 1/28/05 Safety Considerations:

If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:

During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:

Peer checking Three-way communications Phonetic alphabet Self checking ALM use Unit designators Conservative decision making Procedure place keeping Procedure rules of usage Comments:

Instructions:

You may use any approved reference materials, including logs. Make or simulate all written/oral reports as if the evolution is actually being performed. You are expected to discuss all steps you would take, including identifying what switches/i ndications you would use Initiating Cue:

You have been directed by the Unit Supervisor to commence Emergency Boration using Attachment 2 of ABN-107, "Emergency Boration". Inform the Unit Supervisor when the attachment is complete. Terminating Conditions:

Emergency boration established through the Normal Boration valves.

Initial License Exam 03/2005 Job Performance Measure JPM: S3 Page 3 of 5 Rev Date: 1/28/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 1 Place 1/u-MU, RCS MU MAN ACT switch in - STOP. CUE: 1/u-MU is in the STOP position 1/u-MU rotated in the

counterclockwise direction until it is in the STOP position.

Note Start time.

  • 2 Open 1/u-FCV-110B, RCS MU TO CHRG PMP SUCT ISOL VLV.

CUE: 1/u-FCV-110B is in the OPEN position and the red light is LIT.

1/u-FCV-110B rotated in the clockwise position from AUTO to OPEN. *3 Start a boric acid transfer pump: 1/u-APBA1, BA XFER PMP 1

- AUTO (AFTER START)

CUE: The green light is OFF

and the red light is ON.

Rotates handswitch

1/u-APBA1 in the clockwise direction to the START position.

. *4 Open 1/u-FCV-110A, BA BLNDR FLO CTRL VLV.

CUE: 1/u-FCV-110B is in the

OPEN position and the red light is ON.

1/u-FCV-110A rotated in the clockwise position from AUTO to OPEN.

Initial License Exam 03/2005 Job Performance Measure JPM: S3 Page 4 of 5 Rev Date: 1/28/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 5 Verify flow on u-FR-110 (RED PEN), BA FLOW TO BLNDR CUE: Boric acid flow is 38 gpm. Using the RED pen on

u-FR-110, verify that flow is between 35 and 40 gpm. 6 Verify flow on u-FI-121A, CHRG FLOW CUE: Charging flow indicates 115 gpm. TASK COMPLETE Using u-FI-121A, verifies that Charging flow is going to the RCS. Note Completion

time.

Initial License Exam 03/2005 Job Performance Measure JPM: S3 Page 5 of 5 Rev Date: 1/28/05 INITIATING CUE:

You have been directed by the Unit Supervisor to commence Emergency Boration using Attachment 2 of ABN-107, "Emergency Boration". Inform the Unit Supervisor when the attachment is complete.

Initial License Exam 03/2005 Job Performance Measure JPM: S4 Page 1 of 5 Rev Date: 1/27/05 System: Small Break LOCA JTA Task #: (NEW) Task Title: Perform Attachment 2 of EOP-0.0A (Alternate Path)

KSA Ref: EPE.009.EA1.08 PEO: RO: 4.0 SRO: 4.1 Operator's Name:

Performance Environment:

PLANT CONTROL ROOM SIMULATOR Performance Method:

PERFORMED SIMULATED DISCUSSED Time to complete JPM: Estimated 20 minutes Actual The operator's performance was evalua ted against the standards contained in this JPM and was determined to be: SATISFACTORY UNSATISFACTORY Reason, if unsatisfactory:

Evaluator's Signature:

Date: Comments (list all steps not satisfactorily completed):

References:

EOP-0.0A "Reactor Trip or Safety Injection" Tools, Equipment, Job Aids, etc:

Initialize into IC-15.

Enter the following Malfunctions: RP09A and RP09B, RH01B. (Make trigger file to remove Malf when H/S to start) Insert Overrides LOCHHS 5729 2, and LOCCHS 6202 5 to ON. Manually trip the reactor and initiate SI. After the Seq has timed out FREEZE. Attachment 2 of EOP-0.0A, Safety Injection Actuation Alignment.

Initial License Exam 03/2005 Job Performance Measure JPM: S4 Page 2 of 5 Rev Date: 1/27/05 Safety Considerations:

If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:

During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:

Peer checking Three-way communications Phonetic alphabet Self checking ALM use Unit designators Conservative decision making Procedure place keeping Procedure rules of usage Comments:

NOTE TO EXAMINER:

This JPM is constructed to list th e failures that the candidate will encounter while performing Attachment 2. It will only list the critical steps. To follow along as the candidate performs the attachment, utilize INFO ONLY copy of Attachment 2.

Instructions:

You may use any approved reference materials, including logs. Make or simulate all written/oral reports as if the evolution is actually being performed. You are expected to discuss all steps you would take, including identifying what switches/i ndications you would use Initiating Cue:

Automatic Reactor Trip and Safety Injection have occurred The crew is at step 5 of EOP-0.0A.

The Unit Supervisor has directed you to perform Attachment 2 of EOP-0.0A. Inform the Unit Supervisor when the attachment is complete. Terminating Conditions: Attachment 2 is complete with the following exceptions: Phase A was manually actuated. The B RHR pump did not auto start and was manually started. The Primary Plant Supply Fan 20 is running. The Spent Fuel Pool Exhaust fan 36 is running.

Initial License Exam 03/2005 Job Performance Measure JPM: S4 Page 3 of 5 Rev Date: 1/27/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 1 The candidate will retrieve the attachment from the drawer where it is normally kept.

The candidates are expected to complete Attachment 2 independently and without error.

Note Start time.

It is managements expectation that the candidate will place keep the procedure by marking completed steps and indicating any exceptions.

  • 2 Step 3. Verify Containment Isolation Phase A-Appropriate MLB LIGHT INDICATION (RED WINDOWS)

CUE: The RED LIGHTS on

the MLB's 1A1, 1A2, 1B1, and 1B2 are dark. All others are LIT. The RED LIGHTS will

be dark. The candidate must manually initiate Phase using HS 1/1-CIPAA1 on CB-02 in the SFGD MAN

ACT/RESET section, by rotating the switch in the clockwise direction to ACT.

  • 3 Step 6. Verify RHR pumps-RUNNING. CUE: The red light is lit and the green light is dark.

For RHR Pump 1-02 the red light will be off and green light will be on. The candidate must attempt a manual start by rotating 1/1-APRH2 in the clockwise direction to the START position.

.

Initial License Exam 03/2005 Job Performance Measure JPM: S4 Page 4 of 5 Rev Date: 1/27/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT *4 Step 13, Attachment 1. X-HS-6202 on CV-01, STOPPED.

On Ventilation Panel CV-01 Primary Plant Supply Fan 20 will indicate RUNNING. The candidate must attempt to stop the fan

by rotating X-HS-6202 counterclockwise direction to the STOP position.

NOTE: It is not critical that the candidate rotate the switch, but the exception MUST be documented, either by oral report or place keeping the procedure.

  • 5 Step 13, Attachment 1. X-HS-5729 on CV-03, STOPPED.

On Ventilation Panel CV-03 Spent Fuel Pool Exhaust fan will indicate RUNNING. The candidate must attempt to stop the fan

by rotating X-HS-5729 counterclockwise direction to the STOP position.

NOTE: It is not critical that the candidate rotate the switch, but the exception MUST be documented, either by oral report or place keeping the procedure.

6 Report the completion of Attachment 2 to the Unit

Supervisor and note exceptions to the requirements of the Attachment. TASK COMPLETE Candidate must indicate the above exceptions.

Note Completion time.

Initial License Exam 03/2005 Job Performance Measure JPM: S4 Page 5 of 5 Rev Date: 1/27/05 INITIATING CUE:

Automatic Reactor Trip and Safety Injection have o ccurred. The crew is at step 5 of EOP-0.0A. The Unit Supervisor has directed you to perform Attachment 2 of EOP-0.0A. Inform the Unit Supervisor when the attachment is complete.

Initial License Exam 03/2005 Job Performance Measure JPM: S5 Page 1 of 5 Rev Date: 1/27/05 System: Containment Spray JTA Task #: (Modified) RO2003 Task Title: Operate the Containment Spray System (Alternate Path)

KSA Ref: SF6.026.A4.01 PEO: RO: 4.5 SRO: 4.3 Operator's Name:

Performance Environment:

PLANT CONTROL ROOM SIMULATOR Performance Method:

PERFORMED SIMULATED DISCUSSED Time to complete JPM: Estimated 5 minutes Actual The operator's performance was evalua ted against the standards contained in this JPM and was determined to be: SATISFACTORY UNSATISFACTORY Reason, if unsatisfactory:

Evaluator's Signature:

Date: Comments (list all steps not satisfactorily completed):

References:

SOP-204A/B, "Containment Spray System", u

-ALB-2B, "ALM-0022A/B" Tools, Equipment, Job Aids, etc:

Simulator Setup: OVERRIDE 1TI-4793 (RWST Temperature) to 45°F, activate HS-4776 override after CSP's have been started.

Initial License Exam 03/2005 Job Performance Measure JPM: S5 Page 2 of 5 Rev Date: 1/27/05 Safety Considerations:

If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:

During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:

Peer checking Three-way communications Phonetic alphabet Self checking ALM use Unit designators Conservative decision making Procedure place keeping Procedure rules of usage Comments:

Instructions:

You may use any approved reference materials, including logs. Make or simulate all written/oral reports as if the evolution is actually being performed. You are expected to discuss all steps you would take, including identifying what switches/i ndications you would use Initiating Cue:

Temperature is 45°F in the RWST, the Unit Supervis or directs you to recirc the RWST with Train "A" Containment Spray Pumps, using section 5.1.2 of SOP-204A and the 1-01 CSP. Containment Spray is in Standby per SOP-204A/B Section 5.1.1. Crew briefing is completed and PCS trends are initiated. Terminating Conditions:

Containment Spray Pumps have been stopped.

Initial License Exam 03/2005 Job Performance Measure JPM: S5 Page 3 of 5 Rev Date: 1/27/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 1 Place CS HX1 Outlet Vlv to Pull-Out Pull-outs 1-HS-4776, acknowledges SSII Train A Note Start time. SSII alarms 2 Verify chemical additive tanks discharge valve is closed CUE: u-HS-4754 green light lit Checks u-HS-4754 closed. 3 Contact PEO to Unlock and Open u CT-0050 CUE: PEO reports u CT-0050 open Reverse Operated Valve 4 Initiate a trend of selected pump parameters on the plant computer.

CUE: The extra RO has initiated the trend of the pump parameters This has already been done by extra RO

  • 5 Start Containment Spray Pump 1-01 CUE: "RED" light lit on u-HS-4764, u-FI-4772-1 (0 gpm), u-PI-4774-1 (300 psig)

CUE: Alarm window 3.5 CS HX 1 OUT VLV NOT CLOSE HV-4776 on ALB 2B Places u-HS-4764 1-01 Containment Spray Pump in "START" on and checks flow and pressure Override HS-4776 to OPEN, via the handswitch on mimic display CB02 6 Monitor CSP discharge flow CUE: u-FI-4772-1 indicates 3000 gpm, u-FI-4772-2 indicates 3100 gpm Monitors u-FI-4772-1, u-FI-4772-2 flow indicators

Initial License Exam 03/2005 Job Performance Measure JPM: S5 Page 4 of 5 Rev Date: 1/27/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 7 Ensure CS HX OUT VLV is closed CUE: u-HS-4776 red light LIT CUE: "CNTMT SMP 1, 2 FILL RATE INCREASE" and "ANY CNTMT SMP PMP RUN" alarm ON MCB Checks position of u-HS-4776 *8 Stop CNTMT Spray Pumps CUE: u-HS-4764 and u-HS-4765 red and green lights are dark TASK COMPLETE Go to stop (or PULL OUT) on u-HS-4764 and u-HS-4765 Note Completion

time.

Initial License Exam 03/2005 Job Performance Measure JPM: S5 Page 5 of 5 Rev Date: 1/27/05 INITIATING CUE:

Temperature is 45°F in the RWST, the Unit Supervisor directs you to recirc the RWST with Train "A" Containment Spray Pumps, using section 5.1.2 of SOP-204A and the 1-01 CSP. Containment Spray is in Standby per SOP-204A/B Section 5.1.1. Crew briefing is completed and PCS trends are initiated.

Initial License Exam 03/2005 Job Performance Measure JPM: S6 Page 1 of 7 Rev Date: 1/26/05 System: Emergency Diesel Generator JTA Task #: (Modifed)RO4032 Task Title: Load Diesel Generator (Alternate Path)

KSA Ref: SF6.064.A4.06 PEO: RO: 3.9 SRO: 3.9 Operator's Name:

Performance Environment:

PLANT CONTROL ROOM SIMULATOR Performance Method:

PERFORMED SIMULATED DISCUSSED Time to complete JPM: Estimated 15 minutes Actual The operator's performance was evalua ted against the standards contained in this JPM and was determined to be: SATISFACTORY UNSATISFACTORY Reason, if unsatisfactory:

Evaluator's Signature:

Date: Comments (list all steps not satisfactorily completed):

References:

SOP-609A OPT-214A ABN-501 Tools, Equipment, Job Aids, etc:

OPT-214A (Working Copy) Simulator set-up: Any at power IC, go to RUN, START DG 1. Set up trigger file to insert malfunction SW01A when EDG load is 2.3MW.

Initial License Exam 03/2005 Job Performance Measure JPM: S6 Page 2 of 7 Rev Date: 1/26/05 Safety Considerations:

If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:

During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:

Peer checking Three-way communications Phonetic alphabet Self checking ALM use Unit designators Conservative decision making Procedure place keeping Procedure rules of usage Comments:

Instructions:

You may use any approved reference materials, including logs. Make or simulate all written/oral reports as if the evolution is actually being performed. You are expected to discuss all steps you would take, including identifying what switches/i ndications you would use Initiating Cue:

OPT-214A, Diesel Generator Operability Test is being performed on DG 1 for a normal 30 day test. You are on step 8.1.S, the DG is running at 60 Hz and 6.9 kV. The PEO at the DG has reported that the DG is running prop erly. Continue with the test. Terminating Conditions:

The Emergency Diesel Generator ha s been placed in "Pull Out".

Initial License Exam 03/2005 Job Performance Measure JPM: S6 Page 3 of 7 Rev Date: 1/26/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 1 Refer to OPT-214A, Step 8.1.S. OPT-214A entered at step 8.1.S Note Start time.

  • 2 Turn the Synchroscope for DG1 to the "ON" position.

CUE: The synchroscope switch is in the ON position.

Synchroscope Switch (SS-1EG1) in the ON position.

The operating handle is STAR-shaped. The Synchroscope Switch (SS-1EG1) is located

above DG1 output breaker on CB-11 (Beveled Section). The switch is 2-

Position MAINTAIN SWITCH. The ON position is to the right.

3 Compare incoming voltage to running voltage.

CUE: V-1EG1 reads 6900 volts and V-1EA1 reads 7000

volts. V-1EG1 and V-1EA1 checked. V-IN and V-RUN

are preferred, any indications listed in OPT-214A are acceptable for use. 4 Adjust the DG voltage to slightly greater than that on the BUS. CUE: DG voltage slightly greater than BUS voltage (50-

100v) Voltage control switch (90-1EG1) taken to RAISE or LOWER until DG 1 volts (V-1DG1) is 50 - 100 volts greater than BUS

1EA1 volts (V-1EA1).

The DG output voltage (6900 Volts) is to agree with 1EA1-1 BUS Voltage (6900 Volts). These meters are located on CB-11 (Vertical Section). The DG Voltage Control Handswitch (90-1EG1) is a 3-POSITION SRING RETURN to OFF type switch. Located on CB-11 (A SEC)

Initial License Exam 03/2005 Job Performance Measure JPM: S6 Page 4 of 7 Rev Date: 1/26/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 5 Check DG speed CUE": Synchroscope is rotating in clockwise direction.

Synchroscope checked (On CB-11) Lights are a

backup to the sync scope (OFF when in phase, ON when out of phase). 6 Adjust the speed so the Synchroscope is moving slowly in the fast direction.

CUE: Synchroscope is rotating 2-4 RPM in the fast

direction.

Speed Control Handswitch (65-1EG1) taken to RAISE and synchroscope checked until rotating SLOWLY in FAST

direction (2-4 RPM_.

(65-u EG1 taken to LOWER if speed too fast.) Handswitch (65-1EG1) is a 3-POSITION SPRING RETURN TO OFF type switch

located on CB-11 (Apron Section).

The INCREASE position is to the RIGHT. The

FAST Direction is CLOCKWISE.

  • 7 Close the DG breaker when the Synchroscope is slightly before

the 12 O'CLOCK position and moving slowly in the FAST Direction.

CUE: ALB-10B 3.5 alarm has annunciated and the

breaker red light lit and green light off.

DG Breaker (CS-u EG1) is closed and position is checked. (Indicated by Annunciator Alarm (ALB-10B 3.5), Handswitch FLAG (RED FLAG) and indication Lights.

Handswitch (65-1EG1) is a 3 POSITION, SPRING RETURN TO AUTO type

switch. Located on CB-11 (Apron Section).

Indicating lights on Handswitch

should be RED (Green Light out) with RED FLAG

indication.

Annunciator ALB-10B 3.5 (6.9KV BUS 1EA1/1EA2

PARALELLED) ON (energized).

Initial License Exam 03/2005 Job Performance Measure JPM: S6 Page 5 of 7 Rev Date: 1/26/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT *8 Immediately pick-up at least 2.2-2.5 MW for stability CUE: When load is first checked, DG1 MW Meter (W-1EG1) indicates ZERO MW; when load is checked after going to RAISE, W-1EG1 indicates 2.1 MW.

SPEED CONTROL HANDSWITCH 65-1EG1, taken to RAISE to pick up sufficient load to prevent a reverse power trip of

DG 1. DG1 MW Meter (W-1EG1) located on CB-11 (Vertical Section).

Handswitch (65-

1EG1) is a 3-Position Spring Return to OFF type switch.

Located on CB-

11 (Apron Section). The RAISE position is

to the RIGHT.

9 Turn the Synchroscope to the "OFF" position.

CUE: The Synchroscope switch is in the OFF position.

Synchroscope Switch (SS-1EG1) in the OFF position.

The Synchroscope Switch (SS-1EG1) is located above DG1 output breaker on

CB-11 (Beveled Section). The switch is a 2-Position MAINTAIN Switch. The OFF position is to the LEFT. 10 Maintain 0-500 KVAR OUT , CUE: When KVARS first checked, meter indicate 500 KVARS (to left of ). When switch is taken to RAISE and KVARS checked, give readings indicating KVAR increasing or for LOWER<

KVAR decreasing.

Reactive load maintained 0-500 KVAR OUT; DG1 Voltage Control

Handswitch (90-1EG1) taken to RAISE to increase KVARS or LOWER to decrease

KVARS as on DG1 KILOVAR Meter (VAR-1EG1) checked.

(This step should be

repeated as the DG is loaded.)

Initial License Exam 03/2005 Job Performance Measure JPM: S6 Page 6 of 7 Rev Date: 1/26/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 11 Load the selected DG to 6.0 MW over a 20 minute period.

CUE: When switch is taken to RAISE and W-uEG2 is observed, give reading indication incr easing MW or for Lower, decreasing MW. DG1 loaded to 6.0 MW over a 20 minute period

( .3 MW/min) by moving the Speed Control Handswitch (65-1EG1) to RAISE direction and observing the DG1 MW Meter (W-1EG1).

Speed Control

Handswitch (65-u EG1) located on CB-11 (Apron Section) DG1 MW Meter (W-1EG1) located on CB-11 (Vertical

Section). As LOAD is increased the KILOVARS will decrease toward 0 (zero). 12 Acknowledge and respond to 1-ALB-01 window 1.8 "SSWP 1/2 OVRLOAD/TRIP Refer to ALM-01-1.8 and/or ABN-501.

  • 13 Determines that EDG 1-01 should be in "Pull Out" .

ALM -01 (1.8) and Initial Operator Action from ABN-501, Service Water Malfunction.

TASK COMPLETE Places EDG 1-01 in "Pull Out" using CS-1EG1. Note Completion time.

Initial License Exam 03/2005 Job Performance Measure JPM: S6 Page 7 of 7 Rev Date: 1/26/05 INITIATING CUE:

OPT-214A, Diesel Generator Operability Test is being performed on DG 1 for a normal 30 day test. You are on step 8.1.S, the DG is running at 60 Hz a nd 6.9 kV. The PEO at the DG has reported that the DG is running properly. Continue with the test.

Initial License Exam 03/2005 Job Performance Measure JPM: S7 Page 1 of 5 Rev Date: 1/26/05 System: Nuclear Instrumentation System JTA Task #: NEW Task Title: Respond To Source Range Instrumentation Malfunction (Alternate Path)

KSA Ref: APE.032.AK3.01 PEO: RO: 3.2 SRO: 3.6 Operator's Name:

Performance Environment:

PLANT CONTROL ROOM SIMULATOR Performance Method:

PERFORMED SIMULATED DISCUSSED Time to complete JPM: Estimated 10 minutes Actual The operator's performance was evalua ted against the standards contained in this JPM and was determined to be: SATISFACTORY UNSATISFACTORY Reason, if unsatisfactory:

Evaluator's Signature:

Date: Comments (list all steps not satisfactorily completed):

References:

IPO-002A, "Plant Startup from Hot Standby to Minimum Load", ABN-701, ALM-0064A Tools, Equipment, Job Aids, etc:

IPO-002A, ABN-701, Simulator: Load IC 7, actuate malfunction RP01 and RP013 A & B. . Following initiating CUE, go to run. Actuate Malf NI01A @

severity 1E6 when the candidate starts to dilute or when referencing the SOP.

Initial License Exam 03/2005 Job Performance Measure JPM: S7 Page 2 of 5 Rev Date: 1/26/05 Safety Considerations:

If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:

During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:

Peer checking Three-way communications Phonetic alphabet Self checking ALM use Unit designators Conservative decision making Procedure place keeping Procedure rules of usage Comments:

Instructions:

You may use any approved reference materials, including logs. Make or simulate all written/oral reports as if the evolution is actually being performed. You are expected to discuss all steps you would take, including identifying what switches/i ndications you would use Initiating Cue:

Preparations are underway for RX startup. You have been directed to dilute 200 gallons to reach critical boron concentration. Current RCS boron concentration is 1731 ppm. Terminating Conditions:

The Reactor has been tripped by de energizing the Rod Drive MG's.

Initial License Exam 03/2005 Job Performance Measure JPM: S7 Page 3 of 5 Rev Date: 1/26/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 1 Prepare for Dilution.

Refers to SOP-104A step 5.1.3. Note Start Time Note to Examiner: If asked, all prereq's are met.

2 Recognize First Out alarm is LIT Red and the need for a Reactor Trip. CUE: SR FLUX HI RX TRIP Alarm 6C (1.5) is in Alarm and lit RED. Respond to SR FLUX HI RX TRIP Alarm 6C (1.5) 3 Manually trips Reactor.

CUE: 1/1-RTC rotated but the Trip Breakers did not open. On CB07 turns 1/1-RTC "Rx Trip Bkr" in the counter clockwise direction 4 Manually trips Reactor.

CUE: 1/1-RTC rotated but the

Trip Breakers did not open.

On CB010 turns 1/1-RT "Rx Trip" in the counter clockwise direction

  • 5 Momentarily deenergizes the Rod Drive MG sets by opening 480 VAC MCC supply breakers 1B3 and 1B4.

CUE: All DRPI rod bottom lights are LIT.

TASK COMPLETE Rotates CS-1B3-1

counterclockwise to open and then clockwise back to close. Rotates CS-1B4-1 counterclockwise to open and then clockwise back to close. Note Completion Time

Initial License Exam 03/2005 Job Performance Measure JPM: S7 Page 4 of 5 Rev Date: 1/26/05 INITIATING CUE:

Preparations are underway for RX startup. You have been directed to dilute 200 gallons to reach critical boron concentration. Current RCS boron concentration is 1731 ppm.

Initial License Exam 03/2005 Job Performance Measure JPM: S-8 Page 1 of 5 Rev Date: 1/19/05 System: Component Cooling Water System JTA Task #: (Bank NRC 2002) Task Title: Shift CCW Pumps with CCW Pump Trip (ALTERNATE PATH)

KSA Ref: APE.026.AK3.04 PEO: RO: 3.5 SRO: 3.7 Operator's Name:

Performance Environment:

PLANT CONTROL ROOM SIMULATOR Performance Method:

PERFORMED SIMULATED DISCUSSED Time to complete JPM: Estimated 15 minutes Actual The operator's performance was evalua ted against the standards contained in this JPM and was determined to be: SATISFACTORY UNSATISFACTORY Reason, if unsatisfactory:

Evaluator's Signature:

Date: Comments (list all steps not satisfactorily completed):

References:

SOP-502A, "CCW System" ABN-502, "Component Cooling Water System Malfunction" Tools, Equipment, Job Aids, etc:

Simulator:

1) Any IC above Mode 4. 2) Insert and activate MALF-CC03B 3) Insert MALF-CC02B on a key. When CCW pump 1-01 is stopped, activate malfunction.

Initial License Exam 03/2005 Job Performance Measure JPM: S-8 Page 2 of 5 Rev Date: 1/19/05 Safety Considerations:

If this JPM is to be performed in the plant/control room, the candidate is NOT to manipulate any plant components unless he/she has permission from the Shift/Unit Supervisor. Human Performance Measures:

During this Job Performance Measure, MONITOR for demonstrations of the following as outlined in Operations department guidance:

Peer checking Three-way communications Phonetic alphabet Self checking ALM use Unit designators Conservative decision making Procedure place keeping Procedure rules of usage Comments:

NOTE to EXAMINER: during the CCWP shift, CCWP2 will trip off after CCWP1 has been secured. CCWP1 fails to autostart when CCWP2 trips, so the operator will have to manually restart CCWP1. The operator may attempt to trip the reactor based on loss of CCW instead of attempting to restart CCWP1; if he attempts a reactor trip, stop him and end the JPM (failure). The Reactor must not be tripped because it would interfere with another JPM being conducting concurrently.

Instructions:

You may use any approved reference materials, including logs. Make or simulate all written/oral reports as if the evolution is actually being performed. You are expected to discuss all steps you would take, including identifying what switches/i ndications you would use Initiating Cue:

The Unit Supervisor directs you to shift CCW pumps (start CCWP1-02, and secure CCWP1-01 per SOP-502 section 5.2.1) in preparation for maintenance. Terminating Conditions:

CCWP1 Running again (after CCWP2 trips off)

Initial License Exam 03/2005 Job Performance Measure JPM: S-8 Page 3 of 5 Rev Date: 1/19/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 1 Ensure SSWP2 is running CUE: SSWP2 indication is RED. Operator visually verifies SSWP2 is running by verifying handswitch indication is RED. Note Start time.

Give applicant a copy of SOP-502A, section 5.2. 2 Ensure oil level in bearing

housings for CCWP2 are normal. CUE: bearing housing oil levels are normal.

Operator directs PEO to verify oil level for CCWP2. 3 Operator may adjust flow prior to pump start in anticipation of unbalanced flow. This is not required for the JPM.

CUE: Flow has increased

enough to start 2 nd pump. Opens either 1-HS-

4574 CS HX 1 or 1-HS-4572 RHR HX to increase flow.

  • 4 Start CCWP2 CUE: u-HS-4519A handswitch light indication is RED.

Take handswitch u-HS-4519A to the start position and verify red light indication on the handswitch.

5 If the pumps are being rotated for their bi-weekly rotation per OWI-409, then momentarily initiate flow through the RHR and CS heat exangers.

CUE: This rotation is NOT part of the OWI program.

Initial License Exam 03/2005 Job Performance Measure JPM: S-8 Page 4 of 5 Rev Date: 1/19/05 STEP# *Critical ELEMENT STANDARD NOTES SAT/ UNSAT 6 Ensure the following equipment are removed from service before securing CCWP1: RHR Pumps 1-01, CS Pumps 1-01/03/

CUE: Listed Pumps are removed from service. Same as Element.

RHR and CS pumps that are loads supplied from the CCWP1 should be secured before securing the CCWP1.

7 Stop CCWP1 CUE: u-HS-4518A handswitch light indication is green. (CCWP2 trips):

u-HS-4519A green light and white trip light lit. Annunciator Alarms: CCWP 1/2 OVRLOAD/TRIP, CCW TRN A/B SFGD LOOP PRESS LO, CCW HX 1/2 OUT & RECIRC FLO LO, CCW HX 1/2 SPLY FLO LO Operator holds the u-HS-4518A handswitch in STOP until flow and pressure stabilize and then releases handswitch. WARNING:

Operator MAY attempt to trip RX (per section 6.0 of ABN-502A "Loss of all CCW

Flow") when CCWP2 trips; BUT, operator SHOULD go to section 2.0

ofABN-502A "CCW Pump Trip" and attempt to start CCWP1; 8 Verify unaffected train CCW Pump - RUNNING. NOTE: CCWP1 fails to auto start, and must be manually restarted.

CUE: u-HS-4518A handswitch light indication is green.

Operator recognizes that CCWP 1 is not running by noting u-HS-4518A handswitch

indication is GREEN on CB-3 If operator attempts to trip the RX, DO NOT allow RX trip, and terminate the

JPM. *9 Manually Start u-HS-4518A CCWP 1 CUE: u-HS-4518A RED light lit and flow restored.

TASK COMPLETE Take handswitch u-HS-4518A to the start position and verify red light indication on the handswitch and flow restored.

Note Completion

time.

Initial License Exam 03/2005 Job Performance Measure JPM: S-8 Page 5 of 5 Rev Date: 1/19/05 INITIATING CUE:

The Unit Supervisor directs you to shift CCW pumps (start CCWP1-02, and secure CCWP1-01 per SOP-502, section 5.2.1) in preparation for maintenance.

Revision 0 Appendix D Scenario Outline Form ES-D-1 Facility:

CPSES Scenario No.:

1 Op-Test No.:

1 Examiners:

Operators:

Note: (NEW) Do SRO Admin A.4.1, Emerg. Class. with this Scenario (SAE). Initial Conditions: BOL, 100% power Eq. Xenon. Unit 2 is at 100% power. The A MDAFWP is OOS for oil contamination. ( 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> into LCO)

IC-15, REMF FWR20 in Rackout with H/S in P.O and Red Tagged.

Turnover:

Unit 1 and Unit 2 are at 100% power. U1 has been at 100% for the last 15 days following refueling. The "A" MDAFWP is OOS due to contamination in the oil.

Maintenance is in the process of changing the oil and the pump should be ready for test in the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. The Generation Controller has declared an ALERT

due to the loss of several peaking plants and all of the Big Brown units due to a common mode failure. There are no surveillances planned for this shift and the orders are to maintain current load and unit availability.

Event No. Malf. No.

Event Type* Event Description 1 T=1 MS13D I (RO) I (BOP) I (SRO) SG Pressure channel for ARV #4 fails high. (ARV fails full

open) 2 T=7 RX15A @ 100% C (RO) C (SRO) PZR Spray valve fails open. (Set up trigger to remove Malf when the Manual PB is selected) 3 T=13 ED05F M (ALL) Loss of 1EA2 (86-2) 4 T=13 FW09A C (BOP) C (SRO) TDAFWP Overspeed. (will not come in until pump starts) 5 T=28 N (BOP) R (RO) N (SRO) Perform Plant Shutdown due to loss of 2 AFWP's. (Directed

by SM) 6 T=43 FW25C

@ 4e6 M (ALL) Feedline Break ORC 7 T=43 ED05I C (ALL) Loss of 1EA2 (86-1) 8 T=43 SI04A C (BOP) C (SRO) SI pump fails to start on Safety Injection. (Must be manually started. Set up trigger file to remove Malf when HS is turned

.) * (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Revision 0 Appendix D Narrative Description Op-Test No:

1 Scenario No:

1 Event No: Page 2 of 15 The objective of this scenario is to evaluate the operators ability to change Reactor power in a controlled manner when required by plant conditions, respond to various instrument and component failures, and to carry out the requisite emergency procedures to miti gate the consequences of a Lo ss of Heat Sink event.

Event One.

A failure high of the Main Steam Line Pressure channel that feeds the #4 SG ARV occurs. This failure will cause the ARV to open. Operator feedback for this event is an unexpected increase in Reactor Power that can exceed licensed limits and a decrease in RCS temperature with constant Turbine Load.

It is expected that the operators will:

Recognize that Reactor Power is increasing Take steps to reduce Reactor Power in acco rdance with Management Expectations and Pre Shift Briefings Diagnose plant conditions and determine that the ARV should NOT be open Enter the correct ABN procedure Place the controller in manual and close the valve Make the necessary notifications and refer to Technical Specifications.

Event Two.

One of the two Pressurizer Spray valves fails fully open. This is a failure of the valve in automatic and manual control remains available. Feedback to t he operators is evidenced by a decrease in Reactor Coolant system pressure that is not explained by plant conditions and can lead to a Reactor Protection System actuation. It is ex pected that the operators will:

Recognize that RCS pressure is decreasing Diagnose plant conditions and determine that RCS pressure should NOT be decreasing. Determine that the cause of the dec rease is the Spray valve failure. Take manual control of the spray valve and close it Enter the correct ABN procedure Make the necessary notifications and refer to Technical Specifications Event Three and Four.

Safeguards bus 1EA2 deenergizes due to an 86-2 lockout relay. An 86-2 lockout is caused by a phase to ground fault on the bus. The bus normal supply br eaker will open, the EDG will start, and the bus will be re-energized from the EDG. The bus will rema in powered by the EDG for the remainder of the scenario. The TDAFWP will overspeed on the BOS star t signal. Operator feedback is provided by alarm annunciation and equipment started by the Blackout S equencer. It is expected that the operators will:

Respond to Alarms and determine the loss of bus 1EA2. Determine that the BOS has actuated. Evaluate plant conditions and determine if the st art of the TDAFWP has caused Reactor Power to increase above license limits and meet management expectations to reduce power Enter the correct ABN procedure Stop unnecessary equipment started by the BOS Make the necessary notifications and refer to Technical Specifications Determine that the TDAFWP oversped on the BOS start signal It is expected that the SRO will recognize t he loss of 2 AFW pumps and determine the need to shutdown the plant per the Limiting Conditions for Operations.

Revision 0 Appendix D Narrative Description Op-Test No:

1 Scenario No:

1 Event No: Page 3 of 15 Event Five. Inoperable equipment requires a forced down power maneuver to meet license requirements.

In order to preclude unnecessary delay while the SRO communicates with plant management about plant conditions and make recommendations, the lead evaluator may direct the staff to act as SM and instruct the SRO to commence an immediate plant shutdown.

Operator feedback for the need to shutdown the plant will be Technical Specification LCO's or plant management di rection. It is expected that the crew will:

Refer to the appropriate plant procedure Complete a reactivity brief. Commence boration and reduce power using the Turbine Digital Control System Event Six, and Seven and Eight.

When power has been reduced enough to meet the requirements of NUREG 1021 and at the lead examiners discretion, a Main Feed System leak w ill occur outside the Reactor Containment Building.

Operator feedback for this event is decreasing st eam generator levels and increasing Main Feed Pump Speed. Annunciation will occur at the designed parameter

s. Concurrent with the Main Feedline Break, bus IEA2, (earlier energized by the ED G) will fault in such a manner t hat it cannot be re-energized.

Note: Noteworthy is that at this point there are NO AFW pumps available, the Main Feed and Condensate systems are unavailable due to the feed break, and that heat removal by the secondary system is not possible. It is inevitable that the crew will have to initiate feed and bleed of the RCS to remove decay heat.

When FRH-0.1A is entered, step 2 asks if BOTH CCP's are available. Due to the loss of 1EA2, the CCP 1-02 is unavailable. The crew should trip the RCP's and immediately go to step 11 and initiate feed and bleed. The crew will note at step 12 of FRH-0.1A that no SIP's are operating and take action to start at least one SIP.

It is expected that the crew will:

Recognize the need to trip the Reactor and initiate Safety Injection or respond to the automatic actuations. Enter the correct EOP and carry out the Immediate Actions Verify automatic actions have occurred, or take actions to compensate for the lack of automatic actions Initiate monitoring of the Critical Safety Function Status Trees Transition to the correct FRG when conditions are met. Initiate Feed and Bleed to remove decay heat from the core. Start SIP per step 12 of the FRG.

Revision 0 Appendix D Narrative Description Op-Test No:

1 Scenario No:

1 Event No: Page 4 of 15 Note: In the CPSES Probabilistic Risk Analysis, import ant operator actions are evaluated in Table 9 of the PRA Summary Document. Operator action to establish feed and bleed is the most important action listed with a normalized value of 100.

The scenario may be terminated when safety injection is providing cooling to the core and the Pressurizer PORV's are open to remove decay heat.

Recommended Critical Tasks:

Fails to control Pressurizer Pressure resulting in a Reactor Trip or Safety Injection. Fails to start a Safety Injection Pump prior to the initiation of Feed and Bleed. Fails to establish core cooling through initiation of Feed and Bleed when plant conditions are met.

Revision 0 Appendix D Op-Test No:

1 Scenario No:1 Event No:1 Page 5 of 15 Event

Description:

SG Pressure channel for ARV #4 fails high. (ARV fails full open)

Time RO BOP SRO Applicant's Actions or Behavior Recognizes that plant condi tions are not normal by observation of Nuclear power increasing RCS temperature decreasing Plant computer system alarms.

Diagnose plant conditions and determines that SG #4 ARV is open by its RED light, LIT and green light OFF.

Determine that the ARV should be closed. MSL pressure is normal, and one

channel indicates failure HIGH. (1-PI-2328, MSL 4 PRESS)

Note to Examiner: The crew may cl ose the ARV prior to entry to the procedure.

Enter ABN-709, section 2. STEAM LINE PRESSURE INSTRUMENT

MALFUNCTION Step 1. Check ONE Main Steamline Pressure Channel indicating -

GREATER THAN 60 psig differ ence between remaining channels.

NOTE: 1-PI-2328, MSL 4 PRESS is failed high.

Step 2. Verify Steam Generator At mospheric Relief Valves - CLOSED:

NO Step 2, RNO. Perform following:

a. IF pressure is less than 1125 psig, THEN manually close affected atmospheric relief valve.
b. Notify Chemistry that a release has occurred and for Chemistry to determine if a release permit is required per STA-603.
c. GO TO Step 11.

Step 11. Refer to Techni cal Specifications per Attachment 6.

Attachment 6 indicates TS are NA.

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Revision 0 Appendix D Op-Test No:

1 Scenario No:1 Event No:2 Page 6 of 15 Event

Description:

PZR Spray valve fails open.

Time RO BOP SRO Applicant's Actions or Behavior 3.1 Symptoms

a. Annunciator Alarms
b. Plant Indication Spray valve indicated open when not called for by master controller.

3.2 Automatic Actions

a. Control response for failed open spray valve(s)
1) Control and backup heaters come on.
2) Reactor trip at 1880 psig.
3) Safety Injection at 1820 psig.

NOTE to Examiner: If there is delay in putting the spray valve to manual an OTN16 turbine runback may occur.

Enter section ABN-705, section 3, Pressurizer Spray Valve Failure Step 1. CLOSE Pressurizer Spray Valve(s) u-PK-455B, RC LOOP 1 PRZR SPR VLV CTRL u-PK-455C, RC LOOP 4 PRZR SPR VLV CTRL Step 2. Check RCS pressure stable or increasing.

Sep 3. Verify RCS pressure returning to 2235 psig.

Step 4. Refer to the following Technical Specifications:

3.3.1, Reactor Trip Syst em (RTS) Instrumentation 3.3.2, Engineered Safety Features Actuation System (ESFAS)

Instrumentation 3.3.3, Post Accident Monitoring (PAM) Instrumentation 3.3.4, Remote Shutdown Instrumentation 3.4.1, RCS Pressure, Temperature, and Flow Departure from

Nucleate Boiling (DNB) Limits 3.4.14, RCS Pressure Isolation Valves (PIV) Leakage 13.4.14, Reactor Coolant System Pressure Isolation Valves

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Revision 0 Appendix D Op-Test No:

1 Scenario No:1 Event No:3 & 4Page 7 of 15 Event

Description:

LOR on 1EA2 (Bus will be powered by the EDG) and TDAFWP Overspeed Time RO BOP SRO Applicant's Actions or Behavior 2.1 Symptoms

a. Annunciator Alarms
b. Plant Indications Lockout relay (LOR) trip of any 6.9 KV safeguard bus A 6.9 KV bus de-energized with no apparent causes.

NOTE: It is probable that the crew will decrease Turbine Load approx. 50 MW in response the AFW pump start.

Enter ABN-602 section 3.

Step 1 Check Unit MODE - 1, 2, 3 OR 4 Step 2 Check 6.9 KV safeguard bus - AT LEAST ONE ENERGIZED CAUTION: If power is greater than 10%. MDAF W should be allowed to run until the sequencer times out. The pumps will be stopped in Section 8.0, if not required. DO NOT throttle AFW above 10% power. The AFWP flow control and isolation valves are required to be fully

open when above 10% power per TS 3.7.5.

NOTE: An emergency start will allow DG breaker to automatically close on a phase to ground bus An Operator Lockout signal from Blackout Sequencer (BOS) opens TDAFWP steam supply valves. The BOS also starts associated train MDAFWP. It may be necessary to limit AFW flow to prevent excessive RCS cooldown, or other adverse condition. Placing the TDAFW Pump in PULL-OUT with one safeguards bus de-energized will result in two inoperable AFW Pumps per TS 3.7.5. Throttling any train of AFW above 10% power renders the train INOPERABLE. Attachment 4 contains steps to deenergize the sequencer if the bus will not be needed. This would restore common equipment available to the other unit (e.g. CRACs, UPS).

  • BOLD INDICATES CRITICAL STEP Revision 2 Appendix D Op-Test No:

1 Scenario No:1 Event No:3 & 4Page 8 of 15 Event

Description:

LOR on 1EA2 (Bus will be powered by the EDG) and TDAFWP Overspeed Time RO BOP SRO Applicant's Actions or Behavior Step 3 Check 6.9 KV safeguard buses - BOTH ENERGIZED

a. Bus voltage, 6500-7100 volts
b. Bus frequency, 59.5-60.5 Hz
c. GO TO Step 5.

Step 5 Monitor blackout sequencer status:

a. Affected bus - ENERGIZED
b. Verify Blackout Sequencer -OPERATED OUTPUT-STEP TIME lights -ALL LIT OR Automatic lockouts AL light -LIT
c. Verify all required equipment actuated per Attachment 2.
d. Recover from blackout sequencer operation per Section 8 while continuing.

EXAMINER NOTE: After crew completes Att 2, the Booth Operator calls US as Shift Manager and informs the crew that the CPC RO will take over the ABN. The crew should focus on the determination of the TDAFWP status.

Symptoms Annunciator Alarms Plant Indications Automatic Action Enter ABN-305 Aux Feedwater Malfunction Step1 Verify Turbine Driven Auxiliary Feedwater Pump malfunctioning by one or more of the following indications:

AFWPT TRIP light on u-HS-2452F - LIT Step 2 Verify Turbine Driven Auxiliary Feedwater Pump - NOT TRIPPED

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Revision 0 Appendix D Op-Test No:

1 Scenario No:

1 3 & 4Page 9 of 15 Event

Description:

LOR on 1EA2 (Bus will be powered by the EDG) and TDAFWP Overspeed Time RO BOP SRO Applicant's Actions or Behavior Step 2 RNO. Perform the following:

a. Ensure at least one steam supply valve open: u-HS-2452-1, AFWPT STM SPLYVLV-MSL 4 u-HS-2452-2, AFWPT STM SPLYVLV-MSL 1
b. Lower u-SK-2452A, AFWPT SPD CTRL to 0% output.
c. Direct Plant Equipment Operator to perform the following per Attachment 1 1) Reset overspeed trip linkage.

The PEO reports that the overspeed tr ip linkage is galled and will not move enough to reset.

EXAMINER NOTE: After crew completes Att 2, and the SM is notified that the TD AFW Pump is INOPERABLE, the Booth Operator calls US as Shift Manager and informs the crew that they should focus on the plant Shutdown. The SM will inform the crew that they need to be in Mode 3 in 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. *BOLD INDICATES CRITICAL STEP Revision 0 Appendix D Op-Test No:

1 Scenario No:1 Event No:5 Page 10 of 15 Event

Description:

Power Reduction (Directed by the Shift Manager)

Time RO BOP SRO Applicant's Actions or Behavior Review IPO-003A, Power Operations Notifies Generation Controller prior to reducing load.

Notifies Chemistry and Radiation Prot ection if power will be reduction will be

> 15% in one hour Notifies Reactor Engineering of power reduction > 25%.

Calculates the amount of boration required Calculates the rate of boration Reviews AFD guidance Initiates boration using SOP-104A.

Sets in the desired unloading rate and amount using the Digital Control System Maintains AFD in the target band Maintains rods above the Rod Insertion Limit Maintains Tave within 1 degree of Tref

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Revision 0 Appendix D Op-Test No:

1 Scenario No:1 Event No:6&7 Page 11 of 15 Event

Description:

Feedline Break Outside Containment/Loss of 1EA2 Time RO BOP SRO Applicant's Actions or Behavior Annunciators Plant Indications Tave decreasing MFP speed increasing SG Level decreasing Enters EOP-0.0A.

Step 1. Verify Reactor Trip

a. Verify the following: Reactor Trip and bypass breakers- OPEN, AND Neutron Flux- DECREASING
b. All control position rod bottom lights-ON Step 2. Verify Turbine Trip:
a. All turbine stop valves - CLOSED Step 3. Verify Power to AC Safeguards Busses:
a. AC safeguards busses - AT LEAST ONE ENERGIZED AC safeguards bus voltage _ 6900 Volts (6500-7100 volts)
b. AC safeguards busses - BOTH ENERGIZED Step b. RNO Restore power to de-energized AC Safeguards bus per ABN-601 or 602, when time permits.

NOTE: It is probable that the crew will place the B EDG in Pull Out.

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Revision 0 Appendix D Op-Test No:

1 Scenario No:1 Event No:6&7 Page 12 of 15 Event

Description:

Feedline Break Outside Containment/Loss of 1EA2 Time RO BOP SRO Applicant's Actions or Behavior Step 4. Check SI Status:

a. Check If SI is Actuated:

SI actuation as indicated on the First Out Ann 1-ALB-6C SI Actuated blue status light - ON

b. Verify Both Trains SI Actuated:

SI Actuated blue status light - ON NOT FLASHING Step 4, RNO.

IF SI is NOT required, THEN go to EOS-0.1 A, REACTOR TRIP RESPONSE The CPC RO will refer to ABN-602 for 1EA2 Bus LOR

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Revision 0 Appendix D Op-Test No:

1 Scenario No:1 Event No:6&7 Page 13 of 15 Event

Description:

Feedline Break Outside Containment/Loss of 1EA2 Time RO BOP SRO Applicant's Actions or Behavior Transitions to EOS-0.1A, Reactor Trip Response Step 1. Check RCS Average Temperature - STABLE AT OR TRENDING TO 557° F.

Step 2. Check FW Status:

a. Verify reactor trip and bypass breaker - OPEN
b. Check RCS average temperatures - LESS THAN 564° F.
c. Verify Feedwater Isolation - ISOLATION COMPLETE
d. Verify total AFW to SGs - GREATER THAN 460 GPM.

Step 3. Check PRZR Level Control:

a. Level - GREATER THAN 17%
b. Verify charging - IN SERVICE c. Verify letdown - IN SERVICE
d. Level - TRENDING TO 25%

Step 4. Check PRZR Pressure Control:

a. Pressure - GREATER THAN 1820 PSIG
b. Pressure - STABLE AT OR TRENDING TO 2235 Step 5. Check SG Levels:
a. Narrow Range Level - GREATER THAN 5%
b. Control Feed flow to maintain narrow range level between 5% and 50%.

NOTE: The crew may get to this point or even further before the Heat Sink Red Path becomes required...

Steam Generator Levels will continue to decrease. There is no AFW flow and the plant condition continues to degrade. As it becomes clear to the crew that the location of the feed break precludes the establishment of normal feed to the Steam Generator s the crew will enter FRH-0.1A, Response to a Loss of Secondary Heat Sink.

At approximately 8 minutes after the Feed break, AFW flow to the SG's will still be 0 and the narrow range level will be <5%.

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Revision 0 Appendix D Operator Actions Op-Test No:

1 Scenario No:1 Event No:8 Page 14 of 15 Event

Description:

Loss of Heat Sink ( with SI Pump Failure)

Time RO BOP SRO Applicant's Actions or Behavior Enter FRH-0.1A Loss of Heat Sink Step 1 Check If Se condary Heat Sink is Required:

a. RCS pressure - GREATER THAN ANY NON_FAULTED SG PRESSURE b. RCS temperature - GREATER THAN 320°F Yes, continue to step 2.

Step 2. Check CCP Status - BOTH AVAILABLE Step 2, RNO. Immediately perform the following:

a. STOP ALL RCP's
b. Got to Step 11. OBSERVE CAUTION PRIOR TO STEP 11.

CAUTION: Steps 11 through 20 must be performed quickly in order to establish RCS heat removal by RCS bleed and feed.

Step 11. Actuate SI.

Step 12. Verify RCS Feed Path:

a. Check Pump Status: CCP's BOTH RUNNING OR AT LEAST ON CCP AND AT LEAST ONE SI PUMP-RUNNING
b. Check valve alignment for operating pumps - PROPER EMERGENCY ALIGNMENT PER ATTACHMENT 3.

Step 12, RNO. Manually start pumps.

  • BOLD INDICATES CRITICAL STEP Revision 0 Appendix D Operator Actions Op-Test No:

1 Scenario No:1 Event No:8 Page 15 of 15 Event

Description:

Loss of Heat Sink ( with SI Pump Failure) Time RO BOP SRO Applicant's Actions or Behavior Step 14. Reset SI Step 15. Reset SI Sequencers Step 16. Reset Containment Isolation Phase A and B.

Step 17. Reset Containment Spray Signal Step 18. Establish Instrument Air And Nitrogen to Containment.

a. Establish instrument air:
1) Verify air compressor running and establish instrument air to containment.
b. Establish nitrogen
1) Verify ACCUM 1-4 VENT CTRL, 1-HC-943 - CLOSED 2) Open SI/PORV ACCUM N2 ISOL VLV, 1/1-8880.

Step 19. Establish RCS Bleed Path:

a. Verify power to PRZR PORV block valves - AVAILABLE (NOTE: There is power to train A only, train B open, but without power) b. Verify PRZR PORV block valves - BOTH OPEN
c. Open both - PRZR PORV's.

Step 20. Verify Adequate RCS Bleed Path:

PRZR PORV's - BOTH OPEN PRZR PORV block valves - BOTH OPEN The Scenario may be terminated at the Lead Examiners discretion.

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SHIFT TURNOVER INFORMATION 1.0 INITIAL CONDTIONS:

Time in Core Life: BOL Tavg: 589 o F Reactor Power: 100%

RCS Pressure: 2235 psig Turbine Load:1200 MWe Xenon: Equil Boron Concentration:1263 ppm Rod Control: AUTO Rod Height: CB D @ 215steps 2.0 LCOAR/TECHNICAL SPECIFICATION ACTIONS IN EFFECT:

TS# Description Reason 3.7.5 AFW AFW Pump 1-01 OOS for Oil change 3.0 CLEARANCES IN EFFECT:

AFW Pump 1-01 OOS for Oil change 4.0 SAFETY SYSTEM SETTING BYPASS/MALFUNCTIONS None 5.0 DEGRADED EQUIPMENT 6.0 PLANNED EVOLUTIONS:

Return AFW Pump 1-01 to service when the oil change is complete.

7.0 TURNOVER INFORMATION:

Unit 1 and Unit 2 are at 100% power. U1 has been at 100% for the last 15 days following refueling. The "A" MDAFWP is OOS due to contamination in the oil. Maintenance is in the process of changing the oil and the pump should be ready for test in the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. The Generation Controller has declared an ALERT due to the loss of several peaking plants and all of the Big Brown units due to a common mode failure. There are no surveillance's planned for this shift and the orders are to maintain current load and unit availability.

Revision 0 Appendix D Scenario Outline Form ES-D-1 Facility:

CPSES Scenario No.:

2 Op-Test No.:

1 Examiners:

Operators:

Note: (NEW) Do SRO Admin A.4.2, Emerg. Class. With this Scenario (SAE). Initial Conditions: 42% power, Xenon Equilibrium, plant start-up in progress. Unit 2 is at 100%. (IC-13. Preload malfunctions RP07A, and RP07B Train A/B Auto SI failure. REMF FWR20 in Rackout with HIS in PO and red tagged)

Turnover:

Unit 1 is at 42% power and increasing per IPO-003A, step 5.4.19. Shift orders are to increase reactor power during the shift. The "A" MDAFWP is OOS due to

contamination in the oil. Maintenance is in the process of changing the oil and the pump should be ready for test in the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. The Generation Controller

has declared an ALERT due to the loss of several peaking plants and all of the Big Brown units due to a common mode failure. The expectation is that the ALERT will last until midnight. There are no surveillance's planned for this shift.

Event No. Malf. No.

Event Type* Event Description 1 T=0 N (SRO) R (RO) N (BOP) Increase Reactor Power 2 T=13 RX04B @ 100% I (SRO) I (BOP) SG level transmitter LT-552 fails high.

3 T=23 CV01B C (RO) C (SRO) Trip of Running CCP 4 T=33 CV13

@12gpm C (SRO) C (RO) Letdown Leak inside containment 5 T=40 RC15A C (ALL) RCP Seized Shaft 6 T=45 RC09A2 M (ALL) LBLOCA 7 T=45 RH01B C(ALL) RHRP1-2 Trip

  • (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Revision 0 Appendix D Narrative Description Op-Test No:

1 Scenario No:

2 Event No: Page 2 of 22 The objective of this scenario is to evaluate the operator's ability to change Reac tor power in a controlled manner, respond to various instrument and component failures, and to carry out the requisite emergency procedures to mitigate the consequences of a Loss of Coolant Accident.

Event One.

The operators are directed to c ontinue the plant startup.

In order to preclude unnecessary delay, the shift turnover will direct the crew to start the power increase immediately upon taking the watch. The customary reactivity brief will be allowed, but due to the ALERT for grid condi tions, an extensive pre job brief will not be held.

Operator feedback for the need to increas e power will be the ALERT condition or plant management direction. It is expected that the crew will:

Refer to the appropriate plant procedure Complete a reactivity brief. Commence dilution and increase power using the Turbine Digital Control System Event Two.

When power has been increased enough to meet t he requirements of NUREG 1021 and at the lead examiners discretion, the controlling level channel on SG 1-02 will fail high. This will cause the feed regulating valve to go closed more than normal due to the high indicated SG level. Operator feedback for this event is SG level alarms, steam flow/feed flow mismatch alar ms and increasing Reactor Coolant Average temperature due to lower than normal SG le vel. It is expected that the crew will:

Evaluate plant conditions and determine that SG 1-02 level is NOT normal Recognize that the feed flow does not match steam flow Determine that the level indicator LI-552 is reading higher than the other channels Take manual control of the FRV and match steam and feed flow Refer to the correct ABN procedure Make the necessary notifications and refer to Tec hnical Specifications. It is expected that the SRO will stop the power increase during this event.

Event Three.

The running CCP (CCP 1-01) trips. All charging and seal injection flow is lost. Without charging flow to cool the regenerative heat exchanger, letdown will flas h and cause the letdown relief to lift. Operator feedback for this event is provided by annunciation for the CCP trip and various annunciation due to loss of letdown. It is expect ed that the operator will:

Verify that CCW is at least 35 gpm to the RCP Thermal Barrier Heat Exchangers (Initial Operator Action) Isolate letdown (Initial Operator Action) Refer to the correct ABN procedure. Start the CCP 1-02 Establish charging flow to support letdown flow Establish letdown Make the necessary notifications and refer to Technical Specifications

Revision 0 Appendix D Narrative Description Op-Test No:

1 Scenario No:

2 Event No: Page 3 of 22 Event Four. Due to the previous valve, temperature and pressure cycles on the letdown system, a small leak occurs on the Letdown Isolation Valve LCV-460. The leak size is 12 gpm and is evidenced by, increasing charging flow, decreasing VCT level, increased make up to the VCT, and increasing radioactive gas levels inside the Containment. Due to the plant star tup in progress, which results in large dilutions and RCS tave leading turbine load, a decrease in PZR le vel may not be the first indication of the loss of inventory. It is expected that the crew will:

Respond to alarms and determine that pr essurizer level is decreasing. Verify that charging flow has incr eased to maintain pressurizer level Refer to the correct ABN procedure Increase charging and/or decrease letdown to maintain pressurizer level. Evaluate plant conditions and determine that the leak is greater than allowed by Technical Specifications and comply with t he Limiting Condition for Operation.

Event Five Failure of the seal package caused by the cycling of seal injection lead to the RCP 1-01 experiencing a seized shaft. If reactor power is

<48%, then the operator feedback will be MCB alarms for low flow and RCP trip. The operators should trip the Reactor to meet the requirements of the ABN procedures. If reactor power is > 48%, then a Reactor Trip will occu

r. Automatic Reactor Trips were blocked in the scenario setup.

NOTE: The evaluator should also note the crew's res ponse to the SG level in the 1-01 SG. RCS flow will be reversed and SG level will be abnormally high. It is not uncommon for a crew to believe that a SGTR has occurred due to this thermo hydraulic behavior.

It is expected that the operator will:

Respond to alarms and determine that the RCP has tripped. Trip the reactor (Initial Operator Action) Refer to the correct ABN procedure Enter the correct EOP and continue with the ABN procedure. Perform the Immediate Operator Actions from memory. Evaluate plant conditions and determine what Te chnical Specification Limiting Condition for Operations apply. Evaluate the level change in the 1-01 SG and determi ne that the level increase is due to reverse RCS flow through the SG.

Revision 0 Appendix D Narrative Description Op-Test No:

1 Scenario No:

2 Event No: Page 4 of 22 Event Six and Seven.

On the loop with the tripped RCP, a Large Break LOCA o ccurs. Safety Injection first out alarms will come in. The pressurizer will rapidly empty and containment pressure will rapidly increase to the HI-3 setpoint and containment spray will actuate.

It is expected that the crew will:

Recognize that a Safety Injection is required and initiate a Manual SI. Enter the correct EOP. Perform the Immediate Operator Actions from memory. Verify automatic actions, and determi ne that the RHR pump 1-02 has tripped. Trip RCP's when plant conditions meet those listed on the Fold Out page. Transition to the correct EOP Transition to the correct EOS Procedure when conditions are met Establishes at least one train of cold leg recirculation NOTE: In the CPSES Probabilistic Risk Analysis, import ant operator actions are evaluated in Table 9 of the PRA Summary Document. For this scenario, it is important that the Operators establish cold leg recirculation when required. Failure to establish long term cooling for the LBLOCA are major contributors to both the CDF and LERF considerations The scenario may be terminated when one train of cold leg recirculation has been established or at the discretion of the Lead Evaluator.

Recommended Critical Tasks Fails to manually control SG level, resulting in a Reactor Trip on SG Level. Fails to manually initiate Safety Injection when required by plant conditions. Fails to trip RCP's when required by plant conditions.

Revision 0 Appendix D Operator Actions Op-Test No:

1 Scenario No:

2 Event No: 1 Page 5 of 22 Event

Description:

Increase Reactor Power Time RO BOP SRO Applicant's Actions or Behavior Review IPO-003A, Power Operations Notifies Generation Controller prior to increasing load.

Calculates the amount of dilution required Calculates the rate of dilution Reviews AFD guidance Initiates dilution per SOP-104A.

Sets in the desired loading rate and amount using the Digital Control System Maintains AFD in the target band Maintains rods above the Rod Insertion Limit Maintains Tave within 1 degree of Tref

  • BOLD INDICATES CRITICAL STEP Revision 0

Appendix D Op-Test No:

1 Scenario No:

2 Event No: 2 Page 6 of 22 Event

Description:

SG Level Transmitter LT-552 Fails High Time RO BOP SRO Applicant's Actions or Behavior 2.1 Symptoms

a. Annunciator Alarms
b. Plant Indications
1) One steam generator level instrument indicating higher or lower than the other steam generators level instruments.

Diagnose Failed SG Level Controller and Enter ABN-710.

Step 1 Verify controlling level channel -FAILED.

Step 2 Manually controls the following, as necessary to maintain SG -

2 AT PROGRAMMED LEVEL.

u-FK-520, SG 2 FW FLO CTRL u-SK-509A, FWPT MASTER SPD CTRL Step 3 Verify instruments on comm on instrument line - NORMAL (See )

Step 4 Verify ALL other HI-HI level bistable windows on TSLB-3 for affected SG- DARK SG 2(Channels 527, 528, and 529) windows 1.3, 3.3, and 4.3

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Revision 0 Appendix D Op-Test No:

1 Scenario No:

2 Event No: 2 Page 7 of 22 Event

Description:

SG Level Transmitter LT-552 Fails High (cont) Time RO BOP SRO Applicant's Actions or Behavior Step 5 Verify automatic SG level control - DESIRED

a. Alternate level control channel responding normally. b. Automatic level control desired, as determined by Unit Supervisor.

Step 6 Select alternate channel:

Step 7 Verify affected SG conditions for auto level control. Feedwater and steam flows matched. SG level stable at program.

Step 8 Place Feedwater Flow OR Feedwater Bypass Control Valve in automatic AND ensure proper control.

Step 9 Within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, have an I&C Tec hnician place bistable test switches

for failed level channel in CLOSE utilizing Attachments 2 and 3.

Step 10 Verify appropriate Alarms AND Trip Status Lights LIT per AND note this verification in the Unit Log. Step 11 Refer to Technical Specifications, per Attachment 4.

RX trip Inst. Table 3.3.1-1 item #14 ESF Inst Table 3.3.2-1 item 6C Accident Monitoring Table 3.3.3-1 item # 13

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Description:

Trip of Running CCP Time RO BOP SRO Applicant's Actions or Behavior 3.1 Symptoms

a. Annunciator Alarms
b. Plant Indications
1. Amber MISMATCH or trip light(s) ON at the charging pump control switch.
2. Pressurizer level indicating lower than program level during steady state conditions.
3. Charging Flow will indicate 0 gpm 3.2 Automatic Actions
a. Letdown line isolation occurs at 17% pressurizer level AND pressurizer heaters will deenergize.

Diagnose CCP Trip and Enter ABN-105 NOTE: Step 1 and 2 may be performed concurrently. Step 1. (Initial Operator Action ) Verify Component Cooling Water flow to RCP Thermal Barrier HX(s)-GREATER THAN 35 GPM:

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Trip of Running CCP Time RO BOP SRO Applicant's Actions or Behavior Step 2. (Initial Operator Action ) Verify Letdown Flow - ISOLATED 1/u-8149A, LTDN ORIFICE ISOL VLV (45 GPM) - CLOSED 1/u-8149B, LTDN ORIFICE ISOL VLV (75 GPM) - CLOSED 1/u-8149C, LTDN ORIFICE ISOL VLV (75 GPM) -CLOSED 1/u-LCV-459, LTDN ISOL VLV -CLOSED 1/u-LCV-460, LTDN ISOL VLV -CLOSED Step 3. Verify at least one Charging Pump - RUNNING Step 3. (RNO)

Start a Charging Pump.

Step 4 Verify Seal Injection Flow to each RCP - BETWEEN 6 GPM AND 13 GPM Step 5 Verify RCP Parameters in - NORMAL OPERATING RANGE:

6 Verify PRZR level-GREATER THAN 17% AND INCREASING Step 7 Establish normal Letdown:

a. OPEN Letdown Isolation Valves: 1/u-LCV-460, LTDN ISOL VLV 1/u-LCV-459, LTDN ISOL VLV 1/u-8152, LTDN CNTMT ISOL VLV ORC 1/u-8160, LTDN CNTMT ISOL VLV IRC
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Trip of Running CCP Time RO BOP SRO Applicant's Actions or Behavior

b. Manually OPEN u-PK-131, LTDN HX OUT PRESS CTRL to 30% DEMAND (50% if restori ng two orifice valves).
c. Manually OPEN u-TK-130, LTDN HX OUT TEMP CTRL to 50%

DEMAND. d. Adjust charging to desired flow WH ILE maintaining seal injection flow between 6 and 13 gpm.

e OPEN selected Letdown Orifice Isolation Valve(s).

f Adjust u-PK-131, LTDN HX OUT PRESS CTRL to maintain approximately

310 psig AND place in AUTO.

g Adjust u-TK-130, LTDN HX OUT TEMP CTRL to maintain approximately

95°F AND place in AUTO.

Step 8 Verify RCS leakage - NORMAL

a. PRZR level stable at OR trending to program.
b. Charging flow less than 15 GPM above letdown flow.

Step 9 Refer to Technical Specifications listed in Section 9.1, this procedure.

9.1 Technical Specifications/Requirements 3.4.13, RCS Operational Leakage 3.4.14, RCS Pressure Is olation Valve (PIV) Leakage 3.4.15, RCS Leakage Detect ion Instrumentation 3.5.2, ECCS - Operating 3.5.3, ECCS - Shutdown 13.1.31, Boration Injection System - Operating 13.1.32, Boration Inject ion System - Shutdown

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Description:

Letdown Leak Inside Containment Time RO BOP SRO Applicant's Actions or Behavior 2.1 Symptoms

a. Annunciator Alarms 2.1 b. Plant Indications Containment humidity high or increasing Containment radiation levels high or increasing Incore instrument leakage alarm Containment temperature high or increasing Containment pressure high or increasing Containment dew point increasing Increased reactor coolant make-up frequency VCT level decreasing Charging flow increasing Pressurizer relief and safety valve temperature high Pressurizer level decreasing Condenser off gas radiation level increasing Enters ABN-103, RCS Leak Step 1 Verify charging pump - AT LEAST ONE RUNNING
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Description:

Letdown Leak Inside Containment Time RO BOP SRO Applicant's Actions or Behavior Step 2 Ensure Pressurizer level - AT OR TRENDING TO PROGRAM LEVEL SETPOINT a. Verify running charging pump cont roller automatically maintaining Pressurizer level at program setpoint u-FK-121, CCP CHRG FLOCTRL u-SK-459A, PDP SPD CTRL Step 3 Check PRZR Status a. PRZR PORVs - CLOSED 1/u-PCV-455A, PRZR PORV 1/u-PCV-456, PRZR PORV b. PRZR Safety Valves - CLOSED u-ZL-8010A, PRZR SFTY VLV A u-ZL-8010B, PRZR SFTY VLV B u-ZL-8010C, PRZR SFTY VLV C c. PRZR Spray Valves - RESPONDING NORMALLY TO CONTROL PRESSURE u-ZL-455B, RC LOOP 1 PRZRSPR VLV u-ZL-455C, RC LOOP 4 PRZR SPR VLV

d. Pressurizer Relief Tank level AND temperature - NO SIGNIFICANT INCREASE u-TI-468, PRT TEMP u-LI-470, PRT LVL u-PI-469, PRT PRESS
d. Check PRZR PORV AND Safety Valves for indication of leakage: u-TI-463, PRZR PORV OUT TEMP u-TI-464, PRZR SFTY VLV C OUT TEMP u-TI-465, PRZR SFTY VLV B OUT TEMP Step 4 Verify AUTO makeup in service 1/u-MU, RCS MU MAN ACT -START 43/u-MU, RCS MU MODE SELECT- AUTO Step 5 Verify 1/u-LCV-112A, VCT LVL CTRL VLV - ALIGNED TO VCT.

Step 6 Check Steam Generator status:

a. All Steam Generator levels - NORMAL
b. Verify SG feedwater/steam flow - NO SIGNIFICANT MISMATCH
c. Monitor PC-11 trends on affected Steam Generators for increased

radioactivity.

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Description:

Letdown Leak Inside Containment Time RO BOP SRO Applicant's Actions or Behavior Step 7 Verify primary sampling valves closed - u-MLB-1A2- LIGHTS DARK 1.1 u-HV-4165, PRZR STM SMPL ISOL VLV OPEN 2.1 u-HV-4166, PRZR LIQ SMPL ISOL OPEN 3.1 u-HV-4168, HL 1 SMPL ISOL OPEN 4.1 u-HV-4169, HL 4 SMPL ISOL OPEN Step 8 Announce over plant page:

"ATTENTION ALL PERSONNEL. WE HAVE INDICATION OF A LEAK FROM THE UNIT RCS. BE AWAR E OF POSSIBLE INCREASED RADIATION LEVELS OUTSIDE CONTAINMENT BUILDING. REPORT ANY

WATER SPILLAGE, OBSERVED LEAKS, OR UNEXPECTED TANK OR SUMP LEVEL INCREASES TO UNIT u CONTROL ROOM".

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Description:

RCP Seized Shaft Time RO BOP SRO Applicant's Actions or Behavior 2.1 Symptoms

a. Annunciators Alarm
b. Plant Indications Low flow indication on any reactor coolant loop. Breaker TRIP or MISMATCH light illuminated on any RCP handswitch. Motor amps on any RCP motor reading zero.

2.2 Automatic Actions

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Description:

RCP Seized Shaft Time RO BOP SRO Applicant's Actions or Behavior 2.1 Symptoms

a. Annunciators Alarm Plant Indications Automatic Actions Enters EOP-0.0A, Reactor Trip Response Step 1. Verify Reactor Trip
a. Verify the following: Reactor Trip and bypass breakers- OPEN, AND Neutron Flux- DECREASING
b. All control position rod bottom lights-ON Step 2. Verify Turbine Trip:
a. All turbine stop valves - CLOSED Step 3. Verify Power to AC Safeguards Busses:
a. AC safeguards busses -

AT LEAST ONE ENERGIXED AC safeguards bus voltage _ 6900 Volts (6500-7100 volts)

b. AC safeguards busses - BOTH ENERGIZED Step 4. Check SI Status:
a. Check If SI is Actuated:

SI actuation as indicated on the First Out Ann 1-ALB-6C SI Actuated blue status light - ON

b. Verify Both Trains SI Actuated:

SI Actuated blue status light - ON NOT FLASHING Step 4, RNO.

IF SI is NOT required, THEN go to EOS-0.1 A, REACTOR TRIP RESPONSE

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Description:

Reactor Trip Response Time RO BOP SRO Applicant's Actions or Behavior Transitions to EOS-0.1A, Reactor Trip Response Step 1. Check RCS Average Temperature - STABLE AT OR TRENDING TO 557° F.

Step 2. Check FW Status:

a. Verify reactor trip and bypass breaker - OPEN
b. Check RCS average temperatures - LESS THAN 564° F.
c. Verify Feedwater Isolation - ISOLATION COMPLETE
d. Verify total AFW to SGs - GREATER THAN 460 GPM.

Step 3. Check PRZR Level Control:

a. Level - GREATER THAN 17%
b. Verify charging - IN SERVICE c. Verify letdown - IN SERVICE
d. Level - TRENDING TO 25%

Step 4. Check PRZR Pressure Control:

a. Pressure - GREATER THAN 1820 PSIG
b. Pressure - STABLE AT OR TRENDING TO 2235 Step 5. Check SG Levels:
a. Narrow Range Level - GREATER THAN 5%
b. Control Feed flow to maintain narrow range level between 5% and 50%.

NOTE: Because of the RCP Trip, the level in the #1 SG will be higher than in the other SGs. The crew should NOT believe that this is indication of a SGTR. If they do, however, it will not effect the outcome of the scenario

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Description:

LB LOCA (Auto SI Fails) Time RO BOP SRO Applicant's Actions or Behavior 2.1 Symptoms

a. Annunciators Alarm Plant Indications RCS pressure and temperature rapidly dropping, Pressurizer level and pressure dropping and Containment Temperature and Pressure increasing rapidly. NOTE: It is expected that the operator will initiate Manual SI prior to procedure entry.

Transitions to EOP-0.0A.

Step 1. Verify Reactor Trip

a. Verify the following: Reactor Trip and bypass breakers- OPEN, AND Neutron Flux- DECREASING
b. All control position rod bottom lights-ON Step 2. Verify Turbine Trip:
a. All turbine stop valves - CLOSED Step 3. Verify Power to AC Safeguards Busses:
a. AC safeguards busses - AT LEAST ONE ENERGIZED AC safeguards bus voltage _ 6900 Volts (6500-7100 volts)
b. AC safeguards busses - BOTH ENERGIZED Step 4. Check SI Status:
a. Check If SI is Actuated:

SI actuation as indicated on the First Out Ann 1-ALB-6C SI Actuated blue status light - ON

b. Verify Both Trains DI Actuated:

SI Actuated blue status light - ON NOT FLASHING Step 4 RNO. Check if SI required (YES) Manually Initiate SI.

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Description:

LB LOCA (Auto SI Fails) Time RO BOP SRO Applicant's Actions or Behavior Step 5. Ensure Proper Saf eguards Equipment Operation Per Attachment 2.

NOTE: It is expected that the RHR pump trip will be noticed and documented during the performance of Attachment 2.

Step 6. Verify AFW Alignment

a. MDAFWP - RUNNING
b. Turbine Driven AFW Pump - RUNNING IF NECESSARY
c. AFW total flow - GREATER THAN 460 GPM
d. AFW Valves alignment - PROPER ALIGNMENT Step 7. Verify Containment Spray Not Required :
a. Containment Pressure - HAS REMAINED LESS THAN 18 PSIG (NO)

Step a RNO. Perform the following:

1) Verify Containment Spray initiated. 2) Verify appropriated MLB indication for CNTMT SPRAY (BLUE WINDOWS) AND PHASE B (ORANGE WINDOWS) 3) Verify containment spray flow 4) Ensure CHEM ADD TK DISCH VLVs - OPEN
5) Stop all RCPs. (NOTE: The crew will stop RCPs at this point instead of waiting until step 11. They may also have stopped the RCPs per the fold out page for this procedure.) 6) Go to step 8.

Step 8. Check if Main Steamlines should be Isolated:

a. Verify the following: Containment Pressure - GR EATER THAN 6 PSIG (YES)
b. Verify main steam isolation complete.

Step 9. Check RCS Average Temperature - STABLE AT OR TRENDING TO 557°F.

Step 9 RNO. Throttle AFW and stop dumping steam.

Step 10. Check PRZR Valve Status:

a. PRZR Safeties - CLOSED
b. Normal PRZR Spray valves - CLOSED c. PORVs - CLOSED
d. Power to at least one block valve - AVAILABLE e. Block valves - AT LEAST ONE OPEN
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Description:

LB LOCA (Auto SI Fails) Time RO BOP SRO Applicant's Actions or Behavior Step 11. Check if RCPs should be stopped:

a. ECCS pumps - AT LEAST ONE RUNNING CCP -OR- SI pump b. RCS subcooling - LESS THAN 25° F (55° F FOR ADVERSE CONTAINMENT)
c. Stop all RCPs.

Step 12. Check if any SG is Faulted:

a. Check pressures in all SGs: ANY SG DECREASING IN AN UNCONTROLLED MANNER

-OR- ANY SG COMPLETELY DEPRESSURIZED Step 13.Check if SG Tubes Are Not Ruptured:

Condenser off gas radiation

- NORMAL (COG-182, 1RE-2959) Main steamline radiation - NORMAL (MSL-178-181, 1RE-2325 -

2328) SG blowdown and sample radiation monitor - NORMAL (SGS-164, 1RE-4200) No Steam Generator level increasing in an uncontrolled manner Step 14. Check If RCS Is Intact:

Containment pressure - LESS THAN 1.3 PSIG Containment recirculation sump levels - NORMAL Containment radiation - NORMAL (GRID 4)

Step 14 RNO, Go to EOP-1.0A, LO SS OF REACTOR OR SECONDARY COOLANT *BOLD INDICATES CRITICAL STEP Revision 0 Appendix D Op-Test No:

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Description:

LB LOCA (Auto SI Fails) EOP 1.0A Loss of Reactor or Secondary Coolant Time RO BOP SRO Applicant's Actions or Behavior NOTE: It is expected that the RWST level will be at 45% within 17 minutes of the LBLOCA. The progress through EOP-1.0A will vary with each crew dependent upon how fast they proceed.

Actual progress is not important, but the transition to EOS-1.3 A, Trans fer to Cold Leg Recirculation, when plant conditions require, is.

Transitions to EOP-1.0A, Loss of Reactor or Secondary Coolant Step 1. Check if RCPs should be stopped:

a. ECCS pumps - AT LEAST ONE RUNNING CCP -OR- SI pump b. RCS subcooling - LESS THAN 25° F (55° F FOR ADVERSE CONTAINMENT)
c. Stop all RCPs.

NOTE: ALL RCPs SHOULD BE ST OPPED AT THIS POINT.

Step 2. Check if any SG is Faulted:

a. Check pressures in all SGs: ANY SG DECREASING IN AN UNCONTROLLED MANNER

-OR- ANY SG COMPLETELY DEPRESSURIZED Step 3. Check SG Levels:

a. Narrow Range Level - GREATER THAN 26%
b. Control Feed flow to maintain narrow range level between 26% and 50%.

Step 4.Check Secondary Radiation - NORMAL Condenser off gas radiation

- NORMAL (COG-182, 1RE-2959) Main steamline radiation - NORMAL (MSL-178-181, 1RE-2325 -

2328) SG blowdown and sample radiation monitor - NORMAL (SGS-164, 1RE-4200)

When RWST LVL LO-LO Alarm comes in, transition to EOS-1.3A, Transfer to Cold Leg Recirculation. (Reference EOP-1.0A fold out page and ALM 1-ALB-4B, 3.7)

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Description:

LB LOCA (Auto SI Fails) EOS 1.3A Transfer to Cold Leg Recirculation Time RO BOP SRO Applicant's Actions or Behavior Caution: Steps 1 through 3 should be performed without delay. FRGs should not be implemented prior to completion of these steps.

Step 1. Reset SI Step 2. Verify CCW Flow From RHR And Containment Spray Heat Exchangers.

Caution: Any ECCS pump taking suction from RWST should be stopped upon RWST EMPTY alarm at 12% level. Any Containment Spray pump taking suction from RWST should be stopped when RWST level reaches 6%.

Caution: Any ECCS or Containment Spray pump that loses suction or shows indication of cavitation should be stopped.

Caution: SI pumps should be stopped if RCS pressure is greater than their shutoff head pressure.

Step 3. Align ECCS For Cold Leg Recirculation

a. Check open CNTMT SMP TO RHRP 1 AND 2 SUCT ISOL VLVS: 1/1-8811A 1/1-8811B
b. Close RWST TO RHRP 1 AND RHRP 2 SUCT VLVS 1/1-8812A 1/1-8812B
c. Close SIP 1 AND SIP 2 MINIFLO VLVS:

1/1-8814A 1/1-8814B 1/1-8813 d. Close RHRP 1 AND RHRP 2 XTIE VLVS:

1/1-8716A 1/1-8716B

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Description:

LB LOCA (Auto SI Fails) EOS 1.3A Transfer to Cold Leg Recirculation Time RO BOP SRO Applicant's Actions or Behavior

e. Close the CCP ALT MINIFLO ISOL VLVS:

1/1-8511A 1/1-8512B 1/1-8511B 1/1-8512A

f. Open SI < -- > CHRG SUCT HDR XTIE VLVS:

1/1-8807A 1/1-8807B

g. Open RHRPs TO CCP/SIP SUCT VLVS:

1/1-8804A 1/1-8804B NOTE: Due to the RHR pump trip, only one train will be lined up for Cold Leg Recirculation.

Step 4. Align Containment Spray System for Recirculation:

a. Check RWST level - LESS THAN 24%.

Step a RNO. If Containment Spray ACTUATED, then continue with step 5. When RWST level is < 24%, continue with step 4b.

b. Realign Containment Spray System as follows:
1) Open CNTMT SMP TO CSP 1 & 3 AND 2 & 4 SUCT ISOL VLVS:

1-HS-4782 1-HS-4783

2) Close RWST TO CSP 1 & 3 AND 2 & 4 SUCT VLVS 1-HS-4758 1-HS-4759 The scenario may be terminated at the discretion of the Lead Examiner. *BOLD INDICATES CRITICAL STEP

SHIFT TURNOVER INFORMATION 1.0 INITIAL CONDTIONS:

Time in Core Life: BOL Tavg: 571 o F Reactor Power: 42%

RCS Pressure: 2250 psig Turbine Load: 429 MWe Xenon: Equil Boron Concentration: 1442 ppm Rod Control: MAN Rod Height: CB D @ 189 steps 2.0 LCOAR/TECHNICAL SPECIFICATION ACTIONS IN EFFECT:

3.0 CLEARANCES IN EFFECT:

TS# Description Reason 3.7.5 AFW AFW Pump 1-01 OOS for oil change 3.0 CLEARANCES IN EFFECT:

AFW Pump 1-01 OOS for oil change 4.0 SAFETY SYSTEM SETTING BYPASS/MALFUNCTIONS 5.0 DEGRADED EQUIPMENT 6.0 PLANNED EVOLUTIONS:

Return AFW Pump 1-01 to service when the oil change is complete.

7.0 TURNOVER INFORMATION:

Unit 1 is at 40% power and increasing per IPO-003A, step 5.4.19. Shift orders are to increase reactor power during the shift. The normal reactivity brief will be held, but an extensive pre job brief will not, due to the ALERT. The "A" MDAFWP is OOS due to contamination in t he oil. Maintenance is in the process of changing the oil and the pump should be ready for test in the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

The Generation Controller has declared an ALERT due to the loss of several peaking plants and all of the Big Brown units due to a common mode failure.

The expectation is that the ALERT will last until midnight. There are no surveillance's planned for this shift. Unit 2 is at 100% power.

Revision 0 Appendix D Scenario Outline Form ES-D-1 Facility:

CPSES Scenario No.:

3 Op-Test No.:

1 Examiners:

Operators:

Note: (NEW) Initial Conditions: BOL, 100% power Eq Xenon. The A MDAFWP is OOS for oil change. ( 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> into LCO)

IC-15, REMF FWR20 in Rackout with H/S in P.O and Red Tagged.

Preload RP09 A and B Turnover:

Unit 1 and Unit 2 are at 100% power. U1 has been at 100% for the last 15 days following refueling. The "A" MDAFWP is OOS due to contamination in the oil.

Maintenance is in the process of changing the oil and the pump should be ready for test in the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. The Generation Controller has declared an ALERT due to the loss of several peaking plants and all of the Big Brown units due to a common mode failure. There are no surveillances planned for this shift and the orders are to maintain current load and unit availability.

Event No. Malf. No.

Event Type* Event Description 1 T=0 SG01C

@ 8 gpm C (SRO) C (RO) SGTL on #3 Steam Generator 2 T=5 N (SRO) R (RO) N (BOP) Plant Shutdown Required by Steam Generator Tube Leak >

150 gpd. (May be directed by Duty Manager) 3 T= 17 RP06D@

150% I (SRO) I (RO) Loop 4 N-16 Instrument fails high.

4 T=17 RD08 C (SRO) C (RO) Rods move in the opposite direction (Auto only) 5 T=34 RD13B8

@ 6 RD03F8 C (SRO) C (RO) Two rods misaligned by more than 12 steps (Manual Rx trip

required). CBC Rod B8 slips to 6 steps and CBA rod F-8 drops to the bottom.

6 T=38 SG01C @ 675gpm M (ALL) SGTL increases to SGTR at 675 gpm 7 T=38 RP09A & B C (SRO) C (BOP) Phase A fails to actuate on SIS 8 T=46* MS13C

@ 100% I (SRO) I (BOP) The ARV on the ruptured SG fails open due to Main Steam

line pressure xmtr failure. May be manually closed.

  • or after step 3 but prior to Step 6 (Cooldown).
  • (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Revision 0

Appendix D Narrative Description Op-Test No:

1 Scenario No:

3 Event No: Page 2 of 20 The objective of this scenario is to evaluate the operator's ability to change Reac tor power in a controlled manner, respond to various instrument and component failures, and to carry out the requisite emergency procedures to mitigate the consequences of a Steam Generator Tube Rupture Accident.

Event One.

The 1-03 Steam Generator develops a tube leak at 8 gpm. This small leak will not be able to be diagnosed by comparing steam flow and feed flow for a mismatch. Operator feedback for the SGTL will be the Radiation Monitoring system and further investigation by the crew will reveal a small mismatch

between charging flow and letdown flows that is larger than usual. The first indication will be a Radiation Monitor alarm from the Main Steam line N-16 moni tors. Subsequent to the N-16 alarms, the Condenser Off Gas monitor will alarm followed by the less sensitiv e MSL radiation monitors. It is expected that the operators will:

Respond to the Radiation Monitor alarms Determine the SG 1-03 has a tube leak Refer to the correct ABN procedure Evaluate plant conditions and determine that condi tions require a plant shutdown to less than 50% in one hour and Mode 3 in two hours Make the necessary notifications and refer to Technical Specifications.

NOTE: The SRO will find that two ABN procedures apply. ABN-106, "High Secondary Activity" and ABN-103, "Excessive RCS Leakage" are both applicable to th is event. ABN-106 is c onstructed to evaluate SGTL size and then directs the crew to take actions based on leak size. ABN-103 is a diagnostic tool used to locate and isolate the leak. ABN-106 will not DIRECT the operator to ABN-103 because the leak is < 15gpm. It is expected that the crew will recognize the leak is in a steam generator and cannot be isolated, determine the need to shutdown the plant and proceed to IPO-003A for guidance to shutdown the plant.

Event Two. The SGTL requires a forced down power maneuver to meet management expectations and license requirements. In order to preclude unnecessary delay while the SRO communicates with plant management about plant conditions and make recommendations, the lead evaluator may direct the staff to act as SM and instruct the SRO to commence an immediate plant shutdown.

Operator feedback for the need to shutdown the plant will be ABN procedure r equirements, Technical S pecification LCO's, or plant management direction. It is expected that the crew will:

Refer to the appropriate plant procedure Complete a reactivity brief. Commence boration and reduce power using the Turbine Digital Control System

Revision 0 Appendix D Narrative Description Op-Test No:

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3 Event No: Page 3 of 20 Event Three and Four.

When power has been reduced enough to meet the requirements of NUREG 1021 and at the lead examiners discretion, the Loop 4 N-16 Reactor Protecti on channel fails high. This failure will cause the Control Banks for the Rod Control System to demand an inward sequence. This failure is further

compounded by a problem in the Rod Control system t hat causes the rods to move out when inward direction is required. Operator feedback for these events will be various alarms generated by the N-16

failure, turbine load and reactor stable, and rods movi ng in the outward direction with power matched and no significant RCS temperature deviation.

It is expected that the operators will:

Evaluate plant conditions and determine that Rod Motion is not warranted. Determine that Rod Control has malfunctioned and t hat rods are moving in the WRONG directionPlace Rod Control in MANUAL Refer to the correct ABN procedure Select out the failed channel Make the necessary notifications and refer to Technical Specifications. Determine that Rod Control should remain in MANUAL.

NOTE: Rod Control will remain in Manual for the re st of the scenario. It is not expected that the Operators will initiate a Reactor Trip for these ev ents. For the case of an unexpected RX trip, the scenario has been evaluated against the requirement and still exceeds minimum requirements if the next event is NOT completed, (misaligned rods).

Event Five At the lead examiners discretion, a continuation of the previous problem with Rod Control will be encountered. One Control Rod, CBA, Rod F-8, drops to the bottom and Control Rod CBC, Rod B8 slips to 6 steps. Feedback to the operators for this event will be alarms that indicate rods are misaligned by more than 12 steps and one control rod is at the bottom of the core. It is expected that the operators will:

Evaluate plant conditions and determine that more than one control rod is misaligned by more than 12 steps Recognize that ABN procedures require a Manual Reactor Trip or enter the correct ABN and comply with direction to trip the reactor.

Manually trip the reactor Enter the appropriate Emergency Procedure Complete the required Immediate Actions from memory.

Determine that Safety Injection is NOT required.

Transition to the appropriate Optimal Recovery procedure.

Revision 0 Appendix D Narrative Description Op-Test No:

1 Scenario No:

3 Event No: Page 4 of 20 Event Six and Seven.

Shortly after the reactor trip, due to stresses caused by t he trip, the tube that started to leak finally severs completely. The failure results in a Steam Generat or Tube Rupture event at 675 gpm. Concurrent with the SGTR, both trains of Containment Isolation Phase A system fail to respond in auto. Manual operation is available and it is expec ted that the operator manually init iate the Phase A using the manual handswitches. Operator feedback for this event is rapi dly decreasing pressurizer pressure and level, and increasing level in SG 1-03. The Phase A failu re will be evidenced by numerous components indicated on the Monitor Light Boxes not being in the positions called for in Attachment 2 of EOP-0.0A. It is expected that the operators will: Evaluate pressurizer and SG parameters and deter mine the need for Safety Injection or respond to the automatic SI Refer to correct Emergency procedure Complete Immediate Operator actions from memory Verify automatic actions have occurred. Take actions to compensate for lack of automatic actions if required. Diagnose Plant conditions and transition to the correct Optimal Recovery Procedure Identify the ruptured Steam Generator Isolate the ruptured Steam Generator Cool down and depressurize the RCS to minimize RCS leakage.

Event Eight.

After the SGTR has been diagnosed, and at the Lead Examiners discretion, the Main Steam Line pressure transmitter for the Ruptured Steam Generator fails high. This will c ause the ARV to go fully open. The valve will go open regardless of whether or not the operator has adjusted the setpoint to 1160 psig as required by EOP-3.0A. Operator feedback will be decreasing pressure in the ruptured steam generator, valve position indicating lights on the MCB, and RCS temperature decrease. It is expected

that the operators will: Evaluate plant conditions and determine that an uncontrolled RCS cooldown is in progress. Recognize that SG 1-03 pressure is not high enough for the ARV to be fully open. Recognize that the ruptured SG is no longer ISOLATED. Take manual control of the ARV and close it. Make the necessary notifications NOTE: The Lead Evaluator should carefully consider when to insert the ARV malfunction. If it is entered after the operator controlled cool down has been started, an important aspect of the feedback consideration will be lost.

NOTE: The CPSES PRA Assessment Summary document contains the following paragraph:

A SGTR event represents a unique challenge to the RCS safety systems. The SGTR combines a very small LOCA and an interfacing system LOCA. A rupture of the SG tubes results in leakage fro the RCS to the secondary-side which allows RCS inventory to bypass the containment. Thus, SGTR are important to both the CDF and LERF considerations. The operator must reduce RCS pressure and isolate the affected steam generator in order to re-establish adequate RCS integrity. One difference between the SGTR and the very small LOCA is that any water lost through the break to the SG will be lost from the containment and will become unavailable for re circulation. Therefore, it is important that the leakage from the RCS be minimized as soon as possible to preclude long term inventory problems. The loss of a steam generator reduces the number of steam generators available for decay heat removal and can lead to a loss of the auxiliary feedwater steam driven pump if the ruptured steam generator is not isolated from the steam supply line.

Revision 0 Appendix D Narrative Description Op-Test No:

1 Scenario No:

3 Event No:

Page 5 of 20 The scenario may be terminated when the RCS has been cooled down and depressurized to less than ruptured SG pressure or at the discretion of the Lead Evaluator.

Recommended Critical Tasks Fails to identify and isolate the ruptured Steam Generator when required by plant conditions. Fails to manually initiate Phase A when required by plant conditions. Fails to manually close the failed open ARV on the ruptured Steam Generator.

Revision 0 Appendix D Operator Actions Op-Test No:

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3 Event No: 1 Page 6 of 20 Event

Description:

Steam Generator Tube Leak on #3 SG Time RO BOP SRO Applicant's Actions or Behavior 2.1 Symptoms

a. Annunciator Alarms None
b. Plant Indications An abnormal increase in steam gener ator specific activity as reported by Chemistry. An abnormal increase in steam generator sampling radiation as indicated by u-RE-4200 (SGS-u64). An abnormal increase in condenser off-gas radiation as indicated by u-RE-2959(COG-u82). An abnormal increase in main steamline leak rate as indicated on u-RE-2325A (N16-u74), u-RE-2326A (N16-u75), u-RE-2327A (N16-u76), and u-RE-2328A (N16-u77). Computer points R7749A (R7753A) thru R7752A (R7756A).

Enters ABN-106, Steam Generator Tube Leak Step 1. Verify main steamline radiation alarms - CLEAR NOTE: u-RE-2327 (MSL-u80) will be in alarm on the PC-11 Step 1 RNO. Go to Section 3 of this procedure.

Section 3 Step 1. Verify main steamline radiation alarms - CLEAR Step 1 RNO.

a. Reduce power to 50% in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND Be in MODE 3 in the next 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.
b. GO TO Step 5.
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3 Event No: 1 Page 7 of 20 Event

Description:

Steam Generator Tube Leak on #3 SG Time RO BOP SRO Applicant's Actions or Behavior Step 5 Check plant conditions:

a. Turbine-Generator load - STEADY AT DESIRED POWER
b. Verify charging flow within 15 gpm of letdown flow AND both flows STABLE c. Verify PRZR level - STABLE OR TRENDING TO NORMAL LEVEL Step 6. Adjust affected Steam Gener ator Atmospheric Relief Controller setpoint to 1160 PSIG per TDM-501A/B.

Step 7. Verify affected Steam Generator - NOT SG #1 or SG #4 Step 8. Isolate Auxiliary Steam supplied from the affected unit by closing the applicable valves:

NOTE: The US will call the PEO to isolate the appropriate valves.

Step 9 Verify NO significant increase exists, as indicated on PC-11, from system(s) drains that discharge to the LVW:

Step 10 Monitor position of Steam Generator Atmospheric Relief AND Safety Valves during perfo rmance of this procedure:

a. Verify relief AND safety valves remain - CLOSED
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Revision 0 Appendix D Op-Test No:

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3 Event No: 2 Page 8 of 20 Event

Description:

Power Reduction Time RO BOP SRO Applicant's Actions or Behavior Review IPO-003A, Power Operations Notifies Generation Controller prior to reducing load.

Notifies Chemistry and Radiation Prot ection if power reduction will be > 15%

in one hour Notifies Reactor Engineering of power reduction > 25%.

Calculates the amount of boration required Calculates the rate of boration Reviews AFD guidance Initiates boration per SOP-104A.

Sets in the desired unloading rate and amount using the Digital Control System Maintains AFD in the target band Maintains rods above the Rod Insertion Limit Maintains Tave within 1 degree of Tref

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3 Event No: 3 & 4 Page 9 of 20 Event

Description:

Loop 4 N-16 Instrument Fails High and Rods move the wrong way Time RO BOP SRO Applicant's Actions or Behavior 2.1 Symptoms

a. Annunciator Alarms
b. Plant Indications:
3) One N-16 channel higher or lower than the other three.

2.2 Automatic Actions NOTE: This should alert the crew that rods moving OUT is a malfunction and action should be taken.

Enters ABN-704A, TC N16 Failure NOTE: Rod Control should remain in MANUAL until all channels are operable. This does not preclude placing rods in AUTO during rapidly changing transient conditions such as runbacks, etc. as long as rod control is returned to MA NUAL when the plant is stabilized.

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Revision 0 Appendix D Op-Test No:

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3 Event No: 3 & 4 Page 10 of 20 Event

Description:

Loop 4 N-16 Instrument Fails High and Rods move the wrong way Time RO BOP SRO Applicant's Actions or Behavior Step 1 Place Control Rods in - MANUAL NOTE: The RO should recognize that rods moved the wrong way, report this to the US, and recommend driving rods IN to match Tave to Tref.

Step 2 Select the failed channel on:

u-TS-412T, Tave CHAN DEFEAT Step 3 Verify Steam Dump System: NOT actuated NOT armed.

Step 4 Restore Tave to within 1°F of Tref.

Step 5 Select the failed channel on:

1/u-JS-411E, N16 PWR CHAN DEFEAT Step 6 Ensure a valid N16 channel is supplying the recorder:

1/u-TS-411E, u-TR-411 CHAN SELECT Step 7 Verify Steam Dumps not arm ed by observing the following light DARK: TURB LOAD REJ STM DMP ARMED C-7 (PCIP - 3.4)

Step 8 IF Steam Dumps were blocked in Step 2, THEN restore to service byreturning following switches to ON:

43/u-SDA, STM DMP INTLK SELECT 43/u-SDB, STM DMP INTLK SELECT Step 9 Within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, have I&C place bistable test switches for failed channel in CLOSED position per Attachments 1 and 2.

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3 Event No: 3 & 4 Page 11 of 20 Event

Description:

Loop 4 N-16 Instrument Fails High and Rods move the wrong way Time RO BOP SRO Applicant's Actions or Behavior Step 10 Verify appropriate alarms and trip status lights ON per Attachment 3 AND note verification in Unit Log.

Step 11 Refer to Technical Specificati ons listed in Section 3.1 of this procedure to determine applicable LCOAR conditions.

3.1 Technical Specifications/Requirements 3.3.1, Reactor Trip Syst em (RTS) Instrumentation 13.1.38, Control Bank Insertion Limits

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3 Event No: 5 Page 12 of 20 Event

Description:

Two dropped rods (Manual Reactor Trip Required) Time RO BOP SRO Applicant's Actions or Behavior 3.1 Symptoms

a. Annunciator Alarms
b. Plant Indications Plant parameters changing abnormally during rod position changes NIS Power Range instruments power or AFD indications disagree DRPI Rod Bottom Light(s) lit for rods which should be withdrawn DRPIs in a bank disagree by greater than 12 steps DRPI disagrees with its group step counter by greater than 12 steps Enter ABN-712 Rod Control Malfunction ExaminerNote: The crew may not reference the procedure but based on the procedure, take conservative action and trip the plant immediately.
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Revision 0 Appendix D Op-Test No:

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3 Event No: 5 Page 13 of 20 Event

Description:

Two dropped rods (Manual Reactor Trip Required) EOP-0.0A Time RO BOP SRO Applicant's Actions or Behavior 2.1 Symptoms

a. Annunciators Alarm Plant Indications Various First Out Annunciator al arms and changing plant conditions Manual reactor trip and enter EO P-0.0A, Reactor Trip Response Step 1. Verify Reactor Trip
a. Verify the following: Reactor Trip and bypass breakers- OPEN, AND Neutron Flux- DECREASING
b. All control position rod bottom lights-ON Step 2. Verify Turbine Trip:
a. All turbine stop valves - CLOSED Step 3. Verify Power to AC Safeguards Busses:
a. AC safeguards busses - AT LEAST ONE ENERGIZED AC safeguards bus voltage _ 6900 Volts (6500-7100 volts)
b. AC safeguards busses - BOTH ENERGIZED Step 4. Check SI Status:
a. Check If SI is Actuated:

SI actuation as indicated on the First Out Ann 1-ALB-6C SI Actuated blue status light - ON

b. Verify Both Trains SI Actuated:

SI Actuated blue status light - ON NOT FLASHING Step 4, RNO.

IF SI is NOT required, THEN go to EOS-0.1 A, REACTOR TRIP RESPONSE

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Description:

EOS-0.1 A, REACTOR TRIP RESPONSE Time RO BOP SRO Applicant's Actions or Behavior Transitions to EOS-0.1A, Reactor Trip Response Step 1. Check RCS Average Temperature - STABLE AT OR TRENDING TO 557° F.

Step 2. Check FW Status:

a. Verify reactor trip and bypass breaker - OPEN
b. Check RCS average temperatures - LESS THAN 564° F.
c. Verify Feedwater Isolation - ISOLATION COMPLETE
d. Verify total AFW to SGs - GREATER THAN 460 GPM.

Step 3. Check PRZR Level Control:

a. Level - GREATER THAN 17%
b. Verify charging - IN SERVICE c. Verify letdown - IN SERVICE
d. Level - TRENDING TO 25%

Step 4. Check PRZR Pressure Control:

a. Pressure - GREATER THAN 1820 PSIG
b. Pressure - STABLE AT OR TRENDING TO 2235 Step 5. Check SG Levels:
a. Narrow Range Level - GREATER THAN 5%
b. Control Feed flow to maintain narrow range level between 5% and 50%.

NOTE: 4 minutes after the manual RX Trip, the SGTR becomes active at 675 GPM. If not done automatically, the crew should Initiate a Safety Injection and transition to EOP-0.0A, step 1.

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3 Event No: 6 & 7 Page 15 of 20 Event

Description:

SGTR with failure of Phase A to auto actuate Time RO BOP SRO Applicant's Actions or Behavior 2.1 Symptoms

a. Annunciators Alarm PRZR PRESS LO SI ACT (6C-2.7)

Plant Indications Various First Out Annunciator al arms and changing plant conditions Automatic Actions Safety Injection and ECCS actuations Step 1. Verify Reactor Trip

a. Verify the following: Reactor Trip and bypass breakers- OPEN, AND Neutron Flux- DECREASING
b. All control position rod bottom lights-ON Step 2. Verify Turbine Trip:
a. All turbine stop valves - CLOSED Step 3. Verify Power to AC Safeguards Busses:
a. AC safeguards busses - AT LEAST ONE ENERGIZED AC safeguards bus voltage _ 6900 Volts (6500-7100 volts)
b. AC safeguards busses - BOTH ENERGIZED Step 4. Check SI Status:
a. Check If SI is Actuated:

SI actuation as indicated on the First Out Ann 1-ALB-6C SI Actuated blue status light - ON

b. Verify Both Trains SI Actuated:

SI Actuated blue status light - ON NOT FLASHING

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Description:

SGTR with failure of Phase A to auto actuate Time RO BOP SRO Applicant's Actions or Behavior Step 5. Ensure Proper Safeguards Equipment Operation Per .

NOTE: It is expected that the failure of Phase A to actuate will be noted and a manual Phase A initiated while is being performed.

Step 6. Verify AFW Alignment

a. MDAFWP - RUNNING
b. Turbine Driven AFW Pump - RUNNING IF NECESSARY
c. AFW total flow - GREATER THAN 460 GPM
d. AFW Valves alignment - PROPER ALIGNMENT Step 7. Verify Containment Spray Not Required :
1) a. Containment Pressure -

HAS REMAINED LESS THAN 18 PSIG Step 8. Check if Main Steamlines should be Isolated:

a. verify the following: Containment Pressure - GR EATER THAN 6 PSIG (YES)
b. Verify main steam isolation complete.

Step 9. Check RCS Average Temperature - STABLE AT OR TRENDING TO 557°F.

Step 10. Check PRZR Valve Status:

a. PRZR Safeties - CLOSED
b. Normal PRZR Spray valves - CLOSED c. PORVs - CLOSED
d. Power to at least one block valve - AVAILABLE e. Block valves - AT LEAST ONE OPEN
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Description:

SGTR with failure of Phase A to auto actuate Time RO BOP SRO Applicant's Actions or Behavior Step 11. Check if RCPs should be stopped:

a. ECCS pumps - AT LEAST ONE RUNNING CCP -OR- SI pump b. RCS subcooling - LESS THAN 25° F (55° F FOR ADVERSE CONTAINMENT)

Step 12. Check if any SG is Faulted:

a. Check pressures in all SGs: ANY SG DECREASING IN AN UNCONTROLLED MANNER

-OR- ANY SG COMPLETELY DEPRESSURIZED Step a RNO, Go to Step 13.

b. Go to EOP-2.0A, FAULTED STEAM GENERATOR ISOLATION, Step 1.

Step 13.Check if SG Tubes Are Not Ruptured:

Condenser off gas radiation

- NORMAL (COG-182, 1RE-2959) Main steamline radiation - NORMAL (MSL-178-181, 1RE-2325 -

2328) SG blowdown and sample radiation monitor - NORMAL (SGS-164, 1RE-4200) No Steam Generator level increasing in an uncontrolled manner Note: Steam Generator #3 is rupt ured at 675 GPM. The crew should transition to EOP-3.0A, Steam Generator Tube Rupture

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Description:

SGTR EOP-3.0A Steam Generator Tube Rupture Time RO BOP SRO Applicant's Actions or Behavior Step 1. Check if RCPs should be stopped:

a. ECCS pumps - AT LEAST ONE RUNNING CCP -OR- SI pump b. RCS subcooling - LESS THAN 25° F (55° F FOR ADVERSE CONTAINMENT)

Step 2. Identify Ruptured SG (s):

Unexpected increase in any SG narrow range level

-OR- High Radiation form any SG blowdown sample line (SGS-164, 1 RE-

4200) -OR- High Radiation from any Main steamline. (MSL-178-181, 1 RE-

2325-2328)

Step 3 Isolate Flow From Ruptured SG(s):

a. Adjust ruptured SG(s) atmospheric controller setpoint to 1160 PSIG.
b. Check ruptured SG(s) atmospheric - CLOSED
c. Close ruptured SG(s) main steamline isolation and ensure bypass valve closed.
d. Pull-Out steam supply valve handswitch from ruptured SG(s) to Turbine Driven AFW pump.
e. Close ruptured SG drippot isolation valve.
f. Verify blowdown isolation valves from ruptured SG(s) - CLOSED EXAMINER NOTE: Ensure the booth operator inserts Malfunction to fail ARV open, NOW.

Notes that the #3 ARV is open. Verify the SG pressure is less than 1160, places the controller in manual, and closes the ARV.

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Description:

SGTR EOP-3.0A Steam Generator Tube Rupture Time RO BOP SRO Applicant's Actions or Behavior Step 5 Check Ruptured SG(s) Pressure - GREATER THAN 420 PSIG.

Step 6 Initiate RCS Cooldown:

a. When PRZR pressure decreases to less than 1960 psig, block the low steamline pressure SI signal.
b. Determine required core exit temperature from Table 1.

NOTE: It is probable that the temperature selected from the Table will be 485°F. c. Dump steam to condenser from intact SG(s) at maximum rate and avoid main steam isolation.

1) Transfer Steam Dump to steam pressure mode. 2) Place the steam pressure controller in manual increase demand. 3) When P-12 (553°F TAVG is reached, select bypass interlock on Steam Dumps and continue cooldown.
d. Core exit TCs - LESS TH AN REQUIRED TEMPERATURE Step 6d RNO Continue with step 7.

WHEN core exit TCs less than required temperature, THEN do step 6e and 6f.

Step 7. Check Intact SG Levels:

a. Narrow Range Level - GREAT ER THAN 5%(26% FOR ADVERSE CONTAINMENT)
b. Control Feed flow to maintain narrow range level between 5% and 50%.

Step 8. Check PRZR PORVs and Block Valves:

a. Power to block valves - AVAILABLE
b. PORVs - CLOSED
c. Block valves - AT LEAST ONE OPEN Step 9. IF the Diesels Are Running, THEN Place Both DG EMER STOP/START Handswitches in START.

Step 10. Reset SI.

Step 11. Reset SI sequencers.

Step 12. Reset Containment Isolation Phase A and B.

Step 13. Reset Containment Spray Signal.

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Description:

SGTR EOP-3.0A Steam Generator Tube Rupture Time RO BOP SRO Applicant's Actions or Behavior Step 14. Establish Instrument Air And Nitrogen to Containment.

a. Establish instrument air:
1) Verify air compressor running and establish instrument air to containment.
b. Establish nitrogen
1) Verify ACCUM 1-4 VENT CTRL, 1-HC-943 - CLOSED 2) Open SI/PORV ACCUM N2 ISOL VLV, 1/1-8880.

Step 15. Check if RHR Pumps Should be Stopped:

a. RCS pressure - GREATER THAN 325 PSIG (425 PSIG FOR ADVERSE CONTAINMENT) b. Stop RHR Pumps and place in standby c. Reset RHR auto switchover.

Step 16. Check If RCS Cooldown Should Be Stopped:

a. Core exit TC's - LESS THAN REQUIRED TEMPERATURE
b. Verify Steps 6 e and 6 f are complete.

Step 17. Check Ruptured SG(s) Pressure - STABLE OR INCREASING Step 18. Check RCS subcooling - GREATER THAN 45°F (75°F FOR ADVERSE CONTAINMENT)

Step 19. Depressurize the RCS to Minimize Break Flow and Refill PRZR:

a. Normal Spray - AVAILABLE b. Place all PRZR heater sw itches in OFF position. c. Spray PRZR with maximum available spray until ANY of the following conditions satisfied: 1) RCS pressure - LESS THAN RUPTURED SG(s)

PRESSURE 2) PRZR level - GREATER THAN 6% (34% FOR ADVERSE CONTAINMENT

-OR-PRZR level GREATER THAN 74% (65% FOR ADVERSE CONTAINMENT)

-OR-RCS subcooling - At 25°F (55°F FOR ADVERSE

CONTAINMENT)

The scenario may be terminated at the discretion of the lead examiner.

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SHIFT TURNOVER INFORMATION 1.0 INITIAL CONDTIONS:

Time in Core Life: BOL Tavg: 589 o F Reactor Power: 100% RCS Pressure: 2235 psig Turbine Load:1200 Mwe Xenon: Equil Boron Concentration:1263 ppm Rod Control: AUTO Rod Height: CB D @ 215steps 2.0 LCOAR/TECHNICAL SPECIFICATION ACTIONS IN EFFECT:

TS# Description Reason 3.7.5 AFW AFW Pump 1-01 OOS for oil change 3.0 CLEARANCES IN EFFECT:

AFW Pump 1-01 OOS for Oil Change 4.0 SAFETY SYSTEM SETTING BYPASS/MALFUNCTIONS None 5.0 DEGRADED EQUIPMENT 6.0 PLANNED EVOLUTIONS:

Return AFW Pump 1-01 to service when the oil change is complete.

7.0 TURNOVER INFORMATION:

Unit 1 and Unit 2 are at 100% power. U1 has been at 100% for the last 15 days following refueling. The "A" MDAFWP is OOS due to contamination in the oil.

Maintenance is in the process of c hanging the oil and the pump should be ready for test in the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. The G eneration Controller has declared an ALERT due to the loss of several peaking plants and all of the Big Brown units due to a common mode failure. There are no surveillance's planned for this shift and the

orders are to maintain current load and unit availability.

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