Text

Initial Exam 2015-301 Draft Administrative JPMs
	ML16049A501
Person / Time
Site:	Farley
Issue date:	02/18/2016
From:	; Division of Reactor Safety II
To:	; Southern Nuclear Operating Co
References
	Download: ML16049A501 (218)
	v • d • e

FNP ILT-38 ADMIN Page 1 of 5 A.1.a RO/SRO TITLE: Critical Safety Function Status Tree Evaluation.

EVALUATION LOCATION: SIMULATOR CONTROL ROOM CLASSROOM PROJECTED TIME: 10 MIN SIMULATOR IC NUMBER: N/A ALTERNATE PATH TIME CRITICAL PRA JPM DIRECTIONS:

1. Initiation of task may be in group setting, evaluation performed individually upon completion.

2. Requiring the examinee to acquire the required materials may or may not be included as part of the JPM.

TASK STANDARD: Upon successful completion of this JPM, the examinee will:

Correctly assess and determine the status of ALL CSFs and then determine which FRP is required to be implemented using FNP-2-CSF-0.0.

Examinee:

Overall JPM Performance: Satisfactory Unsatisfactory Evaluator Comments (attach additional sheets if necessary)

EXAMINER:

Developer S. Jackson Date: 4/2/15 NRC Approval SEE NUREG 1021 FORM ES-301-3

FNP ILT-38 ADMIN A.1.a RO/SRO Page 2 of 5 CONDITIONS When I tell you to begin, you are to MONITOR AND EVALUATE CRITICAL SAFETY FUNCTION STATUS TREES. The conditions under which this task is to be performed are:

a. Unit 2 tripped from 100% power and Safety Injected 30 minutes ago.

b. Plant conditions are given in the attached Table 1.

c. The crew is performing actions in EEP-1, Loss of Reactor or Secondary Coolant.

d. The SPDS computer is NOT available for monitoring Critical Safety Functions.

e. You have been directed to manually monitor the Critical Safety Functions using CSF-0.0, Critical Safety Function Status Trees, on Unit 2.

Your Task is to:

1. Document each CSF evaluation on FNP-2-CSF-0.0 by circling the final colored ball indicating the CSF status.

2. Report the FRP that is required to be implemented, if any.

INITIATING CUE: IF you have no questions, you may begin.

EVALUATION CHECKLIST RESULTS:

ELEMENTS: STANDARDS: (CIRCLE)

START TIME

1. Evaluate CSF-0.1. POWER RNG LESS THAN 5% - S / U YES BOTH INT RNG SUR ZERO OR NEGATIVE - NO Determines that an Orange condition exists to go to FRP-S.1.

2. Evaluate CSF-0.2. FIFTH HOTTEST CORE EXIT S / U TC LESS THAN 1200°F - YES RCS SUBCOOLING FROM CORE EXIT TCS GRTR THAN 16°F{45°F} - YES Determines that this CSF is SAT.

FNP ILT-38 ADMIN A.1.a RO/SRO Page 3 of 5 EVALUATION CHECKLIST RESULTS:

ELEMENTS: STANDARDS: (CIRCLE)

3. Evaluate CSF-0.3. NAR RNG LVL IN AT LEAST S / U ONE SG GRTR THAN 31%{48%} - NO TOTAL AFW FLOW TO ALL SGS GRTR THAN 395 GPM -

YES PRESS IN ALL SGS LESS THAN 1129 PSIG - YES NAR RNG LVL IN ALL SGS LESS THAN 82% - YES PRESS IN ALL SGS LESS THAN 1075 PSIG - YES NAR RNG LVL IN ALL SGS GRTR THAN 31% - NO Determines that a Yellow condition exists to go to FRP-H.5.

4. Evaluate CSF-0.4. TEMP DECR IN ALL CL IN LAST 60 MIN LESS THAN 100°F - NO ALL RCS PRESS CL TEMP (IN LAST 60 MIN) POINTS TO RIGHT OF LIMIT A - YES ALL RCS CL TEMPS IN LAST 60 MIN GRTR THAN 285°F -

NO Determines that an Orange condition exists to go to FRP-P.1.

FNP ILT-38 ADMIN A.1.a RO/SRO Page 4 of 5 EVALUATION CHECKLIST RESULTS:

ELEMENTS: STANDARDS: (CIRCLE)

5. Evaluate CSF-0.5. CTMT PRESS LESS THAN 54 PSIG - YES CTMT PRESS LESS THAN 27 PSIG - YES CTMT SUMP LVL LESS THAN 7.6 FT. - YES BOTH CTMT RAD LESS THAN 2 R/hr. - YES Determines that this CSF is SAT.

6. Evaluate CSF-0.6. PRZR LVL LESS THAN 92% -

YES PRZR LVL GRTR THAN 15% -

NO Determines that a Yellow condition exists to go to FRP-I.2.

7. Determines FRP entry requirements. Determines that FRP-S.1 is required to be implemented.

STOP TIME Terminate when all elements of the task have been completed.

CRITICAL ELEMENTS: Critical Elements are denoted with an asterisk () before the element number.

FNP ILT-38 ADMIN A.1.a RO/SRO Page 5 of 5 GENERAL

REFERENCES:

1. FNP-2-CSF-0.0, ver 12.0

2. KA: G2.1.7 - 4.4 / 4.7 G2.1.20 - 4.6 / 4.6 GENERAL TOOLS AND EQUIPMENT:

1. FNP-2-CSF-0.0, ver 12.0 - on Reference disk

2. FNP-2-CSF-0.0, ver 12.0 - paper copy Critical ELEMENT justification:

STEP Evaluation 1 Critical: Task completion: required to properly evaluate CSF-0.1 to determine that an Orange path condition exists. This is the highest priority FRP for the conditions given. If this is not evaluated properly, a transition to a lower level procedure could occur, and the highest priority FRP would not be implemented.

2-6 Critical: Task completion: Actions are required to evaluate each CSF properly to complete task successfully. This CSF evaluation should determine the CSF color and procedure, if any, that apply.

7 Critical: Task completion: required to determine that FRP-S.1 is to be implemented.

COMMENTS:

HLT38 ADMIN Exam A.1.a HANDOUT Page 1 of 2 CONDITIONS When I tell you to begin, you are to MONITOR AND EVALUATE CRITICAL SAFETY FUNCTION STATUS TREES. The conditions under which this task is to be performed are:

a. Unit 2 tripped from 100% power and Safety Injected 30 minutes ago.

b. Plant conditions are given in the attached Table 1.

c. The crew is performing actions in EEP-1, Loss of Reactor or Secondary Coolant.

d. The SPDS computer is NOT available for monitoring Critical Safety Functions.

e. You have been directed to manually monitor the Critical Safety Functions using CSF-0.0, Critical Safety Function Status Trees, on Unit 2.

Your Task is to:

1. Document each CSF evaluation on FNP-2-CSF-0.0 by circling the final colored ball indicating the CSF status.

2. Report the FRP that is required to be implemented, if any.

HLT38 ADMIN Exam A.1.a HANDOUT Page 2 of 2 Table 1 INSTRUMENT Channel I or Channel II or Parameter Channel III Channel IV Train A Train B Power Range NI 0% 0% 0% 0%

Intermediate Range SUR +0.2 DPM +0.25 DPM Intermediate Range NI 3.0x10-8 AMPS 3.2x10-8 AMPS Source Range SUR 0 DPM 0 DPM Source Range NI 0 CPS 0 CPS RCS Pressure 1575 psig 1550 psig MCB Core Exit T/C Monitor 329°F 325°F in TMAX mode PRZR level 2% 4% 5%

CTMT Pressure 0 psig 0 psig 0 psig 0 psig RCS Subcooling 275°F 278°F CTMT Emergency Sump Levels 0 inches 0 inches CTMT Radiation < 1 R / Hr < 1 R / Hr RCS Loop 2A RCS Loop 2B RCS Loop 2C Parameter SG NR Level 20% 0% 20%

(all channels)

AFW flow 325 GPM 0 GPM 340 GPM SG Pressure 800 psig 25 psig 820 psig (all channels)

RCS WR Cold Leg Temperature 420°F 265°F 425°F RCP status Off Off Off

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KEY2 UNIT 8/29/2007 08:33 FNP-2-CSF-0.1 SUBCRITICALITY Revision 12 APPLICANT IS ONLY REQUIRED TO ANNOTATE THE CSF OR THAT THE CSF IS SAT GO TO FRP-S.1 GO TO FRP-S.1 NO POWER RNG LESS THAN GO TO 5% FRP-S.2 YES BOTH INT RNG SUR NO NO MORE BOTH INT NEGATIVE RNG SUR THAN -0.2 YES ZERO OR DPM NEGATIVE YES CSF SAT NO BOTH SOURCE RNG ENERGIZED YES GO TO FRP-S.2 BOTH NO SOURCE RNG SUR ZERO OR NEGATIVE YES CSF SAT Page 1 of 1 KEY

8/29/2007 08:33 KEY2 UNIT FNP-2-CSF-0.2 CORE COOLING Revision 12 APPLICANT IS ONLY REQUIRED TO ANNOTATE THE CSF OR THAT THE CSF IS SAT GO TO FRP-C.1 GO TO FRP-C.2 FIFTH HOTTEST NO CORE EXIT TC LESS FIFTH NO THAN YES HOTTEST 1200 F CORE EXIT TC LESS THAN 700° YES RCS SUBCOOLING NO GO TO FROM CORE FRP-C.3 q EXIT TC'S GRTR THAN YES 16° F {45° F}

CSF SAT Page 1 of 1 KEY

8/29/2007 08:33 KEY2 UNIT FNP-2-CSF-0.3 HEAT SINK Revision 12 GO TO FRP-H.1 TOTAL AFW NO FLOW TO ALL SG'S GRTR THAN 395 GPM YES GO TO FRP-H.2 NAR RNG LVL IN AT NO PRESS IN NO LEAST ONE ALL SG'S SG GRTR LESS THAN THAN 31% YES 1129 PSIG YES

{48%}

GO TO APPLICANT IS ONLY FRP-H.3 REQUIRED TO ANNOTATE THE CSF OR NO NAR RNG THAT THE CSF IS SAT LVL IN ALL SG'S LESS THAN 82% YES GO TO FRP-H.4 PRESS IN NO ALL SG'S LESS THAN 1075 PSIG YES GO TO FRP-H.5 NAR RNG NO LVL IN ALL SG'S GRTR THAN 31%

{48%} YES CSF SAT Page 1 of 1 KEY

8/29/2007 08:33 KEY2 UNIT FNP-2-CSF-0.4 INTEGRITY Revision 12 RCS PRESSURE (PSIG) 2560 APPLICANT IS ONLY REQUIRED TO 2200 A

ANNOTATE THE CSF OR IT I M THAT THE CSF IS SAT L 0

235 270 285 315 COLD LEG TEMPERATURE (°F) GO TO FRP-P.1 ALL RCS PRESS -- NO CL TEMP (IN GO TO LAST 60 MIN) FRP-P.1 POINTS TO RIGHT OF YES LIMIT A ALL RCS CL NO TEMPS IN GO TO LAST 60 MIN FRP-P.2 GRTR THAN 285° F YES ALL RCS CL NO TEMPS IN LAST 60 MIN GRTR THAN 315° F YES CSF TEMP DECR NO SAT IN ALL CL IN LAST 60 MIN LESS THAN 100° F YES GO TO FRP-P.1 ALL RCS CL NO TEMPS GRTR THAN 285° F YES NO RCS PRESS LESS THAN GO TO 450 PSIG FRP-P.2 YES ALL RCS NO TEMPS GRTR THAN CSF 325° F SAT YES CSF SAT Page 1 of 2 KEY

8/29/2007 08:33 KEY2 UNIT FNP-2-CSF-0.4 INTEGRITY Revision 12 APPLICANT IS ONLY REQUIRED TO ANNOTATE THE CSF OR THAT THE CSF IS SAT INTEGRITY RCS PRESSURE - TEMPERATURE CRITERIA 3000 2560 2500 A IT I M 2200 L 2000 RCS WIDE RANGE PRESSURE A

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Page 2 of 2 KEY

8/29/2007 08:33 FNP-2-CSF-0.5 KEY2 UNIT CONTAINMENT Revision 12 GO TO FRP-Z.1 CTMT NO GO TO PRESS FRP-Z.1 LESS THAN 54 YES At LEAST ONE NO PSIG CTMT SPRAY PUMP RUNNING (FLOW>1000 GPM) YES GO TO FRP-Z.2 CTMT NO SUMP LVL LESS THAN 7.6 YES CTMT FT.

NO PRESS LESS THAN 27 YES GO TO PSIG FRP-Z.1 GO TO FRP-Z.2 APPLICANT IS ONLY REQUIRED TO ANNOTATE THE CSF OR CTMT NO SUMP LVL THAT THE CSF IS SAT LESS THAN 7.6 YES FT.

GO TO FRP-Z.3 BOTH NO CTMT RAD LESS THAN 2 R/ YES hr.

CSF SAT Page 1 of 1 KEY

8/29/2007 08:33 UNITKEY2 FNP-2-CSF-0.6 INVENTORY Revision 12 APPLICANT IS ONLY REQUIRED TO ANNOTATE THE CSF OR THAT THE CSF IS SAT GO TO FRP-I.3 ALL NO UPPER HEAD AND PLENUM LVLS EQUAL 100% YES GO TO FRP-I.1 NO PRZR LVL LESS THAN 92%

YES GO TO FRP-I.2 NO PRZR LVL GRTR THAN 15%

YES GO TO FRP-I.3 ALL NO UPPER HEAD AND PLENUM LVLS EQUAL 100% YES CSF SAT Page 1 of 1 KEY

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UNIT 2 8/29/2007 08:33 FNP-2-CSF-0.1 SUBCRITICALITY Revision 12 GO TO FRP-S.1 GO TO FRP-S.1 NO POWER RNG LESS THAN GO TO 5% FRP-S.2 YES BOTH INT RNG SUR NO NO MORE BOTH INT NEGATIVE RNG SUR THAN -0.2 YES ZERO OR DPM NEGATIVE YES CSF SAT NO BOTH SOURCE RNG ENERGIZED YES GO TO FRP-S.2 BOTH NO SOURCE RNG SUR ZERO OR NEGATIVE YES CSF SAT Page 1 of 1

8/29/2007 08:33 UNIT 2 FNP-2-CSF-0.2 CORE COOLING Revision 12 GO TO FRP-C.1 GO TO FRP-C.2 FIFTH HOTTEST NO CORE EXIT TC LESS FIFTH NO THAN YES HOTTEST 1200 F CORE EXIT TC LESS THAN 700° YES RCS SUBCOOLING NO GO TO FROM CORE FRP-C.3 q EXIT TC'S GRTR THAN YES 16° F {45° F}

CSF SAT Page 1 of 1

8/29/2007 08:33 UNIT 2 FNP-2-CSF-0.3 HEAT SINK Revision 12 GO TO FRP-H.1 TOTAL AFW NO FLOW TO ALL SG'S GRTR THAN 395 GPM YES GO TO FRP-H.2 NAR RNG LVL IN AT NO PRESS IN NO LEAST ONE ALL SG'S SG GRTR LESS THAN THAN 31% YES 1129 PSIG YES

{48%}

GO TO FRP-H.3 NAR RNG NO LVL IN ALL SG'S LESS THAN 82% YES GO TO FRP-H.4 PRESS IN NO ALL SG'S LESS THAN 1075 PSIG YES GO TO FRP-H.5 NAR RNG NO LVL IN ALL SG'S GRTR THAN 31%

{48%} YES CSF SAT Page 1 of 1

8/29/2007 08:33 UNIT 2 FNP-2-CSF-0.4 INTEGRITY Revision 12 RCS PRESSURE (PSIG) 2560 2200 A

IT I M L

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8/29/2007 08:33 UNIT 2 FNP-2-CSF-0.4 INTEGRITY Revision 12 INTEGRITY RCS PRESSURE - TEMPERATURE CRITERIA 3000 2560 2500 A IT I M 2200 L 2000 RCS WIDE RANGE PRESSURE A

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Page 2 of 2

8/29/2007 08:33 FNP-2-CSF-0.5 UNIT CONTAINMENT 2 Revision 12 GO TO FRP-Z.1 CTMT NO GO TO PRESS FRP-Z.1 LESS THAN 54 YES At LEAST ONE NO PSIG CTMT SPRAY PUMP RUNNING (FLOW>1000 GPM) YES GO TO FRP-Z.2 CTMT NO SUMP LVL LESS THAN 7.6 YES CTMT FT.

NO PRESS LESS THAN 27 YES GO TO PSIG FRP-Z.1 GO TO FRP-Z.2 CTMT NO SUMP LVL LESS THAN 7.6 YES FT.

GO TO FRP-Z.3 BOTH NO CTMT RAD LESS THAN 2 R/ YES hr.

CSF SAT Page 1 of 1

8/29/2007 08:33 UNIT 2 FNP-2-CSF-0.6 INVENTORY Revision 12 GO TO FRP-I.3 ALL NO UPPER HEAD AND PLENUM LVLS EQUAL 100% YES GO TO FRP-I.1 NO PRZR LVL LESS THAN 92%

YES GO TO FRP-I.2 NO PRZR LVL GRTR THAN 15%

YES GO TO FRP-I.3 ALL NO UPPER HEAD AND PLENUM LVLS EQUAL 100% YES CSF SAT Page 1 of 1

FNP ILT-38 ADMIN Page 1 of 6 A.1.b. RO TITLE: Determine maximum RHR flowrate and time to saturation for a loss of RHR event.

EVALUATION LOCATION: SIMULATOR CONTROL ROOM X CLASSROOM PROJECTED TIME: 20 MIN SIMULATOR IC NUMBER: N/A ALTERNATE PATH TIME CRITICAL PRA JPM DIRECTIONS:

1. Initiation of task may be in group setting, evaluation performed individually upon completion.

2. Requiring the examinee to acquire the required materials may or may not be included as part of the JPM.

TASK STANDARD: Upon successful completion of this JPM, the examinee will:

Correctly assess and determine the maximum RHR flowrate for the current RCS level.

Correctly assess and determine the time to core boiling for the current core conditions.

Examinee:

Overall JPM Performance: Satisfactory Unsatisfactory Evaluator Comments (attach additional sheets if necessary)

EXAMINER:

Developer S. Jackson Date: 4/2/15 NRC Approval SEE NUREG 1021 FORM ES-301-3

FNP ILT-38 ADMIN A.1.b RO Page 2 of 6 CONDITIONS When I tell you to begin, you are to DETERMINE MAXIMUM RHR FLOWRATE AND TIME TO SATURATION FOR A LOSS OF RHR EVENT. The conditions under which this task is to be performed are:

a. The Unit 1 Reactor has been shutdown for 350 hours0.00405 days 0.0972 hours 5.787037e-4 weeks 1.33175e-4 months .

b. Refueling is complete, with 53 new fuel assemblies loaded into the core.

c. An RCS leak had occurred, but it has now been isolated.

d. 1A RHR pump is the only RHR pump running.

e. The 1A RHR pump started cavitating and RHR flow has been lowered to 1300 gpm to stop the cavitation per FNP-1-AOP-12.0, Residual Heat Removal Malfunction.

f. Current RCS level is 122 8.5 and stable.

g. Current RCS temperature is 116°F.

h. A current Shutdown Safety Assessment is not available.

Your task is to perform the following per AOP-12.0:

1) Determine the maximum allowable RHR flowrate.

2) Determine the time to core saturation for a loss of RHR.

INITIATING CUE: IF you have no questions, you may begin.

EVALUATION CHECKLIST RESULTS:

ELEMENTS: STANDARDS: (CIRCLE)

START TIME

1. Evaluate Figure 1, RCS HOT LEG LEVEL vs 1) Step 7 of AOP-12.0, Maintain S / U RHR INTAKE FLOW To Minimize Vortexing to RCS level to within the determine maximum allowable RHR flowrate. Acceptable Operating Region of Figure 1, RCS HOT LEG LEVEL vs RHR INTAKE FLOW To Minimize Vortexing for the existing RHR flow.

RCS level is 122 8.5.

Determines that maximum RHR flow is < 1750 gpm.

Allowable tolerance:

< 1600 -1800 gpm.

FNP ILT-38 ADMIN A.1.b RO Page 3 of 6 EVALUATION CHECKLIST RESULTS:

ELEMENTS: STANDARDS: (CIRCLE)

2. Determine time to core saturation, determine 2) ATTACHMENT 3, step 1.1. S / U appropriate table of ATTACHMENT 3, TABLE A or TABLE B. Determines that Attachment 3, TABLE B is required per ATTACHMENT 3, step 1.1.2, Time to saturation with one third of the spent fuel replaced with new fuel.

3. Determine time to core saturation, determine 3) ATTACHMENT 3, step 1.3. S / U appropriate table of ATTACHMENT 3 based on initial RCS temperature : Determines that page from Table for 100°F Attachment 3, TABLE B for Table for 120°F ASSUMED INITIAL Table for 140°F TEMPERATURE = 120°F is required.

4. Determine time to core saturation, determine 4) ATTACHMENT 3, step 1.2. S / U appropriate column of ATTACHMENT 3, TABLE B , ASSUMED INITIAL Determines that page from TEMPERATURE = 120°F : Attachment 3, TABLE B for ASSUMED INITIAL Time to Saturation at midloop (mins) TEMPERATURE = 120°F ,

Time to Saturation 3 below flange (mins) column for Time to Saturation Time to Saturation full Rx cavity (hours) at midloop (mins) is required.

FNP ILT-38 ADMIN A.1.b RO Page 4 of 6 EVALUATION CHECKLIST RESULTS:

ELEMENTS: STANDARDS: (CIRCLE)

5. Determine time to core saturation. 5) Determines that Time After S / U Shutdown (hours) is 350 hours0.00405 days 0.0972 hours 5.787037e-4 weeks 1.33175e-4 months and minutes to boiling is calculated to be 21.35 minutes.

300 hours0.00347 days 0.0833 hours 4.960317e-4 weeks 1.1415e-4 months = 20.2 minutes 400 hours0.00463 days 0.111 hours 6.613757e-4 weeks 1.522e-4 months = 22.5 minutes 20.2 + 22.5 = 42.7 42.7/2 = 21.35 minutes After rounding, 21.4 minutes is acceptable.

Allowable tolerance: 21.3 -21.4 minutes.

Since the Time After Shutdown chart only shows 300 hours0.00347 days 0.0833 hours 4.960317e-4 weeks 1.1415e-4 months and 400 hours0.00463 days 0.111 hours 6.613757e-4 weeks 1.522e-4 months , the candidate may conservatively take the 300 hours0.00347 days 0.0833 hours 4.960317e-4 weeks 1.1415e-4 months after shutdown for time to boil of 20.2 minutes or 20 minutes for rounding. This is acceptable STOP TIME Terminate when all elements of the task have been completed.

CRITICAL ELEMENTS: Critical Elements are denoted with an asterisk () before the element number.

FNP ILT-38 ADMIN A.1.b RO Page 5 of 6 GENERAL

REFERENCES:

1. FNP-1-AOP-12.0, v25

2. G2.1.25 - 3.9 / 4.2 GENERAL TOOLS AND EQUIPMENT:

1. Acquire FNP-1-AOP-12.0, v25- On Reference Disk

2. FNP-1-AOP-12.0, v25, Figure 1 if requested

3. Calculator, ruler or straight edge if requested Critical ELEMENT justification:

STEP Evaluation

1. Critical: Task completion: required to properly determine Maximum RHR flowrate.

2-5 Critical: Task completion: required to properly determine time to core saturation.

COMMENTS:

A.1.a RO HANDOUT Pg 1 of 1 CONDITIONS When I tell you to begin, you are to DETERMINE MAXIMUM RHR FLOWRATE AND TIME TO SATURATION FOR A LOSS OF RHR EVENT. The conditions under which this task is to be performed are:

a. The Unit 1 Reactor has been shutdown for 350 hours0.00405 days 0.0972 hours 5.787037e-4 weeks 1.33175e-4 months .

b. Refueling is complete, with 53 new fuel assemblies loaded into the core.

c. An RCS leak had occurred, but it has now been isolated.

d. 1A RHR pump is the only RHR pump running.

e. The 1A RHR pump started cavitating and RHR flow has been lowered to 1300 gpm to stop the cavitation per FNP-1-AOP-12.0, Residual Heat Removal Malfunction.

f. Current RCS level is 122 8.5 and stable.

g. Current RCS temperature is 116°F.

h. A current Shutdown Safety Assessment is not available.

Your task is to perform the following per AOP-12.0:

1) Determine the maximum allowable RHR flowrate.

2) Determine the time to core saturation for a loss of RHR.

AOP-12 Maximum allowable RHR flowrate Time to Core Saturation

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT KEY 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 FIGURE 1 RCS HOT LEG LEVEL vs RHR INTAKE FLOW To Minimize Vortexing RCS HOT LEG LEVEL vs RHR INTAKE FLOW To Minimize Vortexing

< 1750 gpm

+ 50 gpm Page 1 of 1 KEY

3/15/2013 00:29 FNP-1-AOP-12.0 UNITKEY 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 ATTACHMENT 3 Time to Core Saturation 1 Time to Core Saturation:

1.1 Tables A and B provide estimates of the time to core boiling following a loss RHR capability for two cases:

1.1.1 TABLE A provides a Time to Saturation as a function of time after shutdown for a full core immediately after shutdown for a refueling.

1.1.2 TABLE B provides a Time to Saturation as a function of time after shutdown for a core in which one third of the spent fuel has been replaced with new fuel.

1.2 Both cases are evaluated for conditions when RCS level is at mid loop (122'9"), at three feet below the reactor flange (126'7"), and when the reactor cavity is full.

1.3 Both cases are also evaluated for three assumed initial temperatures:

100 100F, 120 120F, and 140 140F.

1.4 These figures can be used to estimate the amount of time available for operator action to restore RHR before additional protective measures must be taken.

Page 1 of 7 KEY

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT KEY 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 ATTACHMENT 3 Time to Core Saturation TABLE BB---POWER

---POWER UPRATED UNIT TIME TO SATURATION: ONE THIRD NEW FUEL ASSUMED INITIAL TEMPERATURE=

TEMPERATURE=120 F 120

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ Time After Time to Saturation Time to Saturation Time to Saturation Saturation Shutdown (hours)

(hours) at midloop (mins) 3' below flange full Rx cavity (mins) (hours)

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 100 12.8 17.5 9.2

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 200 17.1 23.4 12.4

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ If using interpolation -

300 20.2 27.6 14.6 21.3 - 21.4 min.

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 400 22.5 May use 20 minutes 30.8 16.3 since 20.2 rounds to

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 500 25.4 20 34.8 and 0.2 minutes is 18.4

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 12 sec 600 28.3 38.7 20.5

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 700 30.5 41.7 22.1

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 800 33.0 45.2 23.9

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥º VOLUME REFERENCE TABLE

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ MIDLOOP VOLUME(FT 3 ) 945

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥ VOLUME 3FT BELOW FLANGE(FT 3 ) 348 TOTAL= 1293

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ VOLUME FULL REACTOR CAVITY(FT 3 ) 39750 TOTAL= 41043

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥º Page 6 of 7 KEY

3/15/2013 00:29 UNIT 1 FNP-1-AOP-12.0 1-02-2013 Revision 25.0 FARLEY NUCLEAR PLANT ABNORMAL OPERATING PROCEDURE FNP-1-AOP-12.0 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION S

A

² F PROCEDURE USAGE REQUIREMENTS per NMP-AP-003 SECTIONS E

¨¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ T Continuous Use ALL Y

¨¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ Reference Use R

¨¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ E Information Use L

©° A T

E D

Approved:

David L Reed (for)

Operations Manager 01/28/13 Date Issued:

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 TABLE OF CONTENTS Procedure Contains Number of Pages Body................................... 24 Figure 1............................... 1 Attachment 1........................... 9 Attachment 2........................... 4 Attachment 3........................... 7 Attachment 4........................... 1 Page 1 of 1

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 A. Purpose This procedure provides actions for response to a malfunction of the RHR system.

Actions in this procedure for restoring RHR PUMPs assume electrical power is available. During loss of electrical power conditions, FNP-1-AOP-5.0, LOSS OF A OR B TRAIN ELECTRICAL POWER, provides actions for restoration of electrical power which should be performed in addition to continuing with this procedure.

The first part of this procedure deals with the protection of any running RHR pump and isolation of any leakage. If a running train is maintained the procedure is exited. Credit may be taken for RCS Loops providing core cooling in place of a running train of RHR. The next portion deals with restoring a train of RHR while monitoring core temperatures. If a train cannot be restored actions are taken for protection of personnel, establishing containment closure, and provides alternate methods of decay heat removal while trying to restore a train of RHR. Alternate cooling methods include:

establishing a secondary heat sink if steam generators are available; feed and bleed cooling and feed and spill cooling.

The intent of feed and bleed cooling is to regain pressurizer level and allow steaming through a bleed path to provide core cooling. This requires that the RCS be in a configuration that will allow a level in the pressurizer.

The intent of feed and spill cooling is to allow spillage from the RCS and locally throttle injection flow to provide core cooling. This method is used when the reactor vessel head is blocked or RCS loop openings exist.

This procedure is applicable in modes 4, 5 and 6.

Containment closure is required to be completed within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of the initiating event unless an operable RHR pump is placed in service cooling the RCS AND the RCS temperature is below 180 F.

180 Page 1 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 B. Symptoms or Entry Conditions 1 This procedure is entered when a malfunction of the RHR system is indicated by any of the following:

1.1 Trip of any operating RHR pump 1.2 Excessive RHR system leakage 1.3 Evidence of running RHR pump cavitation 1.4 Closure of loop suction valve 1.5 High RCS or core exit T/C temperature 1.6 Procedure could be entered from various annunciator response procedures.

CF3 1A OR 1B RHR PUMP OVERLOAD TRIP CF4 1A RHR HX OUTLET FLOW LO CF5 1B RHR HX OUTLET FLOW LO CG3 1A OR 1B RHR HX CCW DISCH FLOW HI EA5 1A OR 1B RHR PUMP CAVITATION EB5 MID-LOOP CORE EXIT TEMP HI EC5 RCS LVL HI-LO Page 2 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained CAUTION CAUTION:

Containment closure is required to be completed within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of the initiating event unless an operable RHR pump is placed in service cooling the RCS AND the RCS temperature is below 180 F.

180 CAUTION CAUTION:

Filling the pressurizer to 100% will cause a loss of nozzle dams due to the head of water.

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ NOTE: RCS to RHR loop suction valves will be deenergized if RCS TAVG is less than 180 180F.

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 1 Check RHR loop suction valves - 1 Stop any RHR PUMP with closed OPEN. loop suction valve(s).

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥ 1.1 IF required, RHR PUMP 1A 1B THEN adjust charging flow to

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ maintain RCS level.

1C(1A) RCS LOOP TO 1A(1B) RHR PUMP Q1E11MOV [] 8701A 8701A

[] 8702A 8702A

[] 8701B 8701B

[] 8702B 8702B

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 1C(1A) RCS LOOP TO 1A(1B) RHR PUMP [] FU-T5 FU-T5

[] FU-G2 FU-G2 LOOP SUCTION POWER [] FV-V2 FV-V2

[] FV-V3 FV-V3 SUPPLY BREAKERS CLOSED(

CLOSED(IF IF REQUIRED)

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥º 2 IF the standby RHR train is NOT 2 IF core cooling provided by the affected AND plant conditions SGs, permit operation, THEN proceed to step 8.

THEN place the standby RHR train in service per FNP-1-SOP-7.0, RESIDUAL HEAT REMOVAL SYSTEM.

Page 3 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ NOTE: Rapid flow adjustments may cause more severe pump cavitation.

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 3 Check RHR PUMPs - NOT 3 Perform the following:

CAVITATING.

3.1 Slowly reduce RHR flow rate to The following parameters should eliminate cavitation.

be stable and within normal ranges. 3.2 IF cavitation CANNOT be

[] RHR flow rate within the eliminated, Acceptable Operating Region of THEN stop the affected RHR FIGURE 1, RCS HOT LEG LEVEL vs pump(s).

RHR INTAKE FLOW To Minimize Vortexing.

[] Discharge pressure

[] Suction pressure

[] RHR motor ammeter readings

[] No unusual pump noise 4 Check any RHR PUMP - RUNNING 4 Proceed to step 13.

5 Verify RHR flow > 3000 gpm. 5 Refer to Technical Specifications 3.9.4 and 3.9.5 1A(1B) for applicability.

RHR HDR FLOW

[] FI 605A

[] FI 605B Page 4 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained CAUTION CAUTION: : Indicated RCS level will rise approximately 1 ft for every 0.5 psi rise in RCS pressure if the indication is not pressure compensated.

CAUTION CAUTION: : Only borated water should be added to the RCS to maintain adequate shutdown margin.

6 Check RCS level ADEQUATE 6.1 Compare any available level indications.

[] LT 2965A&B/level hose

[] LI-2384 1B LOOP RCS NR LVL

[] LI-2385 1C LOOP RCS NR LVL

[] Temporary remote level indicator off of a RCS FT on A or C loop 6.2 Check RCS level within the 6.2 Raise RCS level.

Acceptable Operating Region of FIGURE 1, RCS HOT LEG LEVEL vs 6.2.1 Notify personnel in RHR INTAKE FLOW To Minimize containment that RCS level Vortexing. will be raised.

6.2.2 Align Technical Requirements Manual boration flow path.

6.2.3 Raise RCS level to within the Acceptable Operating Region of FIGURE 1, RCS HOT LEG LEVEL vs RHR INTAKE FLOW To Minimize Vortexing for the existing RHR flow.

Page 5 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained 7 Maintain RCS level within the 7 Verify RHR PUMP(s) stopped AND following limits: proceed to step 13.

[] Maintain RCS level to within the Acceptable Operating Region of FIGURE 1, RCS HOT LEG LEVEL vs RHR INTAKE FLOW To Minimize Vortexing for the existing RHR flow.

[] Maintain RCS level less than 123 ft 4 in if personnel are in the channel heads without nozzle dams installed.

[] Maintain RCS level less than 123 ft 9 in if primary manways are removed without nozzle dams installed.

[] Maintain RCS level less than 123 ft 9 in if seal injection is not established and RCPs are not backseated.

[] Maintain RCS level less than 124 ft if safety injection check valves are disassembled.

Page 6 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained CAUTION CAUTION:: IF the leaking RHR train can NOT be identified, THEN both trains should be assumed leaking.

8 Check RHR system - INTACT 8 Isolate RHR leakage.

[] Stable RCS level. 8.1 Isolate affected RHR train(s)

[] No unexpected rise in from RCS.

containment sump level.

[] No RHR HX room sump level 8.1.1 Stop affected RHR pump(s).

rising.

[] No RHR pump room sump level 8.1.2 Verify closed affected RHR rising. train valves.

[] No waste gas processing room sump level rising >>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥

[] No rising area radiation Affected RHR Train A B monitor ¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥

[] No unexplained rise in PRT 1C(1A) RCS LOOP level or temperature. TO 1A(1B) RHR PUMP [] 8701A 8701A[] 8702A 8702A Q1E11MOV [] 8701B 8701B[] 8702B 8702B

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 1C(1A) RCS LOOP TO 1A(1B) RHR PUMP [] FU-T5 FU-T5[] FU-G2 FU-G2 LOOP SUCTION POWER [] FV-V2 FV-V2[] FV-V3 FV-V3 SUPPLY BREAKERS CLOSED

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 1A(1B) RHR HX TO RCS RCS COLD LEGS ISO [] 8888A 8888A[] 8888B 8888B Q1E11MOV

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 1A(1B) RHR TO RCS HOT LEGS XCON [] 8887A 8887A[] 8887B 8887B Q1E11MOV

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥º 8.2 Isolate source of any RHR/RCS leakage.

9 Check core cooling provided by 9 Proceed to step 13.

RHR or SGs.

10 Check RCS temperature stable or 10 Proceed to step 13.

lowering.

Page 7 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained 11 Verify low pressure letdown aligned to operating RHR train:

11.1 Determine RHR train that low pressure letdown is aligned.

11.2 IF required, THEN align low pressure letdown to the operating RHR train using FNP-1-SOP-7.0, RESIDUAL HEAT REMOVAL SYSTEM 12 Go to procedure and step in effect.

CAUTION CAUTION:: Containment closure is required to be completed within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of the initiating event unless an operable RHR pump is placed in service cooling the RCS and the RCS temperature is below 180 F.

13 Begin establishing containment 13 IF in mode 6, closure using FNP-1-STP-18.4, THEN refer to Technical CONTAINMENT MID-LOOP AND AND/OR

/OR Specifications 3.9.4 and 3.9.5 REFUELING INTEGRITY for other containment isolation VERIFICATION AND CONTAINMENT requirements.

CLOSURE.

Page 8 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained 14 Monitor time to core saturation.

14.1 Check time to core saturation 14.1 Determine time to core from the current Shutdown saturation:

Safety Assessment.

Use ATTACHMENT 3, Time to Core Saturation OR Monitor any available core exit thermocouples for a heat up trend.

14.2 Monitor RCS temperature trend during the performance of this procedure.

14.2.1 Check vacuum degas system 14.2.1 IF vacuum refill in NOT in service. progress maintaining a vacuum on the RCS, THEN break vacuum on the RCS using FNP-0-SOP-74.0, OPERATION OF THE RCVRS SKID. (155' CTMT)

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ NOTE: Step 14.2.2 is a continuing action step.

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 14.2.2 IF RCS level decreases to less than 121 ft 11 in AND core exit T/Cs are greater than 200 200F, THEN proceed to step 21.

14.3 IF applicable, THEN review the current shutdown safety assessment of FNP-0-UOP-4.0 for applicability of other outage Abnormal Operating Procedures.

15 Begin venting any RHR trains which have experienced evidence of cavitation using ATTACHMENT 1, RHR PUMP VENTING.

Page 9 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained 16 Suspend any boron dilution in progress. (IN 91-54) 17 IF the charging system is still in service, THEN align the RWST to the running Charging pump.

>>¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥ Operable Operable CHG PUMP PUMP 1A 1B(A TRN)

TRN)1B(B TRN)

TRN) 1C RWST TO CHG PUMP PUMP Q1E21LCV Q1E21LCV [] 115B 115B[] 115B [] 115D [] 115D 115D

¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥º CAUTION CAUTION: : The RCS tygon level hose and LT 2965A&B utilize the same level tap.

These are not independent indications.

18 Check for two independent RCS level indications.

18.1 Compare available level indications.

[] LT 2965A&B/level hose

[] LI-2384 1B LOOP RCS NR LVL

[] LI-2385 1C LOOP RCS NR LVL

[] Temporary remote level indicator off of a RCS FT on A or C loop 18.2 Check RCS level greater than 18.2 Raise RCS level.

123 ft 3 in.

18.2.1 Notify personnel in containment that RCS level will be raised.

18.2.2 Align Technical Requirements Manual boration flow path.

18.2.3 Raise RCS level to greater than 123 ft 3 in.

Step 18 continued on next page.

Page 10 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained 18.3 Maintain RCS level within the following limits:

[] Maintain RCS level less than 123 ft 4 in if personnel are in the channel heads without nozzle dams installed.

[] Maintain RCS level less than 123 ft 9 in if primary manways are removed without nozzle dams installed.

[] Maintain RCS level less than 123 ft 9 in if seal injection is not established and RCPs are not backseated.

[] Maintain RCS level less than 124 ft if safety injection check valves are disassembled.

CAUTION CAUTION:: The standby RHR train may be lost due to cavitation if it is placed in service without adequate RCS level.

CAUTION CAUTION:: Starting an RHR PUMP may cause RCS level to fall due to shrink or void collapse.

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ NOTE: The term "standby RHR train" refers to the train most readily available to restore RHR cooling.

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 19 WHEN RCS level greater than 19 IF unable to establish at least 123 ft 3 in, one train of RHR, THEN place standby RHR train in THEN proceed to step 21 while service. continuing efforts to restore at least one train of RHR.

19.1 Verify CCW PUMP in standby train - STARTED.

Step 19 continued on next page.

Page 11 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained 19.2 Verify CCW - ALIGNED TO STANDBY RHR HEAT EXCHANGER.

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥ Standby RHR Train Train A B CCW TO 1A(1B) RHR HX Q1P17MOV [] 3185A 3185A[] 3185B 3185B

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥º 19.3 Verify the following conditions satisfied.

19.3.1 RWST TO 1A(1B) RHR PUMP Q1E11MOV8809A and B closed.

19.3.2 1A(1B) RHR HX TO CHG PUMP SUCT Q1E11MOV8706A and B closed.

19.3.3 RCS pressure less than 402.5 psig.

19.3.4 PRZR vapor space temperature less than 475 475F.

Step 19 continued on next page.

Page 12 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ NOTE: RCS to RHR loop suction valves will be deenergized if RCS TAVG is less than 180 180F.

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 19.4 Verify standby RHR train loop suction valves - OPEN.

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥ Standby RHR Train A B 1C(1A) RCS LOOP to 1A(1B) RHR PUMP Q1E11MOV [] 8701A 8701A[] 8702A 8702A

[] 8701B 8701B[] 8702B 8702B

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 1C(1A) RCS LOOP TO 1A(1B) RHR PUMP [] FU-T5 FU-T5[] FU-G2 FU-G2 LOOP SUCTION POWER [] FV-V2 FV-V2[] FV-V3 FV-V3 SUPPLY BREAKERS CLOSE(

CLOSE(IF IF REQUIRED)

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥º Step 19 continued on next page.

Page 13 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained 19.5 Check standby RHR train discharge flow path available.

19.5.1 Verify standby RHR train -

ALIGNED TO RCS COLD LEGS.

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥ RHR Train A B

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ RHR HX TO RCS COLD LEGS ISO [] 8888A8888A[] 8888B 8888B Q1E11MOV Q1E11MOV¥¥ OPEN

¥¥OPEN

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥º

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ NOTE: The RHR HX bypass valves will fail closed and the RHR HX discharge valves will fail open upon loss of air to the AUX BLDG.

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 19.5.2 Verify standby RHR train HX BYP FLOW - ADJUSTED TO 15%

OPEN.

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥£¥¥¥¥¥¥¥ Standby RHR Train Train A B 1A(1B) RHR HX BYP FLOW FK [] 605A 605A [] 605B 605B

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥º 19.5.3 Verify standby RHR train HX 19.5.3 Close standby RHR train -

discharge valve - ADJUSTED TO RCS COLD LEGS ISO CLOSED. valves. (121 ft, AUX BLDG piping penetration room)

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥£¥¥¥¥¥¥¥ Standby RHR Train A B >>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥ 1A(1B) RHR HX TO RCSRCS RHR Train A B DISCH VLV ¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ HIK [] 603A 603A [] 603B 603B RHR HX TO RCS

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥º COLD LEGS ISO [] 8888A 8888A

[] 8888B 8888B Q1E11MOV

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥º Step 19 continued on next page.

Page 14 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained 19.6 Verify standby RHR train pump miniflow valve - OPEN.

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥£¥¥¥¥¥¥¥ Standby RHR Train Train A B 1A(1B) RHR PUMP MINIFLOW Q1E11FCV [] 602A 602A[] 602B 602B

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥º 19.7 Start RHR PUMP in standby train.

19.8 Control standby RHR train RHR 19.8 IF unable to control standby HX bypass valve to obtain RHR train flow with RHR HX desired flow. bypass valve, THEN locally control RHR HX TO

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥£¥¥¥¥¥¥¥ RCS COLD LEGS ISO valves.

Standby RHR Train A B (121 ft, AUX BLDG piping 1A(1B) RHR HX penetration room)

BYP FLOW FK [] 605A 605A[] 605B 605B >>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥º RHR Train A B

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ RHR HX TO RCS COLD LEGS ISO [] 8888A 8888A[] 8888B 8888B Q1E11MOV

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥º 20 IF RHR restored, 20 Continue efforts to restore at THEN go to procedure and step least one RHR train while in effect. continuing with this procedure.

Page 15 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained 21 Initiate protective measures for personnel in containment.

21.1 Evacuate all nonessential personnel from containment.

21.2 Ensure HP monitors essential personnel remaining in containment for the following:

[] Changing containment conditions which could require evacuation of all personnel.

[] Use of extra protective clothing if needed.

[] Use of respirators if needed.

21.3 Monitor containment radiation monitors for changing conditions.

[] R-2 CTMT 155 ft

[] R-7 SEAL TABLE

[] R-27A CTMT HIGH RANGE (BOP)

[] R-27B CTMT HIGH RANGE (BOP)

Page 16 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained 22 Start all available containment coolers 22.1 Determine which containment coolers have Service Water aligned.

[] Q1E12H001A

[] Q1E12H001B

[] Q1E12H001C

[] Q1E12H001D 22.2 Start Containment coolers with 22.2 Start Containment coolers with service water aligned and with service water aligned and with power available in FAST speed. power available in SLOW speed.

[] 1A CTMT CLR FAN FAST SPEED [] 1A CTMT CLR FAN SLOW SPEED Q1E12H001A to START Q1E12H001A to START (BKR EA10) (BKR ED15)

[] 1B CTMT CLR FAN FAST SPEED [] 1B CTMT CLR FAN SLOW SPEED Q1E12H001B to START Q1E12H001B to START (BKR EB05) (BKR ED16)

[] 1C CTMT CLR FAN FAST SPEED [] 1C CTMT CLR FAN SLOW SPEED Q1E12H001C to START Q1E12H001C to START (BKR EB06) (BKR EE08)

[] 1D CTMT CLR FAN FAST SPEED [] 1D CTMT CLR FAN SLOW SPEED Q1E12H001C to START Q1E12H001D to START (BKR EC12) (BKR EE16) 22.3 Check discharge damper open on 22.3 STOP any containment cooler any started containment whose discharge damper fails cooler. to indicate OPEN.

[] CTMT CLR 1A DISCH 3186A indicates OPEN.

[] CTMT CLR 1B DISCH 3186B indicates OPEN.

[] CTMT CLR 1C DISCH 3186C indicates OPEN.

[] CTMT CLR 1D DISCH 3186d indicates OPEN.

23 IF not previously started, THEN begin venting any RHR train(s) which have experienced evidence of cavitation using ATTACHMENT 1, RHR PUMP VENTING.

Page 17 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ NOTE: Steps 24 and 25 should be performed in conjunction with the remainder of this procedure.

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 24 Check SGs available. 24 Proceed to step 26.

Check SG primary nozzle dams

- REMOVED.

Check SG primary manways -

INSTALLED.

Check SG secondary handhole covers - INSTALLED.

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ NOTE: Establishing a secondary heat sink will reduce RCS heat up and pressurization rate to provide more time for recovery actions.

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 25 Verify secondary heat sink established.

25.1 Maintain wide range level in all available SGs greater than 75% using FNP-1-SOP-22.0, AUXILIARY FEEDWATER SYSTEM.

25.2 IF SG steam space intact, THEN open atmospheric relief valves to prevent SG pressurization.

1A(1B,1C) MS ATMOS REL VLV

[] PC 3371A adjusted

[] PC 3371B adjusted

[] PC 3371C adjusted 25.3 IF SGBD system available, AND AFW system available, THEN establish blowdown from available SGs using FNP-1-SOP-16.3, STEAM GENERATOR FILLING AND DRAINING.

Page 18 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained 26 Evaluate event classification and notification requirements using NMP-EP-110, EMERGENCY CLASSIFICATION DETERMINATION AND INITIAL ACTION, NMP-EP-111, EMERGENCY NOTIFICATIONS, and FNP-0-EIP-8, NON-EMERGENCY NOTIFICATIONS.

27 Verify RCS isolated.

27.1 Close RHR TO LTDN HX HIK 142.

27.2 Close LTDN LINE ISO Q1E21LCV459 and Q1E21LCV460.

27.3 Close EXC LTDN LINE ISO VLV Q1E21HV8153 and Q1E21HV8154.

27.4 Dispatch personnel to isolate all known RCS drain paths.

27.5 Dispatch personnel to isolate any RCS leakage.

28 Dispatch personnel to close hot leg recirculation valve disconnects. (139 ft, AUX BLDG rad-side)

CHG PUMP TO RCS HOT LEGS Q1E21MOV8886(8884)

[] Q1R18B029-A (Master Z key)

[] Q1R18B033-B (Master Z key) 29 Check core cooling.

29.1 Check RCS level LESS than 29.1 Return to step 1.0.

121 ft 11 in AND core exit T/Cs GREATER than 200 F.

200 Page 19 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ NOTE: Maintaining RCS level is the primary concern. RCS makeup should be restored as soon as possible through any available makeup path.

RCS makeup flow requirements can exceed 90 gpm due to boil off if an adequate hot leg vent is established.

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 30 WHEN RHR flow restored, THEN proceed to step 40.

31 Check any CHG PUMP - AVAILABLE. 31 Establish RWST gravity drain using ATTACHMENT 2, RWST TO RCS GRAVITY FEED.

31.1 WHEN gravity drain established, THEN proceed to step 37.

32 Verify operable CHG PUMP miniflow valves - OPEN.

1A(1B,1C) CHG PUMP MINIFLOW ISO

[] Q1E21MOV8109A

[] Q1E21MOV8109B

[] Q1E21MOV8109C 33 Verify CHG PUMP miniflow isolation valve - OPEN.

CHG PUMP MINIFLOW ISO

[] Q1E21MOV8106 34 Verify RWST to CHG PUMP valve for operable CHG PUMP - OPEN.

>>¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥ Operable Operable CHG PUMP PUMP 1A 1B(A TRN)

TRN)1B(B TRN)

TRN) 1C RWST TO CHG PUMP PUMP Q1E21LCV Q1E21LCV[] 115B 115B

[] 115B [] 115D [] 115D 115D

¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥º 35 Verify operable CHG PUMP -

STARTED.

Page 20 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained 36 Verify required injection path isolation valve - OPEN.

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ Q1E21MOV8803A HHSI TO RCS CL ISO ISO

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ Q1E21MOV8803B HHSI TO RCS CL ISO ISO

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ Q1E21MOV8885 CHG PUMP RECIRC TOTO RCS COLD LEGS

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ Q1E21MOV8884 CHG PUMP RECIRC TOTO RCS HOT LEGS

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ Q1E21MOV8886 CHG PUMP RECIRC TOTO RCS HOT LEGS

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥º Page 21 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained CAUTION CAUTION:: Reactor vessel level may be much lower than indicated if no hot leg vent path is available.

CAUTION CAUTION:: RCS pressurization may cause SG nozzle dam failure. This will cause a rapid loss of RCS inventory and the creation of a RCS spill pathway.

37 IF RCS configuration will allow 37 IF RCS configuration will NOT a level in the pressurizer, allow a level in the THEN establish feed and bleed pressurizer, cooling. THEN establish feed and spill cooling as follows.

37.1 Verify RCS bleed path available as follows. a) Locally control required injection path isolation Verify all pressurizer valve to maintain core exit safety valves - REMOVED. T/Cs less than 200 F.

200 OR b) Proceed to step 38.

Verify pressurizer manway -

REMOVED.

OR Verify both PRZR PORVs and PRZR PORV ISOs - OPEN.

Step 37 continued on next page.

Page 22 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained 37.2 WHEN pressurizer level greater 37.2 Locally control required than 7% (136 ft 9 in), injection path isolation valve THEN establish normal to maintain pressurizer level charging. greater than 7% (136 ft 9 in).

37.2.1 Verify charging pump miniflow valves - OPEN.

1A(1B,1C) CHG PUMP MINIFLOW ISO

[] Q1E21MOV8109A

[] Q1E21MOV8109B

[] Q1E21MOV8109C CHG PUMP MINIFLOW ISO

[] Q1E21MOV8106 37.2.2 Manually close charging flow control valve.

CHG FLOW

[] FK 122 37.2.3 Verify charging pump discharge flow path -

ALIGNED.

CHG PUMP DISCH HDR ISO

[] Q1E21MOV8132A open

[] Q1E21MOV8132B open

[] Q1E21MOV8133A open

[] Q1E21MOV8133B open CHG PUMPS TO REGENERATIVE HX

[] Q1E21MOV8107 open

[] Q1E21MOV8108 open Step 37 continued on next page.

Page 23 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained 37.2.4 Verify only one charging line valve - OPEN.

RCS NORMAL CHG LINE

[] Q1E21HV8146 RCS ALT CHG LINE

[] Q1E21HV8147 37.2.5 Maintain pressurizer level greater than 7% (136 ft 9 in).

CHG FLOW

[] FK 122 adjusted 37.2.6 Close required injection path isolation valve.

38 Maintain RCS feed and bleed 38 Maintain RCS feed and spill cooling until at least one RHR cooling until at least one RHR train restored. train restored.

39 Check RHR - RESTORED. 39 Return to step 37.

40 Maintain RCS at desired level.

41 Begin RCS cooldown using FNP-1-SOP-7.0, RESIDUAL HEAT REMOVAL SYSTEM.

42 WHEN core exit T/Cs stable at desired temperature, THEN go to procedure and step in effect.

-END-Page 24 of 24

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 FIGURE 1 RCS HOT LEG LEVEL vs RHR INTAKE FLOW To Minimize Vortexing RCS HOT LEG LEVEL vs RHR INTAKE FLOW To Minimize Vortexing Page 1 of 1

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained ATTACHMENT 1 RHR PUMP VENTING CAUTION CAUTION:: Installation of vent rigs must not delay venting operations if only the air bound train is available for service. Contamination should be minimized but contamination control must not interfere with venting.

1 IF both trains of RHR are air bound OR unavailable, THEN proceed to step 4

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ NOTE: Vent rigs may be routed to either floor drains or poly bottles.

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 2 IF 1A RHR PUMP AIR bound, THEN install vent rigs on A train RHR system.

2.1 Install vent rig at 1A RHR PUMP SEAL COOLER OUTLET VENT ISO Q1E11V080C. (83 ft, AUX BLDG 1A RHR PUMP room) 2.2 Install vent rig at 1A RHR HX OUTLET VENT ISO Q1E11V068C.

(83 ft, AUX BLDG RHR HX room) 2.3 Install vent rig at 1C RCS LOOP TO 1A RHR PUMP HDR VENT ISO Q1E11V064C. (100 ft, AUX BLDG piping penetration room, PEN #16) 2.4 Install vent rig at 1A RHR HX TO RCS COLD LEGS HDR VENT ISO Q1E11V055B. (121 ft, AUX BLDG piping penetration room, PEN

15)

Page 1 of 9

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained ATTACHMENT 1 3 IF 1B RHR PUMP air bound, THEN install vent rigs on B train RHR system.

3.1 Install vent rig at 1B RHR PUMP SEAL COOLER OUTLET VENT ISO Q1E11V080D. (83 ft, AUX BLDG 1B RHR PUMP room) 3.2 Install vent rig at 1B RHR HX OUTLET VENT ISO Q1E11V068D.

(83 ft, AUX BLDG RHR HX room) 3.3 Install vent rig at 1A RCS LOOP TO 1B RHR PUMP HDR VENT ISO Q1E11V064D. (100 ft, AUX BLDG piping penetration room, PEN #18) 3.4 Install vent rig at 1B RHR HX TO RCS COLD LEGS HDR VENT ISO Q1E11V058B. (121 ft, AUX BLDG piping penetration room, PEN

17)

Page 2 of 9

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained ATTACHMENT 1 CAUTION CAUTION:: Using the RCS as a makeup source for RHR system inventory lost during venting (per RNO), will result in a loss of RCS inventory and therefore a lowering of RCS level. This could jeopardize the other train of RHR, if it is in operation.

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ NOTE: The intent of aligning the RWST to the air bound train when the RCS loop suctions are open is to make up for inventory lost when venting, however, this action also initiates gravity flow from the RWST.

Close coordination will be required between the control room operator monitoring RCS level and the operator controlling the RWST supply locally.

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 4 Align a source of make up to the air bound train.

4.1 Locally, throttle open RWST 4.1 Open RCS supply to air bound supply to air bound train train.

until it is just off the closed seat. (83 ft el, RHR >>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥£¥¥¥¥¥¥¥ PUMP Rm) Air Bound Train A B 1C(1A) RCS LOOP

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥£¥¥¥¥¥¥¥ TO 1A(1B) RHR PUMP PUMP Air Bound Train Train A B Q1E11MOV []8701A

[]8701A

[]8702A

[]8702A RWST TO []8701B

[]8701B

[]8702B

[]8702B 1A(1B) RHR PUMP PUMP

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥º Q1E11MOV []8809A

[]8809A

[]8809B

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥º Page 3 of 9

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained ATTACHMENT 1 5 IF 1A RHR PUMP air bound, THEN perform the following.

5.1 Open 1A RHR PUMP SEAL COOLER OUTLET VENTS Q1E11V080C and Q1E11V080A. (83 ft, AUX BLDG 1A RHR PUMP room) 5.2 WHEN air free water is seen, THEN close 1A RHR PUMP SEAL COOLER OUTLET VENTS Q1E11V080C and Q1E11V080A. (83 ft, AUX BLDG 1A RHR PUMP room) 5.3 Open 1A RHR HX OUTLET VENTS Q1E11V068C and Q1E11V068A.

(83 ft, AUX BLDG RHR HX room) 5.4 WHEN air free water is seen, THEN close 1A RHR HX OUTLET VENTS Q1E11V068C and Q1E11V068A. (83 ft, AUX BLDG RHR HX room) 5.5 Open 1C RCS LOOP TO 1A RHR PUMP HDR VENTS Q1E11V064C and Q1E11V064A. (100 ft, AUX BLDG piping penetration room, PEN

16) 5.6 WHEN air free water is seen, THEN close 1C RCS LOOP TO 1A RHR PUMP HDR VENTS Q1E11V064C and Q1E11V064A. (100 ft, AUX BLDG piping penetration room) 5.7 Open 1A RHR HX TO RCS COLD LEGS HDR VENTS Q1E11V055B and Q1E11VO55A. (121 ft, AUX BLDG piping penetration room, PEN

15) 5.8 WHEN air free water is seen, THEN close 1A RHR HX TO RCS COLD LEGS HDR VENTS Q1E11V055B and Q1E11VO55A. (121 ft, AUX BLDG piping penetration room)

Page 4 of 9

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained ATTACHMENT 1 6 IF 1B RHR PUMP air bound, THEN perform the following.

6.1 Open 1B RHR PUMP SEAL COOLER OUTLET VENTS Q1E11V080D and Q1E11V080B. (83 ft, AUX BLDG 1B RHR PUMP room) 6.2 WHEN air free water is seen, THEN close 1B RHR PUMP SEAL COOLER OUTLET VENTS Q1E11V080D and Q1E11V080B. (83 ft, AUX BLDG 1B RHR PUMP room) 6.3 Open 1B RHR HX OUTLET VENTS Q1E11V068D and Q1E11V068B.

(83 ft, AUX BLDG RHR HX room) 6.4 WHEN air free water is seen, THEN close 1B RHR HX OUTLET VENTS Q1E11V068D and Q1E11V068B. (83 ft, AUX BLDG RHR HX room) 6.5 Open 1A RCS LOOP TO 1B RHR PUMP HDR VENTS Q1E11V064D and Q1E11V064B. (100 ft, AUX BLDG piping penetration room, PEN

18) 6.6 WHEN air free water is seen, THEN close 1A RCS LOOP TO 1B RHR PUMP HDR VENTS Q1E11V064D and Q1E11V064B. (100 ft, AUX BLDG piping penetration room) 6.7 Open 1B RHR HX TO RCS COLD LEGS HDR VENTS Q1E11V058B and Q1E11VO58A. (121 ft, AUX BLDG piping penetration room, PEN

17) 6.8 WHEN air free water is seen, THEN close 1B RHR HX TO RCS COLD LEGS HDR VENTS Q1E11V058B and Q1E11VO58A. (121 ft, AUX BLDG piping penetration room)

Page 5 of 9

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained ATTACHMENT 1 7 IF RWST aligned to air bound 7 IF RCS aligned to air bound train, train, THEN prepare the air bound pump THEN prepare the air bound pump for starting as follows. for starting as follows.

7.1 Verify closed RCS supply to a) Verify air bound train RHR air bound train. HX BYP FLOW - ADJUSTED TO 15% OPEN.

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥£¥¥¥¥¥¥¥ Air Bound Train A B >>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥£¥¥¥¥¥¥ 1C(1A) RCS LOOP Air Bound Train A B TO 1A(1B) RHR PUMP PUMP 1A(1B) RHR HX Q1E11MOV []8701A

[]8701A []8702A

[]8702A BYP FLOW

[]8701B

[]8701B []8702B

[]8702B FK []605A

[]605A[]605B

[]605B

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥º ¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¢¥¥¥¥¥¥º 7.2 Verify air bound train RHR HX b) Verify air bound train RHR BYP FLOW - ADJUSTED TO 15% HX discharge valve -

OPEN. ADJUSTED CLOSED.

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥£¥¥¥¥¥¥ >>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥£¥¥¥¥¥¥ Air Bound Train A B Air Bound Train A B 1A(1B) RHR HX 1A(1B) RHR HX TO RCS RCS BYP FLOW DISCH VLV FK []605A

[]605A []605B

[]605B HIK []603A

[]603A[]603B

[]603B

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¢¥¥¥¥¥¥º ¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¢¥¥¥¥¥¥º 7.3 Verify air bound train RHR HX c) Proceed to step 8.

discharge valve - ADJUSTED CLOSED.

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥£¥¥¥¥¥¥ Air Bound Train A B 1A(1B) RHR HX TO RCS RCS DISCH VLV HIK []603A

[]603A []603B

[]603B

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¢¥¥¥¥¥¥º 7.4 Open fully RWST supply to air bound train.

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥£¥¥¥¥¥¥¥ Air Bound Train A B RWST TO 1A(1B) RHR PUMP Q1E11MOV []8809A

[]8809A []8809B

[]8809B

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥º Page 6 of 9

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained ATTACHMENT 1 CAUTION CAUTION:: Excessive start/stop cycling of RHR PUMPs may cause motor damage.

8 Run air bound RHR PUMP for 10 seconds.

9 IF 1A RHR PUMP was run for 10 seconds, THEN perform the following.

9.1 Open 1A RHR PUMP SEAL COOLER OUTLET VENTS Q1E11V080C and Q1E11V080A. (83 ft, AUX BLDG 1A RHR PUMP room) 9.2 WHEN air free water is seen, THEN close 1A RHR PUMP SEAL COOLER OUTLET VENTS Q1E11V080C and Q1E11V080A. (83 ft, AUX BLDG 1A RHR PUMP room) 9.3 Open 1A RHR HX OUTLET VENTS Q1E11V068C and Q1E11V068A.

(83 ft, AUX BLDG RHR HX room) 9.4 WHEN air free water is seen, THEN close 1A RHR HX OUTLET VENTS Q1E11V068C and Q1E11V068A. (83 ft, AUX BLDG RHR HX room) 9.5 Open 1C RCS LOOP TO 1A RHR PUMP HDR VENTS Q1E11V064C and Q1E11V064A. (100 ft, AUX BLDG piping penetration room, PEN

16) 9.6 WHEN air free water is seen, THEN close 1C RCS LOOP TO 1A RHR PUMP HDR VENTS Q1E11V064C and Q1E11V064A. (100 ft, AUX BLDG piping penetration room)

Step 9 continued on next page.

Page 7 of 9

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained ATTACHMENT 1 9.7 Open 1A RHR HX TO RCS COLD LEGS HDR VENTS Q1E11V055B and Q1E11VO55A. (121 ft, AUX BLDG piping penetration room, PEN

15) 9.8 WHEN air free water is seen, THEN close 1A RHR HX TO RCS COLD LEGS HDR VENTS Q1E11V055B and Q1E11VO55A. (121 ft, AUX BLDG piping penetration room) 10 IF 1B RHR PUMP was run for 10 seconds, THEN perform the following.

10.1 Open 1B RHR PUMP SEAL COOLER OUTLET VENTS Q1E11V080D and Q1E11V080B. (83 ft, AUX BLDG 1B RHR PUMP room) 10.2 WHEN air free water is seen, THEN close 1B RHR PUMP SEAL COOLER OUTLET VENTS Q1E11V080D and Q1E11V080B. (83 ft, AUX BLDG 1B RHR PUMP room) 10.3 Open 1B RHR HX OUTLET VENTS Q1E11V068D and Q1E11V068B.

(83 ft, AUX BLDG RHR HX room) 10.4 WHEN air free water is seen, THEN close 1B RHR HX OUTLET VENTS Q1E11V068D and Q1E11V068B. (83 ft, AUX BLDG RHR HX room) 10.5 Open 1A RCS LOOP TO 1B RHR PUMP HDR VENTS Q1E11V064D and Q1E11V064B. (100 ft, AUX BLDG piping penetration room, PEN

18)

Step 10 continued on next page.

Page 8 of 9

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained ATTACHMENT 1 10.6 WHEN air free water is seen, THEN close 1A RCS LOOP TO 1B RHR PUMP HDR VENTS Q1E11V064D and Q1E11V064B. (100 ft, AUX BLDG piping penetration room) 10.7 Open 1B RHR HX TO RCS COLD LEGS HDR VENTS Q1E11V058B and Q1E11VO58A. (121 ft, AUX BLDG piping penetration room, PEN

17) 10.8 WHEN air free water is seen, THEN close 1B RHR HX TO RCS COLD LEGS HDR VENTS Q1E11V058B and Q1E11VO58A. (121 ft, AUX BLDG piping penetration room) 11 IF no air seen, 11 Return to step 8.

THEN notify control room that venting is complete.

12 WHEN desired, THEN remove RHR vent rigs.

13 WHEN desired, THEN verify vent lines capped.

14 Notify control room that ATTACHMENT 1 is complete.

-END-Page 9 of 9

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained ATTACHMENT 2 RWST TO RCS GRAVITY FEED CAUTION CAUTION:: Gravity feed may not be sufficient to prevent core uncovery if a secondary heat sink or a hot leg vent path is not available.

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ NOTE: ATTACHMENT 2, FIGURE 1 and ATTACHMENT 2, FIGURE 2 provide expected gravity feed flow rates.

RWST TO 1A(1B) RHR PUMP Q1E11MOV8809A and Q1E11MOV8809B may be locally adjusted to control gravity feed flow at the Shift Supervisor's discretion.

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 1 IF A train RHR to RCS hot leg 1 IF B train RHR to RCS hot leg flow path available, flow path available, THEN perform the following. THEN perform the following.

1.1 Open 1C RCS LOOP TO 1A RHR a) Open 1A RCS LOOP TO 1B RHR PUMP Q1E11MOV8701A and PUMP Q1E11MOV8702A and Q1E11MOV8701B. Q1E11MOV8702B.

1.2 Open RWST TO 1A RHR PUMP b) Open RWST TO 1B RHR PUMP Q1E11MOV8809A to establish Q1E11MOV8809B to establish gravity feed. gravity feed.

2 IF gravity feed established, THEN proceed to step 4.

Page 1 of 4

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 Step Action/Expected Response Response NOT Obtained ATTACHMENT 2 3 IF A train RHR to RCS cold leg 3 IF B train RHR to RCS cold leg flow path available, flow path available, THEN perform the following. THEN perform the following.

3.1 Verify 1C RCS LOOP TO 1A RHR a) Verify 1A RCS LOOP TO 1B PUMP Q1E11MOV8701A and RHR PUMP Q1E11MOV8702A and Q1E11MOV8701B - CLOSED. Q1E11MOV8702B - CLOSED.

3.2 Verify 1A RHR PUMP MINIFLOW b) Verify 1B RHR PUMP MINIFLOW Q1E11FCV602A - OPEN. Q1E11FCV602B - OPEN.

3.3 Verify 1A RHR HX TO RCS COLD c) Verify 1B RHR HX TO RCS LEGS ISO Q1E11MOV8888A - OPEN. COLD LEGS ISO Q1E11MOV8888B

- OPEN.

3.4 Open RWST TO 1A RHR PUMP Q1E11MOV8809A to establish d) Open RWST TO 1B RHR PUMP gravity feed. Q1E11MOV8809B to establish gravity feed.

4 Notify control room that ATTACHMENT 2 is complete.

-END-Page 2 of 4

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 ATTACHMENT 2 FIGURE 1 Page 3 of 4

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 ATTACHMENT 2 FIGURE 2 Page 4 of 4

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 ATTACHMENT 3 Time to Core Saturation 1 Time to Core Saturation:

1.1 Tables A and B provide estimates of the time to core boiling following a loss RHR capability for two cases:

1.1.1 TABLE A provides a Time to Saturation as a function of time after shutdown for a full core immediately after shutdown for a refueling.

1.1.2 TABLE B provides a Time to Saturation as a function of time after shutdown for a core in which one third of the spent fuel has been replaced with new fuel.

1.2 Both cases are evaluated for conditions when RCS level is at mid loop (122'9"), at three feet below the reactor flange (126'7"), and when the reactor cavity is full.

1.3 Both cases are also evaluated for three assumed initial temperatures:

100 100F, 120 120F, and 140 140F.

1.4 These figures can be used to estimate the amount of time available for operator action to restore RHR before additional protective measures must be taken.

Page 1 of 7

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 ATTACHMENT 3 Time to Core Saturation TABLE AA---POWER

---POWER UPRATED UNIT TIME TO SATURATION: FULL CORE ASSUMED INITIAL TEMPERATURE=

TEMPERATURE=100 F 100

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ Time After Time to Saturation Time to Saturation Time to Saturation Saturation Shutdown (hours)

(hours) at midloop (mins) 3' below flange full Rx cavity (mins) (hours)

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 40 7.7 10.5 5.6

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 60 8.7 11.9 6.3

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 80 9.5 13.0 6.9

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 100 10.4 14.2 7.5

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 120 11.3 15.4 8.2

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 140 11.9 16.3 8.6

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 160 12.7 17.4 9.2

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 180 13.3 18.2 9.6

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 200 13.9 19.0 10.1

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 336 17.1 23.4 12.4

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 504 20.8 28.5 15.1

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥º VOLUME REFERENCE TABLE

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ MIDLOOP VOLUME(FT 3 ) 945

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥ VOLUME 3FT BELOW FLANGE(FT 3 ) 348 TOTAL= 1293

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ VOLUME FULL REACTOR CAVITY(FT 3 ) 39750 TOTAL= 41043

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥º Page 2 of 7

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 ATTACHMENT 3 Time to Core Saturation TABLE AA---POWER

---POWER UPRATED UNIT TIME TO SATURATION: FULL CORE ASSUMED INITIAL TEMPERATURE=

TEMPERATURE=120 120F

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ Time After Time to Saturation Time to Saturation Time to Saturation Saturation Shutdown (hours)

(hours) at midloop (mins) 3' below flange full Rx cavity (mins) (hours)

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 40 6.3 8.6 4.5

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 60 7.1 9.8 5.2

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 80 7.8 10.6 5.6

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 100 8.5 11.7 6.2

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 120 9.2 12.6 6.7

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 140 9.8 13.4 7.1

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 160 10.4 14.2 7.5

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 180 10.9 14.9 7.9

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 200 11.4 15.6 8.2

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 336 14.0 19.1 10.1

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 504 17.0 23.3 12.3

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥º VOLUME REFERENCE TABLE

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ MIDLOOP VOLUME(FT 3 ) 945

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥ VOLUME 3FT BELOW FLANGE(FT 3 ) 348 TOTAL= 1293

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ VOLUME FULL REACTOR CAVITY(FT 3 ) 39750 TOTAL= 41043

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥º Page 3 of 7

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 ATTACHMENT 3 Time to Core Saturation TABLE AA---POWER

---POWER UPRATED UNIT TIME TO SATURATION: FULL CORE ASSUMED INITIAL TEMPERATURE=

TEMPERATURE=140 140F

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ Time After Time to Saturation Time to Saturation Time to Saturation Saturation Shutdown (hours)

(hours) at midloop (mins) 3' below flange full Rx cavity (mins) (hours)

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 40 4.9 6.7 3.5

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 60 5.6 7.6 4.0

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 80 6.1 8.3 4.4

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 100 6.6 9.1 4.8

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 120 7.2 9.8 5.2

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 140 7.6 10.4 5.5

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 160 8.1 11.1 5.9

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 180 8.5 11.6 6.1

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 200 8.9 12.1 6.4

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 336 10.9 14.9 7.9

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 504 13.3 18.2 9.6

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥º VOLUME REFERENCE TABLE

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ MIDLOOP VOLUME(FT 3 ) 945

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥ VOLUME 3FT BELOW FLANGE(FT 3 ) 348 TOTAL= 1293

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ VOLUME FULL REACTOR CAVITY(FT 3 ) 39750 TOTAL= 41043

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥º Page 4 of 7

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 ATTACHMENT 3 Time to Core Saturation TABLE BB---POWER

---POWER UPRATED UNIT TIME TO SATURATION: ONE THIRD NEW FUEL ASSUMED INITIAL TEMPERATURE=

TEMPERATURE=100 100F

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ Time After Time to Saturation Time to Saturation Time to Saturation Saturation Shutdown (hours)

(hours) at midloop (mins) 3' below flange full Rx cavity (mins) (hours)

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 100 15.6 21.4 11.3

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 200 20.9 28.5 15.1

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 300 24.7 33.7 17.8

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 400 27.5 37.6 19.9

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 500 31.1 42.5 22.5

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 600 34.5 47.3 25.0

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 700 37.2 51.0 27.0

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 800 40.4 55.3 29.2

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥º VOLUME REFERENCE TABLE

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ MIDLOOP VOLUME(FT 3 ) 945

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥ VOLUME 3FT BELOW FLANGE(FT 3 ) 348 TOTAL= 1293

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ VOLUME FULL REACTOR CAVITY(FT 3 ) 39750 TOTAL= 41043

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥º Page 5 of 7

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 ATTACHMENT 3 Time to Core Saturation TABLE BB---POWER

---POWER UPRATED UNIT TIME TO SATURATION: ONE THIRD NEW FUEL ASSUMED INITIAL TEMPERATURE=

TEMPERATURE=120 120F

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ Time After Time to Saturation Time to Saturation Time to Saturation Saturation Shutdown (hours)

(hours) at midloop (mins) 3' below flange full Rx cavity (mins) (hours)

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 100 12.8 17.5 9.2

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 200 17.1 23.4 12.4

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 300 20.2 27.6 14.6

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 400 22.5 30.8 16.3

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 500 25.4 34.8 18.4

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 600 28.3 38.7 20.5

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 700 30.5 41.7 22.1

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 800 33.0 45.2 23.9

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥º VOLUME REFERENCE TABLE

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ MIDLOOP VOLUME(FT 3 ) 945

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥ VOLUME 3FT BELOW FLANGE(FT 3 ) 348 TOTAL= 1293

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ VOLUME FULL REACTOR CAVITY(FT 3 ) 39750 TOTAL= 41043

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥º Page 6 of 7

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 ATTACHMENT 3 Time to Core Saturation TABLE BB---POWER

---POWER UPRATED UNIT TIME TO SATURATION: ONE THIRD NEW FUEL ASSUMED INITIAL TEMPERATURE=

TEMPERATURE=140 140F

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ Time After Time to Saturation Time to Saturation Time to Saturation Saturation Shutdown (hours)

(hours) at midloop (mins) 3' below flange full Rx cavity (mins) (hours)

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 100 10.0 13.6 7.2

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 200 13.3 18.2 9.6

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 300 15.7 21.5 11.4

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 400 17.5 24.0 12.7

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 500 19.8 27.1 14.3

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 600 22.0 30.1 15.9

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 700 23.7 32.5 17.2

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ 800 25.7 35.2 18.6

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥º VOLUME REFERENCE TABLE

>>¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ MIDLOOP VOLUME(FT 3 ) 945

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥£¥¥¥¥¥¥¥¥ VOLUME 3FT BELOW FLANGE(FT 3 ) 348 TOTAL= 1293

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥ VOLUME FULL REACTOR CAVITY(FT 3 ) 39750 TOTAL= 41043

¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥¥¥¢¥¥¥¥¥¥¥¥º

-END-Page 7 of 7

3/15/2013 00:29 FNP-1-AOP-12.0 UNIT 1 RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION Revision 25.0 ATTACHMENT 4 REFERENCES/COMMITMENTS 1 0007011 Commmitment completed by Rev 1&2 of this procedure 2 0007012 PROCEDURE STEPS, step 19 Caution prior to the step 3 0007013 PROCEDURE STEPS, step 15 4 0007230, 0007236 Entire procedure fulfills these commitments 5 0007569 PROCEDURE STEPS, step 21.1 6 0007570 PROCEDURE STEPS, step 22 7 0007583 PROCEDURE STEPS, step 31 8 0007584, 0007594, 0009103 Entire procedure fulfills these commitments

-END-Page 1 of 1

FNP ILT-38 ADMIN Page 1 of 6 A.1.b SRO TITLE: Determine Active License Status.

EVALUATION LOCATION: SIMULATOR CONTROL ROOM CLASSROOM PROJECTED TIME: 30 MIN SIMULATOR IC NUMBER: N/A ALTERNATE PATH TIME CRITICAL PRA JPM DIRECTIONS:

1. Initiation of task may be in group setting, evaluation performed individually upon completion.

2. Requiring the examinee to acquire the required references may or may not be included as part of the JPM.

TASK STANDARD: Upon successful completion of this JPM, the examinee will:

Correctly assess and determine the Active or Inactive License status of Plant Operators.

Examinee:

Overall JPM Performance: Satisfactory Unsatisfactory Evaluator Comments (attach additional sheets if necessary)

EXAMINER:

Developer S Jackson Date: 4/2/15 NRC Approval SEE NUREG 1021 FORM ES-301-3

FNP ILT-38 ADMIN A.1.b. SRO Page 2 of 6 CONDITIONS When I tell you to begin, you are to DETERMINE THE ACTIVE OR INACTIVE STATUS OF LICENSED OPERATORS. The conditions under which this task is to be performed are:

a. An RO is required to fill the OATC position on January 31, 2015.

b. Three off shift ROs are available.

c. All three are current in LOCT (Licensed Operator Continuing Training) and have had a medical exam as required to maintain an active license.

d. None of the three have worked any shifts since December 31, 2014.

e. The three operators work history are as follows:

Operator A - License was active on October 1, 2014.

10/02/14 worked 1900-0700 as Unit 2 OATC 10/04/14 worked 1900-0700 as Unit 1 UO 10/05/14 worked 1900-0700 as Unit 1 OATC 11/14/14 worked 0700-1500 as Unit 2 UO 11/17/14 worked 0700-1500 as Unit 2 UO 11/18/14 worked 0700-1100 as Unit 2 UO

Operator B - License was active on October 1, 2014.

10/28/14 worked 0700-1900 as Unit 1 UO 11/03/14 worked 0700-1900 as Unit 1 UO 11/05/14 worked 0700-1900 as an on shift Extra 11/14/14 worked 1900-0700 as Unit 1 OATC 12/05/14 worked 0700-1900 as Unit 1 UO

Operator C - License was inactive on October 1, 2014.

From 10/12/2014 thru 10/16/2014 worked 40 hours4.62963e-4 days 0.0111 hours 6.613757e-5 weeks 1.522e-5 months under the direction of the Unit 1 OATC and completed all requirements for license reactivation.

11/15/14 worked 0700-1900 as Unit 2 OATC 12/04/14 worked 0700-1900 as Unit 2 OATC 12/16/14 worked 0700-1900 as Unit 1 UO 12/17/14 worked 0700-1900 as Unit 1 OATC

f. You have been directed to determine the Active or Inactive status of the three off shift ROs on January 31, 2015, in accordance with NMP-TR-406, Active License Maintenance.

INITIATING CUE: IF you have no questions, you may begin.

FNP ILT-38 ADMIN A.1.b. SRO Page 3 of 6 EVALUATION CHECKLIST RESULTS ELEMENTS: STANDARDS: (CIRCLE)

START TIME

1. Evaluate the status of Operator A. Operator A is determined to have S / U INACTIVE license status based on the 11/18/14 shift is less than 8 or 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months so it does not count toward the 56 hour6.481481e-4 days 0.0156 hours 9.259259e-5 weeks 2.1308e-5 months total. 52 hours6.018519e-4 days 0.0144 hours 8.597884e-5 weeks 1.9786e-5 months count. Step 5.5.2.2 of NMP -TR-406.

2. Evaluate the status of Operator B. Operator B is determined to have S / U INACTIVE license status. This operator worked 5 - 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months shifts during the calendar quarter October 1 - December 31, but one of those shifts was NOT in a position required by Tech Specs (11/05/2014 working as an on shift Extra). Step 5.5.2.1 of NMP -TR-406.

3. Evaluate the status of Operator C. Operator C is determined to have S / U ACTIVE license status. This operator reactivated his license during the calendar quarter of October 1-December 31, 2014.

When a license is reactivated, it is considered active for that quarter without working any additional shifts. When a licensed operator has met the requirements for an active license in a quarter he is available and considered active for the next quarter. Step 5.6.1 and 5.6.8 and 5.6.9 of NMP -TR-406.

STOP TIME Terminate when all elements of the task have been completed.

CRITICAL ELEMENTS: Critical Elements are denoted with an asterisk () before the element number.

FNP ILT-38 ADMIN A.1.b. SRO Page 4 of 6 GENERAL

REFERENCES:

1. NMP-TR-406, ver 6.2

2. KA: G2.1.4 - 3.3 / 3.8 GENERAL TOOLS AND EQUIPMENT:

1. NMP-TR-406, ver 6.2 - on Reference Disk

2. Scratch paper, calculator as requested.

Critical ELEMENT justification:

STEP Evaluation 1 Critical: Task completion: required to properly evaluate the active or inactive status of Operator A.

2 Critical: Task completion: required to properly evaluate the active or inactive status of Operator B.

3 Critical: Task completion: required to properly evaluate the active or inactive status of Operator C.

COMMENTS:

FNP ILT-38 ADMIN A.1.b. SRO Page 5 of 6 KEY Operator A status - ____INACTIVE___________. (Active / Inactive)

Operator B status - ____ INACTIVE _____. (Active / Inactive)

Operator C status - ____ ACTIVE ____. (Active / Inactive)

FNP ILT-38 ADMIN A.1.b SRO HANDOUT Pg 1 of 1 CONDITIONS When I tell you to begin, you are to DETERMINE THE ACTIVE OR INACTIVE STATUS OF LICENSED OPERATORS. The conditions under which this task is to be performed are:

a. An RO is required to fill the OATC position on January 31, 2015.

b. Three off shift ROs are available.

c. All three are current in LOCT (Licensed Operator Continuing Training) and have had a medical exam as required to maintain an active license.

d. None of the three have worked any shifts since December 31, 2014.

e. The three operators work history is as follows:

Operator A - License was active on October 1, 2014.

10/02/14 worked 1900-0700 as Unit 2 OATC 10/04/14 worked 1900-0700 as Unit 1 UO 10/05/14 worked 1900-0700 as Unit 1 OATC 11/14/14 worked 0700-1500 as Unit 2 UO 11/17/14 worked 0700-1500 as Unit 2 UO 11/18/14 worked 0700-1100 as Unit 2 UO

Operator B - License was active on October 1, 2014.

10/28/14 worked 0700-1900 as Unit 1 UO 11/03/14 worked 0700-1900 as Unit 1 UO 11/05/14 worked 0700-1900 as an on shift Extra 11/14/14 worked 1900-0700 as Unit 1 OATC 12/05/14 worked 0700-1900 as Unit 1 UO

Operator C - License was inactive on October 1, 2014.

From 10/12/2014 thru 10/16/2014 worked 40 hours4.62963e-4 days 0.0111 hours 6.613757e-5 weeks 1.522e-5 months under the direction of the Unit 1 OATC and completed all requirements for license reactivation.

11/15/14 worked 0700-1900 as Unit 2 OATC 12/04/14 worked 0700-1900 as Unit 2 OATC 12/16/14 worked 0700-1900 as Unit 1 UO 12/17/14 worked 0700-1900 as Unit 1 OATC

f. You have been directed to determine the Active or Inactive status of the three off shift ROs on January 31, 2015, in accordance with NMP-TR-406, Active License Maintenance.

Operator A status - _______________. (Active / Inactive)

Operator B status - _______________. (Active / Inactive)

Operator C status - _______________. (Active / Inactive)

Southern Nuclear Operating Company Nuclear NMP-TR-406 Management License Administration Version 6.2 Procedure Page 10 of 28 5.4.3 After the Licensed Operator signs the NRC Form 398, they shall return it to the Operations Training Group who will then route the NRC Form 398 and the individuals most recent NRC Form 396 to the Training Manager for review and approval.

5.4.3.1 The Training Manager shall sign the NRC Form 398 after the individual and then send the signed form to the Site Vice President or Senior Management Representative.

5.4.4 The Operation Training Group shall mail the original NRC Form 398 and the NRC Form 396, along with a cover letter to the NRC, per 10 CFR 55, at least 30 days (i.e.,

25 Administrative day limit) prior to expiration of the Licensed Operators license.

Refer to Attachment 5 for a sample Cover Letter.

NOTE IF an Operator or Senior Operator applies for a renewal at least 30 days (i.e., 25 Administrative day limit) before the Expiration Date of the existing license, THEN the license does NOT expire until the NRC determines the final disposition of the renewal application.

5.4.5 When the license renewal has been signed and mailed to the NRC in a timely manner (i.e., at least 25 Administrative days prior to expiration) the Operations Training Group shall create a Learning Event for the Licensed Operator for the appropriate item in the LMS for the date the license renewal was submitted.

5.4.6 Upon receipt of the license, renewal from the NRC the Operations Training Group shall edit the Learning Event for the Licensed Operator for the appropriate item in the LMS for the date the license was effective.

5.4.7 The Operations Training Group shall transmit a copy of NRC Form 396 to Medical Services for record processing. The Operations Training Group shall process the cover letter, the NRC Form 398, and the license for records retention.

5.5 Maintenance of an ACTIVE License Only a Licensed Operator with an ACTIVE license shall be allowed to manipulate the controls or supervise the manipulation of the controls of the reactor.

5.5.1 Per NUREG 1262 Q. 293, a newly Licensed Operator is considered to have met the proficiency requirements for an active license for the initial calendar quarter in which the license was issued.

5.5.1.1 Upon receipt of a new license, a Learning Event shall be created for the Licensed Operator to give credit for proficiency.

5.5.2 NUREG 1021 states:

In accordance with 10 CFR 55.53 (e), licensed operators are required to maintain their proficiency by actively performing the functions of an operator or senior operator on at least seven 8-hour or five 12-hour shifts per calendar quarter. This requirement may be completed with a combination of complete 8- and 12-hour shifts (in a position required by the plants technical specifications) at sites having a mixed shift schedule, and watches shall not be truncated with the minimum quarterly requirement (56 hours6.481481e-4 days 0.0156 hours 9.259259e-5 weeks 2.1308e-5 months ) is satisfied. Overtime may be credited if the overtime work is in a position required by

Southern Nuclear Operating Company Nuclear NMP-TR-406 Management License Administration Version 6.2 Procedure Page 11 of 28 the plants technical specifications. Overtime as an extra helper after the official watch has been turned over to another watch stander does not count toward proficiency time.

5.5.2.1 Maintenance of an active license requires that an individual spend seven (7) eight-hour shifts or five (5) twelve-hour shifts in a position that requires the license per the Technical Specifications (i.e., OATC, UO, SS, SM, or SRO during Core Alterations as defined in Technical Specifications) in a calendar quarter.

5.5.2.2 IF an individual stands a combination of complete 12 or eight-hour shifts that total 56 hours6.481481e-4 days 0.0156 hours 9.259259e-5 weeks 2.1308e-5 months in the quarter, THEN this requirement is satisfied. A shift of less than eight (8) hours does NOT count toward the 56-hour total. IF an individual spends this shift time in a position that only requires an RO license (i.e., UO, OATC), THEN they are an active RO only. If they spend this time in an SRO position (i.e., SS, SM) they are an active SRO. IF they spend this time as a SRO in charge of fuel handling during Core Alterations, THEN they are an active SRO only for supervising Core Alterations.

5.5.2.2.1 It is permissible for an individual with an SRO license to maintain only the RO portion of their license in an active state by performing the functions of an RO for a minimum of seven (7) 8-hour OR five (5) 12-hour shifts per calendar quarter pursuant to 10 CFR 55.53(e).

5.5.2.3 In order to maintain the Supervisory portion of the SRO license active, a SRO must stand at least one (1) complete watch per calendar quarter in an SRO-only supervisory position. The remainder of complete watches required in a calendar quarter may be performed in either a credited SRO or RO position. These shifts must be on a unit that has fuel in the vessel. IF a Licensed SRO stands all of their required proficiency watches in an SRO position, THEN the RO portion of the license is still considered active. Performing the required number of shifts per calendar quarter on a single unit maintains the license active for all similar units on an individuals license.

5.5.3 The active Licensed Operator shall complete NMP-TR-406-F01 once per quarter to document these proficiency hours and forward the form to the Operation Training Coordinator.

5.5.4 The Operations Department Training Coordinator or designee shall maintain a record of these hours and create a Learning Event for each Licensed Operator who meets the SRO requirement or for each Licensed Operator who meets the RO requirement.

Failure to meet the time requirements for hours on-shift places that level of license (i.e., RO, SRO) in an Inactive status. The Licensed Operator shall NOT be allowed to stand shift in a position that requires that level of license until they have completed reactivation per this procedure. Operations Supervision and the Licensed Operator shall be notified by the Operations Training Group OR the Operations Training Coordinator if the Licensed Operators license is placed in an Inactive condition.

Southern Nuclear Operating Company Nuclear NMP-TR-406 Management License Administration Version 6.2 Procedure Page 12 of 28 5.5.5 An ACTIVE license shall require a Licensed Operator to either:

x Maintain NMP-TR-406-F01 OR x Complete NMP-TR-406-F02 OR NMP-TR-406-F03 OR x Receive a Nuclear Regulatory Commission (NRC) license within the current calendar quarter.

5.5.5.1 Additionally, an ACTIVE license shall require a Licensed Operator to:

x Maintain Medical Certification.

x Maintain Medical Certification for respirator use per the applicable Medical Services procedures.

x Have Dosimetry available.

x Have contacts OR respirator glasses readily available to correct vision to within the limits of ANSI 3.4, 1983 or ANSI 3.4, 1996, as applicable.

x Be current in Licensed Operator Continuing Training (LOCT) as demonstrated by showing qualification complete in the Learning Management System (LMS).

x Be current in respirator medical per the LMS qualifications S-MEDRES49 OR S-MEDRES50.

x Be current in Respirator Training per the LMS Qualification.

x Be current in Self-Contained Breathing Apparatus (SCBA) Training per the LMS.

5.5.5.2 IF a Licensed Operator fails to meet the Medical OR Training Requirements above, THEN they may be removed from a shift position that requires an active license until the requirement is met. The Operations Training Group shall notify Operations Management of the required removal from active licensed duties via a telephone call to Line Management followed by a written memo.

5.6 License Reactivation NOTE All items shall be completed within the same calendar quarter.

In order to reactivate an RO or SRO license, 10 CFR 55 paragraph 55.53(f) requires:

5.6.1 Before resumption of functions authorized by a license issued under this part, an authorized Representative of the Facility shall certify the following:

That the licensee has completed a minimum of 40 hours4.62963e-4 days 0.0111 hours 6.613757e-5 weeks 1.522e-5 months of shift functions (i.e., UO or OATC for RO; SS or SM for SRO) under the direction of an Operator or Senior

Southern Nuclear Operating Company Nuclear NMP-TR-406 Management License Administration Version 6.2 Procedure Page 13 of 28 Operator (i.e., SS or SM) as appropriate and in the position to which the individual will be assigned. The 40 hours4.62963e-4 days 0.0111 hours 6.613757e-5 weeks 1.522e-5 months must have included a complete tour of the Plant and all required shift turnover procedures with an Operator or Senior Operator. The 40 hours4.62963e-4 days 0.0111 hours 6.613757e-5 weeks 1.522e-5 months must be on a unit that has fuel in the vessel and be performed in the same calendar quarter. Refer to 2.14 Page 78, Question 277 of NUREG 1262.

5.6.2 The above means that the individual will stand shift with the person in the stated position. The individual reactivating may only be separate from the person who signs for the time credited for infrequent (i.e., 1-2 times in a shift) brief periods OR during plant tours. The Plant Tour is part of the 40 hours4.62963e-4 days 0.0111 hours 6.613757e-5 weeks 1.522e-5 months of shift functions. At least one (1) shift turnover at the beginning of shift and one (1) at the end of shift must be observed.

5.6.3 Only one (1) individual per licensed position may reactivate under the direction and in the presence of a Licensed Operator or Senior Operator.

5.6.4 The Licensee reactivating shall ensure that entries are made in the Control Room Operator Log for the time period involved in reactivation; including each shift, turnover, and Plant Tour.

5.6.5 Complete NMP-TR-406-F03 of this procedure and return it to the Lead Instructor -

Operations Continuing Training OR the Nuclear Operations Training Manager (OTM).

5.6.6 Operations Training Supervision shall forward the form to the Operations Director for approval.

5.6.7 After the Operations Director or designee approves the reactivation form, it shall be returned to the Operations Training Group. Training shall then create a learning event in the LMS for Reactivation. Training shall transmit the original to Document Control.

5.6.8 The Licensed Operator does NOT have to stand any more shifts through the end of the calendar quarter in which they reactivated.

5.6.9 The license will remain active until the Licensed Operator fails to meet the requirements of this procedure to maintain an active license.

5.6.10 All items of NMP-TR-406-F03, up to and including the Operations Directors signature for reactivation approval, shall be completed within the same calendar quarter.

5.7 Reactivation of a Senior Reactor Operator for Supervising Core Alterations NOTE Reactivation of the Core Alterations license is only good for one refueling outage and the license shall be de-activated in the LMS at the end of the refueling outage.

In order to reactivate a SRO license for supervising Core Alterations only, NUREG 1021 states:

The NRCs requirements regarding the conduct of under-instruction or training watches are reflected in 10 CFR 55.13, which allows trainees to manipulate the controls of a facility under the direction and in the presence of a licensed operator or senior operator This position is also evident in the responses to Questions 252 and 276 in NUREG 1262, Answers to Questions at Public Meetings Regarding Implementation of

FNP ILT-38 ADMIN Page 1 of 4 A.2 RO TITLE: MOD - Perform A Quadrant Power Tilt Ratio Calculation PROGRAM APPLICABLE: SOT SOCT OLT X LOCT X ACCEPTABLE EVALUATION METHOD: X PERFORM SIMULATE DISCUSS EVALUATION LOCATION: X CLASSROOM PROJECTED TIME: 20 MIN SIMULATOR IC NUMBER: N/A ALTERNATE PATH TIME CRITICAL PRA JPM DIRECTIONS:

1. Initiation of task may be in group setting, evaluation performed individually upon completion.

TASK STANDARD: Upon successful completion of this JPM, the examinee will:

1. Correctly determine the QPTR.

2. Correctly determine whether or not the QPTR meets acceptance criteria Examinee:

Overall JPM Performance: Satisfactory Unsatisfactory Evaluator Comments (attach additional sheets if necessary)

EXAMINER: _____________________________

Developer S. Jackson Date: 4/3/15 NRC Approval SEE NUREG 1021 FORM ES-301-3

FNP ILT-38 ADMIN Page 2 of 4 CONDITIONS When I tell you to begin, you are to PERFORM A QUADRANT POWER TILT RATIO CALCULATION. The conditions under which this task is to be performed are:

a. N-41, N-42, & N-43 PR NI detectors are OPERABLE.

b. N-44 PR NI detector is INOPERABLE.

c. You are directed by Shift Supervisor to perform STP-7.0, using curves 71A-D and pictures provided, and determine if the acceptance criteria is met.

d. The IPC and QPTR computer spreadsheet are not available.

e. A DVM will NOT be used to collect data.

f. A pre-job brief is not required.

EVALUATION CHECKLIST RESULTS:

ELEMENTS: STANDARDS: (CIRCLE)

START TIME NOTE: Critical to use the correct 0% AFD values from curves.

1. Obtain normalized currents from curves Obtains normalized current values S / U 71A, 71B, & 71C. (Curve 71A-C) and records them on Attachment 1 of STP-7.0.

2. Record data for power range detector A and Values from PRNI pictures for S / U detector B from Data sheet 2. detector A and detector B of NI-41, 42, & 43 displays recorded on Attachment 1 of STP-7.0.

3. Calculate upper and lower quadrant power Upper ratio calculated at S / U tilt ratios. 1.01 to 1.014 Lower ratio calculated at 1.01 to 1.02 NOTE: Depending on how rounding is performed in the calculation, both upper and lower ratios may be equal.

4. Enter the greater of the upper or lower Greater of the above two values S / U quadrant power tilt ratio. Lower: 1.01 to 1.02 entered.

5. Records power level. Current avg power level recorded. S / U

6. Determines acceptance criteria MET. Determination made that S / U acceptance criteria is MET.

FNP ILT-38 ADMIN Page 3 of 4 EVALUATION CHECKLIST RESULTS:

ELEMENTS: STANDARDS: (CIRCLE)

7. Reports to Shift Supervisor that acceptance Reports to Shift Supervisor that S / U criteria is NOT met. acceptance criteria is MET.

QPTR. (CUE: Shift Supervisor acknowledges).

8. Fills out Surveillance Test Review sheet per Fills out Surveillance Test Review S / U attached key. sheet per attached key.

STOP TIME Terminate when assessment of acceptance criteria is performed.

CRITICAL ELEMENTS: Critical Elements are denoted with an asterisk () preceding the element number.

GENERAL REFERENCES

1. FNP-1-STP-7.0, Version 17.0

2. Core Physics curves 71A-D Rev. 16.0

3. K/A: G2.1.12 - 3.7 / 4.1 GENERAL TOOLS AND EQUIPMENT

1. Calculator

2. STP-7.0

3. Core Physics curves 71A-D

4. Pictures of PRNIs.

Critical ELEMENT justification:

STEP Evaluation 1-4 Critical: Task completion: required to properly determine QTPR.

5 Not Critical: Does not determine the calculation nor the acceptance criteria.

6 Critical: Task completion: Must decide whether or not acceptance criteria is met.

7-8 Not Critical: Does not determine the calculation nor the acceptance criteria.

COMMENTS:

A.2 RO HANDOUT CONDITIONS When I tell you to begin, you are to PERFORM A QUADRANT POWER TILT RATIO CALCULATION.

The conditions under which this task is to be performed are:

a. N-41, N-42, & N-43 PR NI detectors are OPERABLE.

b. N-44 PR NI detector is INOPERABLE.

c. You are directed by Shift Supervisor to perform STP-7.0, using curves 71A-D and pictures provided, and determine if the acceptance criteria is met.

d. The IPC and QPTR computer spreadsheet are not available.

e. A DVM will NOT be used to collect data.

f. A pre-job brief is not required.

FARLEY Unit 1 SAFETY RELATED FNP-1-STP-7.0 Quadrant Power Tilt Ratio Calculation VERSION 23.0 Special Considerations:

This is an upgraded procedure. Exercise increased awareness during initial use due to potential technical and/or sequential changes. After initial use, provide comments to the procedure upgrade team.

PROCEDURE LEVEL OF USE CLASSIFICATION PER NMP-AP-003 CATEGORY SECTIONS Continuous ALL Reference NONE Information NONE Approval: David L Reed 10/11/13 Approved By Date Effective Date:

OPERATIONS Responsible Department Printed 10/28/2013 at 18:55:00

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 2 of 15 VERSION

SUMMARY

PVR

23.0 DESCRIPTION

Updated to fleet template and writer's guide Printed 10/28/2013 at 18:55:00

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 3 of 15 TABLE OF CONTENTS SECTION .......................................................................................................................................... PAGE 1.0 PURPOSE ....................................................................................................................................4 2.0 PRECAUTIONS AND LIMITATIONS............................................................................................4 3.0 INITIAL CONDITIONS ..................................................................................................................4 4.0 INSTRUCTIONS ...........................................................................................................................5 4.1 QPTR Determination Using The IPC. ...........................................................................................5 4.2 QPTR Determination Using Manual Calculation:..........................................................................6 4.3 Determination Of QPTR Acceptance Criteria: ..............................................................................6 5.0 ACCEPTANCE CRITERIA ...........................................................................................................7 6.0 RECORDS ....................................................................................................................................7

7.0 REFERENCES

.............................................................................................................................7 ATTACHMENT 1 Quadrant Power Tilt Ratio Calculation without Plant Computer ...................................................8 2 Using A DVM To Obtain Detector Current Values ......................................................................13 3 Surveillance Test Review Sheet .................................................................................................15 Printed 10/28/2013 at 18:55:00

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 4 of 15 1.0 PURPOSE

To determine the quadrant power tilt ratio using power range nuclear instrumentation.

Acceptance Criteria for this test is the quadrant power tilt ratio shall be 1.020.

2.0 PRECAUTIONS AND LIMITATIONS

1. Reactor power, rod position and reactor coolant temperature should be constant while taking data. ...........................................................................................

2. A QPTR calculation should be done prior to rescaling of Power Range Nuclear Instruments, and after completing the rescaling of ALL Power Ranges Nuclear Instruments. A QPTR calculation performed between individual Power Range rescaling may provide erroneous results......................................................................

3. IF one Power Range NI is inoperable AND thermal power is < 75% RTP, the remaining power range channels may be used for calculating QPTR.

(SR 3.2.4.1) ..................................................................................................................

4. Above 75% RTP, with one Power Range NI inoperable, QPTR must be determined by SR 3.2.4.2. ...........................................................................................

5. The SM/SS shall be notified if any acceptance criteria are NOT satisfied. ..................

3.0 INITIAL CONDITIONS

1. The version of this procedure has been verified to be the current version.

(OR 1-98-498) ..........................................................................................................______

2. This procedure has been verified to be the correct procedure for the task.

(OR 1-98-498) ..........................................................................................................______

3. This procedure has been verified to be the correct unit for the task.

(OR 1-98-498) ..........................................................................................................______

NOTE This STP may be performed at less than 50% power for verification of power range instrument indications. In this case, the STP is NOT for surveillance credit. ....................................

4. Unit 1 is above 50% of rated thermal power. ..........................................................______

5. IF DVM is used to collect data, I&C has obtained a Fluke 45 or equivalent with shielded test leads with NO exposed metal connectors. .........................................______

DVM Serial number Cal. due date Printed 10/28/2013 at 18:55:00

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 5 of 15 3.0 INITIAL CONDITIONS (continued)

6. This procedure may contain previously evaluated Critical Steps that may not be applicable in certain plant conditions. The evaluation of this procedure for Critical Steps is performed during the Pre-Job briefing. The decision concerning how to address error precursors for critical steps should be governed by NMP-GM-005-GL03, Human Performance Tools. .............................______

NOTE Asterisked (*) steps are those associated with Acceptance Criteria. ................................................

4.0 INSTRUCTIONS 4.1 QPTR Determination Using The IPC.

NOTES Section 4.2, QPTR Determination Using Manual Calculation: should be used to calculate QPTR when the IPC QPTR application is unavailable. ......................................................................

1. Open the QPTR AND TILT FACTORS application on the IPC Applications Menu. .......................................................................................................................______

2. Check the following:

UPPER QPTR data indicates GOOD quality as indicated by affected points displayed in green. .............................................................................______

LOWER QPTR data indicates GOOD quality as indicated by affected points displayed in green. .............................................................................______

3. IF QPTR data is NOT GOOD quality, go to Section 4.2, QPTR Determination Using Manual Calculation: ......................................................................................______

4. IF QPTR data is GOOD quality, perform the following:

a. Click PRINT EXCORE REPORT button. ....................................................______

b. Include printed Excore Report with this procedure. .....................................______

c. Go to Section 4.3. .........................................................................................______

Printed 10/28/2013 at 18:55:00

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 6 of 15 NOTE With input from one Power Range Neutron Flux channel INOPERABLE and THERMAL POWER 75% RTP, the remaining three power range channels may be used for calculating QPTR. .............................................................................................................................

4.2 QPTR Determination Using Manual Calculation:

1. Calculate QPTR using Attachment 1, Quadrant Power Tilt Ratio Calculation without Plant Computer ............................................................................................______

2. Go to Section 4.3. ....................................................................................................______

4.3 Determination Of QPTR Acceptance Criteria:

NOTE QPTR value displayed by the IPC utilizes 3 decimal places (to the thousandths place). If the QPTR value displayed is, for example 1.021, this would exceed the limit of 1.02 and require performance of the LCO 3.2.4 Condition A Required Actions.

(NL-10-0406, dated 2/26/2010) .........................................................................................................

1. *Check Excore Maximum Quadrant Power Tilt Ratio 1.020 on either the EXCORE REPORT OR Attachment 1. ....................................................................______

ACCEPTANCE CRITERIA Maximum value of UPPER or LOWER Quadrant Power Tilt Ratio shall be 1.020.

Printed 10/28/2013 at 18:55:00

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 7 of 15 NOTE Asterisked (*) steps are those associated with Acceptance Criteria. ................................................

5.0 ACCEPTANCE CRITERIA The quadrant power tilt ratio shall be 1.020.

6.0 RECORDS Documents created using this procedure will become QA Records when completed unless otherwise stated. The procedures and documents are considered complete when issued in DMS.

QA Record (X) Non-QA Record (X) Record Generated Retention Time R-Type X FNP-1-STP-7.0 LP H06.045

7.0 REFERENCES

FSAR - Chapter 4.4.2.4

Technical Specification 3.2.4 Printed 10/28/2013 at 18:55:00

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 8 of 15 ATTACHMENT 1 Page 1 of 5 Quadrant Power Tilt Ratio Calculation without Plant Computer NOTE QPTR may be determined using normalized currents from Curves 71A, 71B, 71C, 71D AND either of the following:

Indicated detector current meter data. ..................................................................................

Detector currents read by DVM using Attachment 2. ............................................................

1. Obtain normalized currents from Curve 71(A, B, C, D). ..........................................______

2. Enter normalized currents from Curve 71 on the Calculation Sheet........................______

NOTE With input from one Power Range Neutron Flux channel INOPERABLE AND THERMAL POWER 75% RTP, the remaining three power range channels can be used for calculating QPTR. ..............................................................................................................................

3. Perform the following:

a. IF available, enter detector currents indicated on POWER RANGE B drawer meters on the Calculation Sheet for each of the following:

N1C55NI0041, N41B DETECTOR A, (Upper) .......................................

N1C55NI0041, N41B DETECTOR B, (Lower) .......................................

N1C55NI0042, N42B DETECTOR A, (Upper) .......................................

N1C55NI0042, N42B DETECTOR B, (Lower) .......................................

N1C55NI0043, N43B DETECTOR A, (Upper) .......................................

N1C55NI0043, N43B DETECTOR B, (Lower) .......................................

N1C55NI0044, N44B DETECTOR A, (Upper) .......................................

N1C55NI0044, N44B DETECTOR B, (Lower) .......................................

CAUTION DVM readings may be taken in only one drawer at a time. ................................................................

b. IF any NI current reading not available on the POWER RANGE B drawer, enter detector currents obtained by I&C using Attachment 2 for the affected detectors. ..................................................................................______

4. Enter total number of operable detectors in space provided on the Calculation Sheet. ......................................................................................................................______

Printed 10/28/2013 at 18:55:00

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 9 of 15 ATTACHMENT 1 Page 2 of 5 Quadrant Power Tilt Ratio Calculation without Plant Computer

5. Calculate the following:

Upper Quadrant Power Tilt Ratio. .................................................................______

Lower Quadrant Power Tilt Ratio. .................................................................______

6. *Record the greater of the upper or lower Quadrant Power Tilt Ratio value in the space provided on the Calculation Sheet. .........................................................______

ACCEPTANCE CRITERIA Maximum value of upper or lower Quadrant Power Tilt Ratio shall be 1.020.

7. Record the Power Level (Avg) in the space provided. ...........................................______

Printed 10/28/2013 at 18:55:00

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 10 of 15 ATTACHMENT 1 Page 3 of 5 Quadrant Power Tilt Ratio Calculation without Plant Computer Calculation Sheet Calculation Performed Using: Meter Data/DVM Data (Circle One)

UPPER QUADRANT POWER TILT POWER UPPER DET *UPPER DET UPPER DET RANGE B Indicated ÷ 100% Current = Calibrated Drawer Current Output Detector A N41T N41

÷ =

Detector A N42T N42

÷ =

Detector A N43T N43

÷ = Total Number 1 Upper Detector A N44T Operable Average Upper Maximum Upper Quadrant X =

N44 Upper Detector Detector Power Tilt

÷ = Detectors Calibrated Output Calibrated Output Ratio 1

Total Upper Detector Calibrated Output = ÷ = X =

Obtained from Curve 71(A, B, C, D), 0% AFD Current Printed 10/28/2013 at 18:55:00

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 11 of 15 ATTACHMENT 1 Page 4 of 5 Quadrant Power Tilt Ratio Calculation without Plant Computer Calculation Sheet Calculation Performed Using: Meter Data/DVM Data (Circle One)

LOWER QUADRANT POWER TILT POWER LOWER DET *LOWER DET LOWER DET RANGE B Indicated ÷ 100% Current = Calibrated Drawer Current Output Detector B N41B N41

÷ =

Detector B N42B N42

÷ =

Detector B N43B N43

÷ = Total Number 1 Lower Detector B N44B Operable Average Lower Maximum Lower Quadrant X =

N44 Lower Detector Detector Power Tilt

÷ = Detectors Calibrated Output Calibrated Output Ratio 1

Total Lower Detector Calibrated Output = ÷ = X =

Obtained from Curve 71(A, B, C, D), 0% AFD Current Printed 10/28/2013 at 18:55:00

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 12 of 15 ATTACHMENT 1 Page 5 of 5 Quadrant Power Tilt Ratio Calculation without Plant Computer Calculation Sheet Upper QPTR Lower QPTR Maximum of Upper or Lower QPTR ACCEPTANCE CRITERIA Maximum of Upper or Lower Quadrant Power Tilt Ratio does not exceed 1.020.

% Reactor Power Printed 10/28/2013 at 18:55:00

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 13 of 15 ATTACHMENT 2 Page 1 of 2 Using A DVM To Obtain Detector Current Values NOTE Detector current values may be obtained for as many drawers as required. Unused spaces in the Table should be marked N/A. ...................................................................................................

CAUTIONS

DVM readings may be taken in only one drawer at a time. .........................................................

A Fluke 8600 shall NOT be used to obtain currents ....................................................................

1. Using a Fluke 45 or equivalent AND shielded test leads connect to obtain detector voltage readings as follows:

NOTE Voltage values should be in the 2 to 3 volt range...............................................................................

a. For Upper Detector connect to TP301 (+) and TP305 (-). ...........................______

.......................................................................................................................... I&C (1) Record indicated voltage in appropriate space of table on page 2 of 2. .........................................................................................._____

............................................................................................................... I&C

b. For Lower Detector connect to TP302 (+) and TP305 (-). ...........................______

.......................................................................................................................... I&C (1) Record indicated voltage in appropriate space of table on page 2 of 2. .........................................................................................._____

............................................................................................................... I&C Printed 10/28/2013 at 18:55:00

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 14 of 15 ATTACHMENT 2 Page 2 of 2 Using A DVM To Obtain Detector Current Values NOTE The following formula is used to calculate detector currents:

Measured Detector Voltage x Curve 71 " 0% AFD, 100% Current" Value = Calculated Detector Current ..............

2.083

2. Using the 0% AFD, 100% current value from Curve 71, perform the following:

a. Calculate the detector current value. ...........................................................______

b. Record in appropriate space of table below. .................................................______

N41 N42 N43 N44 Upper Lower Upper Lower Upper Lower Upper Lower Detector A Detector B Detector A Detector B Detector A Detector B Detector A Detector B N41T N41B N42T N42B N43T N43B N44T N44B DVM Voltage DVM Voltage DVM Voltage DVM Voltage Step 1 Calculated Current Calculated Current Calculated Current Calculated Current Step 2 Printed 10/28/2013 at 18:55:00

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 15 of 15 ATTACHMENT 3 Page 1 of 1 Surveillance Test Review Sheet TECHNICAL SPECIFICATION REFERENCE MODE(S) REQUIRING TEST:

SR 3.2.4.1 1 (>50% Rated Thermal Power)

TEST RESULTS (TO BE COMPLETED BY TEST PERFORMER)

PERFORMED BY: / DATE/TIME: /

(Print) (Signature)

COMPONENT OR TRAIN TESTED (if applicable)

ENTIRE STP PERFORMED FOR SURVEILLANCE CREDIT PARTIAL STP PERFORMED NOT FOR SURVEILLANCE CREDIT REASON FOR PARTIAL TEST COMPLETED Satisfactory Unsatisfactory The following deficiencies occurred Corrective action taken or initiated SHIFT SUPERVISOR/ SHIFT SUPPORT SUPERVISOR REVIEW Procedure properly completed and satisfactory per step 9.1 of FNP-0-AP-5 Comments REVIEWED BY: / DATE:

(Print) (Signature)

Reviewer must be AP-31 Level II certified & cannot be the Performing Individual ENGINEERING SUPPORT GROUP SCREENING: SCREENED BY DATE (IF APPLICABLE)

Comments Printed 10/28/2013 at 18:55:00

KEY FARLEY Unit 1 SAFETY RELATED FNP-1-STP-7.0 Quadrant Power Tilt Ratio Calculation VERSION 23.0 Special Considerations:

This is an upgraded procedure. Exercise increased awareness during initial use due to potential technical and/or sequential changes. After initial use, provide comments to the procedure upgrade team.

PROCEDURE LEVEL OF USE CLASSIFICATION PER NMP-AP-003 CATEGORY SECTIONS Continuous ALL Reference NONE Information NONE Approval: David L Reed 10/11/13 Approved By Date Effective Date:

OPERATIONS Responsible Department Printed 10/28/2013 at 18:55:00 KEY

KEY Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 2 of 15 VERSION

SUMMARY

PVR

23.0 DESCRIPTION

Updated to fleet template and writer's guide Printed 10/28/2013 at 18:55:00 KEY

KEY Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 3 of 15 TABLE OF CONTENTS SECTION .......................................................................................................................................... PAGE 1.0 PURPOSE ....................................................................................................................................4 2.0 PRECAUTIONS AND LIMITATIONS............................................................................................4 3.0 INITIAL CONDITIONS ..................................................................................................................4 4.0 INSTRUCTIONS ...........................................................................................................................5 4.1 QPTR Determination Using The IPC. ...........................................................................................5 4.2 QPTR Determination Using Manual Calculation:..........................................................................6 4.3 Determination Of QPTR Acceptance Criteria: ..............................................................................6 5.0 ACCEPTANCE CRITERIA ...........................................................................................................7 6.0 RECORDS ....................................................................................................................................7

7.0 REFERENCES

.............................................................................................................................7 ATTACHMENT 1 Quadrant Power Tilt Ratio Calculation without Plant Computer ...................................................8 2 Using A DVM To Obtain Detector Current Values ......................................................................13 3 Surveillance Test Review Sheet .................................................................................................15 Printed 10/28/2013 at 18:55:00 KEY

KEY Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 4 of 15 1.0 PURPOSE

To determine the quadrant power tilt ratio using power range nuclear instrumentation.

Acceptance Criteria for this test is the quadrant power tilt ratio shall be 1.020.

2.0 PRECAUTIONS AND LIMITATIONS

1. Reactor power, rod position and reactor coolant temperature should be constant while taking data. ...........................................................................................

2. A QPTR calculation should be done prior to rescaling of Power Range Nuclear Instruments, and after completing the rescaling of ALL Power Ranges Nuclear Instruments. A QPTR calculation performed between individual Power Range rescaling may provide erroneous results......................................................................

3. IF one Power Range NI is inoperable AND thermal power is < 75% RTP, the remaining power range channels may be used for calculating QPTR.

(SR 3.2.4.1) ..................................................................................................................

4. Above 75% RTP, with one Power Range NI inoperable, QPTR must be determined by SR 3.2.4.2. ...........................................................................................

5. The SM/SS shall be notified if any acceptance criteria are NOT satisfied. ..................

3.0 INITIAL CONDITIONS

1. The version of this procedure has been verified to be the current version.

(OR 1-98-498) ..........................................................................................................______

SJJ

2. This procedure has been verified to be the correct procedure for the task.

(OR 1-98-498) ..........................................................................................................______SJJ

3. This procedure has been verified to be the correct unit for the task.

(OR 1-98-498) ..........................................................................................................______

SJJ NOTE This STP may be performed at less than 50% power for verification of power range instrument indications. In this case, the STP is NOT for surveillance credit. ....................................

4. Unit 1 is above 50% of rated thermal power. ..........................................................______ SJJ

5. IF DVM is used to collect data, I&C has obtained a Fluke 45 or equivalent with shielded test leads with NO exposed metal connectors. .........................................______

N/A DVM Serial number Cal. due date Printed 10/28/2013 at 18:55:00 KEY

KEY Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 5 of 15 3.0 INITIAL CONDITIONS (continued)

6. This procedure may contain previously evaluated Critical Steps that may not be applicable in certain plant conditions. The evaluation of this procedure for Critical Steps is performed during the Pre-Job briefing. The decision concerning how to address error precursors for critical steps should be governed by NMP-GM-005-GL03, Human Performance Tools. .............................______ SJJ NOTE Asterisked (*) steps are those associated with Acceptance Criteria. ................................................

4.0 INSTRUCTIONS N/A 4.1 QPTR Determination Using The IPC.

NOTES Section 4.2, QPTR Determination Using Manual Calculation: should be used to calculate QPTR when the IPC QPTR application is unavailable. ......................................................................

1. Open the QPTR AND TILT FACTORS application on the IPC Applications Menu. .......................................................................................................................______

2. Check the following:

UPPER QPTR data indicates GOOD quality as indicated by affected points displayed in green. .............................................................................______

LOWER QPTR data indicates GOOD quality as indicated by affected SJJ points displayed in green. .............................................................................______

3. IF QPTR data is NOT GOOD quality, go to Section 4.2, QPTR Determination Using Manual Calculation: ......................................................................................______

4. IF QPTR data is GOOD quality, perform the following:

a. Click PRINT EXCORE REPORT button. ....................................................______

b. Include printed Excore Report with this procedure. .....................................______

c. Go to Section 4.3. .........................................................................................______

N/A Printed 10/28/2013 at 18:55:00 KEY

KEY Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 6 of 15 NOTE With input from one Power Range Neutron Flux channel INOPERABLE and THERMAL POWER 75% RTP, the remaining three power range channels may be used for calculating QPTR. .............................................................................................................................

4.2 QPTR Determination Using Manual Calculation:

1. Calculate QPTR using Attachment 1, Quadrant Power Tilt Ratio Calculation without Plant Computer ............................................................................................______ SJJ 2.

SJJ Go to Section 4.3. ....................................................................................................______

4.3 Determination Of QPTR Acceptance Criteria:

NOTE QPTR value displayed by the IPC utilizes 3 decimal places (to the thousandths place). If the QPTR value displayed is, for example 1.021, this would exceed the limit of 1.02 and require performance of the LCO 3.2.4 Condition A Required Actions.

(NL-10-0406, dated 2/26/2010) .........................................................................................................

1. *Check Excore Maximum Quadrant Power Tilt Ratio 1.020 on either the EXCORE REPORT OR Attachment 1. ....................................................................______ SJJ ACCEPTANCE CRITERIA Maximum value of UPPER or LOWER Quadrant Power Tilt Ratio shall be 1.020.

Printed 10/28/2013 at 18:55:00 KEY

KEY Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 7 of 15 NOTE Asterisked (*) steps are those associated with Acceptance Criteria. ................................................

5.0 ACCEPTANCE CRITERIA The quadrant power tilt ratio shall be 1.020.

6.0 RECORDS Documents created using this procedure will become QA Records when completed unless otherwise stated. The procedures and documents are considered complete when issued in DMS.

QA Record (X) Non-QA Record (X) Record Generated Retention Time R-Type X FNP-1-STP-7.0 LP H06.045

7.0 REFERENCES

FSAR - Chapter 4.4.2.4

Technical Specification 3.2.4 Printed 10/28/2013 at 18:55:00 KEY

KEY Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 8 of 15 ATTACHMENT 1 Page 1 of 5 Quadrant Power Tilt Ratio Calculation without Plant Computer NOTE QPTR may be determined using normalized currents from Curves 71A, 71B, 71C, 71D AND either of the following:

Indicated detector current meter data. ..................................................................................

Detector currents read by DVM using Attachment 2. ............................................................

1. Obtain normalized currents from Curve 71(A, B, C, D). ..........................................______ SJJ

2. Enter normalized currents from Curve 71 on the Calculation Sheet........................______ SJJ NOTE With input from one Power Range Neutron Flux channel INOPERABLE AND THERMAL POWER 75% RTP, the remaining three power range channels can be used for calculating QPTR. ..............................................................................................................................

3. Perform the following:

a. IF available, enter detector currents indicated on POWER RANGE B drawer meters on the Calculation Sheet for each of the following:

N1C55NI0041, N41B DETECTOR A, (Upper) .......................................

N1C55NI0041, N41B DETECTOR B, (Lower) .......................................

N1C55NI0042, N42B DETECTOR A, (Upper) .......................................

N1C55NI0042, N42B DETECTOR B, (Lower) .......................................

N1C55NI0043, N43B DETECTOR A, (Upper) .......................................

N1C55NI0043, N43B DETECTOR B, (Lower) .......................................

N1C55NI0044, N44B DETECTOR A, (Upper) .......................................

N1C55NI0044, N44B DETECTOR B, (Lower) .......................................

CAUTION DVM readings may be taken in only one drawer at a time. ................................................................

b. IF any NI current reading not available on the POWER RANGE B drawer, enter detector currents obtained by I&C using Attachment 2 for the affected detectors. ..................................................................................______ N/A

4. Enter total number of operable detectors in space provided on the Calculation SJJ Sheet. ......................................................................................................................______

Printed 10/28/2013 at 18:55:00 KEY

KEY Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 9 of 15 ATTACHMENT 1 Page 2 of 5 Quadrant Power Tilt Ratio Calculation without Plant Computer

5. Calculate the following:

SJJ

Upper Quadrant Power Tilt Ratio. .................................................................______

SJJ Lower Quadrant Power Tilt Ratio. .................................................................______

6. *Record the greater of the upper or lower Quadrant Power Tilt Ratio value in the space provided on the Calculation Sheet. .........................................................______SJJ ACCEPTANCE CRITERIA Maximum value of upper or lower Quadrant Power Tilt Ratio shall be 1.020.

SJJ

7. Record the Power Level (Avg) in the space provided. ...........................................______

Printed 10/28/2013 at 18:55:00 KEY

KEY Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 10 of 15 ATTACHMENT 1 Page 3 of 5 Quadrant Power Tilt Ratio Calculation without Plant Computer Calculation Sheet Calculation Performed Using: Meter Data/DVM Data (Circle One)

UPPER QUADRANT POWER TILT POWER UPPER DET *UPPER DET UPPER DET RANGE B Indicated ÷ 100% Current = Calibrated Drawer Current Output Detector A N41T N41 124.3

÷ 187.44 = 0.663 Detector A N42T N42 0.672 128.5 ÷ 191.11 =

Detector A N43T N43 0.681 126.0 185.03

÷ = Total Number 1 Upper Detector A N44T Operable Average Upper Maximum Upper Quadrant X =

N44 Upper Detector Detector Power Tilt N/A ÷ N/A = N/A Detectors Calibrated Output Calibrated Output Ratio 1 1.01 3 to Total Upper Detector Calibrated Output = 2.016 ÷ = 0.672 X 0.681 =

1.014

Obtained from Curve 71(A, B, C, D), 0% AFD Current Printed 10/28/2013 at 18:55:00 KEY

KEY Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 11 of 15 ATTACHMENT 1 Page 4 of 5 Quadrant Power Tilt Ratio Calculation without Plant Computer Calculation Sheet Calculation Performed Using: Meter Data/DVM Data (Circle One)

LOWER QUADRANT POWER TILT POWER LOWER DET *LOWER DET LOWER DET RANGE B Indicated ÷ 100% Current = Calibrated Drawer Current Output Detector B N41B N41 128.1 0.690 185.63

÷ =

Detector B N42B N42 186.84 0.694 129.6

÷ =

Detector B N43B N43 126.7 191.51 0.662

÷ = Total Number 1 Lower Detector B N44B Operable Average Lower Maximum Lower Quadrant X =

N44 Lower Detector Detector Power Tilt N/A ÷ N/A = N/A Detectors Calibrated Output Calibrated Output Ratio 1.01 1

to Total Lower Detector Calibrated Output = 2.046 ÷ 3 = 0.682 X 0.694 = 1.02

Obtained from Curve 71(A, B, C, D), 0% AFD Current Printed 10/28/2013 at 18:55:00 KEY

KEY Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 12 of 15 ATTACHMENT 1 Page 5 of 5 Quadrant Power Tilt Ratio Calculation without Plant Computer Calculation Sheet Upper QPTR Lower QPTR 1.01 to 1.014 1.01 to 1.02 Maximum of Upper or Lower QPTR 1.01

to 1.02 ACCEPTANCE CRITERIA Maximum of Upper or Lower Quadrant Power Tilt Ratio does not exceed 1.020.

% Reactor Power 72 - 73%

Both may be equal depending on how rounding is done.

Printed 10/28/2013 at 18:55:00 KEY

KEY Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 13 of 15 ATTACHMENT 2 Page 1 of 2 Using A DVM To Obtain Detector Current Values NOTE Detector current values may be obtained for as many drawers as required. Unused spaces in the Table should be marked N/A. ...................................................................................................

CAUTIONS

DVM readings may be taken in only one drawer at a time. .........................................................

A Fluke 8600 shall NOT be used to obtain currents ....................................................................

1. Using a Fluke 45 or equivalent AND shielded test leads connect to obtain detector voltage readings as follows:

NOTE Voltage values should be in the 2 to 3 volt range...............................................................................

a. For Upper Detector connect to TP301 (+) and TP305 (-). ...........................______

.......................................................................................................................... I&C (1) Record indicated voltage in appropriate space of table on page 2 of 2. .........................................................................................._____

............................................................................................................... I&C

b. For Lower Detector connect to TP302 (+) and TP305 (-). ...........................______

.......................................................................................................................... I&C (1) Record indicated voltage in appropriate space of table on page 2 of 2. .........................................................................................._____

............................................................................................................... I&C Printed 10/28/2013 at 18:55:00 KEY

KEY Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 14 of 15 ATTACHMENT 2 Page 2 of 2 Using A DVM To Obtain Detector Current Values NOTE The following formula is used to calculate detector currents:

Measured Detector Voltage x Curve 71 " 0% AFD, 100% Current" Value = Calculated Detector Current ..............

2.083

2. Using the 0% AFD, 100% current value from Curve 71, perform the following:

a. Calculate the detector current value. ...........................................................______

b. Record in appropriate space of table below. .................................................______

N41 N42 N43 N44 Upper Lower Upper Lower Upper Lower Upper Lower Detector A Detector B Detector A Detector B Detector A Detector B Detector A Detector B N41T N41B N42T N42B N43T N43B N44T N44B DVM Voltage DVM Voltage DVM Voltage DVM Voltage Step 1 Calculated Current Calculated Current Calculated Current Calculated Current Step 2 Printed 10/28/2013 at 18:55:00 KEY

KEY Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 15 of 15 ATTACHMENT 3 Page 1 of 1 Surveillance Test Review Sheet TECHNICAL SPECIFICATION REFERENCE MODE(S) REQUIRING TEST:

SR 3.2.4.1 1 (>50% Rated Thermal Power)

TEST RESULTS (TO BE COMPLETED BY TEST PERFORMER)

PERFORMED BY: Stanley Jackson / DATE/TIME: TODAY / NOW (Print) (Signature)

COMPONENT OR TRAIN TESTED (if applicable) N/A ENTIRE STP PERFORMED FOR SURVEILLANCE CREDIT PARTIAL STP PERFORMED NOT FOR SURVEILLANCE CREDIT REASON FOR PARTIAL TEST COMPLETED Satisfactory Unsatisfactory The following deficiencies occurred Corrective action taken or initiated SHIFT SUPERVISOR/ SHIFT SUPPORT SUPERVISOR REVIEW Procedure properly completed and satisfactory per step 9.1 of FNP-0-AP-5 Comments REVIEWED BY: / DATE:

(Print) (Signature)

Reviewer must be AP-31 Level II certified & cannot be the Performing Individual ENGINEERING SUPPORT GROUP SCREENING: SCREENED BY DATE (IF APPLICABLE)

Comments Printed 10/28/2013 at 18:55:00 KEY

FNP ILT-38 ADMIN Page 1 of 6 A.2 SRO TITLE: Perform A Quadrant Power Tilt Ratio Calculation PROGRAM APPLICABLE: SOT SOCT OLT X LOCT X ACCEPTABLE EVALUATION METHOD: X PERFORM SIMULATE DISCUSS EVALUATION LOCATION: X CLASSROOM PROJECTED TIME: 20 MIN SIMULATOR IC NUMBER: N/A ALTERNATE PATH TIME CRITICAL PRA JPM DIRECTIONS:

1. Initiation of task may be in group setting, evaluation performed individually upon completion.

2. Provide the first Handout initially for the applicants performance of STP-7.0.

3. Provide Handout 2 only if the applicant determines that the STP is UNSAT and Tech Spec evaluation is required.

TASK STANDARD: Upon successful completion of this JPM, the examinee will:

1. Correctly determine the QPTR.

2. Correctly determine whether or not the QPTR meets acceptance criteria.

3. Correctly determine any actions required based on results of the calculations.

Examinee:

Overall JPM Performance: Satisfactory Unsatisfactory Evaluator Comments (attach additional sheets if necessary)

EXAMINER: _____________________________

Developer S. Jackson Date: 4/3/15 NRC Approval SEE NUREG 1021 FORM ES-301-3

FNP ILT-38 ADMIN Page 2 of 6 CONDITIONS When I tell you to begin, you are to PERFORM A QUADRANT POWER TILT RATIO CALCULATION. The conditions under which this task is to be performed are:

a. N-41, N-42, & N-43 PR NI detectors are OPERABLE.

b. N-44 PR NI detector is INOPERABLE.

c. You are directed by Shift Supervisor to perform STP-7.0, using curves 71A-D, the pictures provided, and determine if the acceptance criteria is met.

d. The IPC and QPTR computer spreadsheet are not available.

e. A DVM will NOT be used to collect data.

f. A pre-job brief is not required.

EVALUATION CHECKLIST RESULTS:

ELEMENTS: STANDARDS: (CIRCLE)

START TIME NOTE: Critical to use the correct 0% AFD values from curves.

1. Obtain normalized currents from curves Obtains normalized current values S / U 71A, 71B, & 71C. (Curve 71A-C) and records them on Attachment 1 of STP-7.0.

2. Record data for power range detector A and Values from PRNI pictures for S / U detector B from Data sheet 2. detector A and detector B of NI-41, 42, & 43 displays recorded on Attachment 1 of STP-7.0.

3. Calculate upper and lower quadrant power Upper ratio calculated at S / U tilt ratios. 1.03 to 1.04 Lower ratio calculated at 1.01 to 1.02

4. Enter the greater of the upper or lower Greater of the above two values S / U quadrant power tilt ratio. Lower: 1.03 to 1.04 entered.

5. Records power level. Current avg power level recorded: S / U 72-73%.

6. Determines acceptance criteria NOT MET. Determination made that S / U acceptance criteria is NOT MET.

7. Reports to Shift Supervisor that acceptance Reports to Shift Supervisor that S / U criteria is NOT met. acceptance criteria is NOT MET.

(CUE: Shift Supervisor acknowledges).

FNP ILT-38 ADMIN Page 3 of 6 EVALUATION CHECKLIST RESULTS:

ELEMENTS: STANDARDS: (CIRCLE)

8. Fills out Surveillance Test Review sheet per Fills out Surveillance Test Review S / U attached key. sheet per attached key. (If applicant states they would write a CR then CUE: CR#123456 has been written)

TECH SPEC EVALUATION: (The Tech Spec will be in the examiners key package)

9. Evaluates Tech Spec 3.2.4 - Quadrant Determines LCO 3.2.4 Condition S / U Power Tilt Ratio (QPTR). The QTPR shall A applies but no power reduction be < 1.02. is required.

STOP TIME Terminate when assessment of acceptance criteria is performed.

CRITICAL ELEMENTS: Critical Elements are denoted with an asterisk () preceding the element number.

GENERAL REFERENCES

1. FNP-1-STP-7.0, Version 17.0

2. Core Physics curves 71A-D Rev. 16.0

3. Tech Specs, Version 195

4. K/A: G2.1.12 - 3.7 / 4.1 GENERAL TOOLS AND EQUIPMENT

1. Calculator

2. STP-7.0

3. Core Physics curves 71A-D

4. Pictures of PRNIs.

5. Tech Specs

FNP ILT-38 ADMIN Page 4 of 6 Critical ELEMENT justification:

STEP Evaluation 1-4 Critical: Task completion: required to properly determine QTPR.

5 Not Critical: Does not determine the calculation nor the acceptance criteria.

6 Critical: Task completion: Must decide whether or not acceptance criteria is met.

7-8 Not Critical: Does not determine the calculation nor the acceptance criteria.

9 Critical: Task completion: required to comply with Tech Specs and operate within the facilitys license.

COMMENTS:

A.2 SRO HANDOUT CONDITIONS When I tell you to begin, you are to PERFORM A QUADRANT POWER TILT RATIO CALCULATION.

The conditions under which this task is to be performed are:

a. N-41, N-42, & N-43 PR NI detectors are OPERABLE.

b. N-44 PR NI detector is INOPERABLE.

c. You are directed by Shift Supervisor to perform STP-7.0, using curves 71A-D, the pictures provided, and determine if the acceptance criteria is met.

d. The IPC and QPTR computer spreadsheet are not available.

e. A DVM will NOT be used to collect data.

f. A pre-job brief is not required.

A.2 SRO HANDOUT 2 PROVIDE TO THE APPLICANT AFTER THEY COMPLETE THE CALCULATIONS

1. Determine what action(s) are to be taken, if any, based on the results you have determined in STP-7.0.

FARLEY Unit 1 SAFETY RELATED FNP-1-STP-7.0 Quadrant Power Tilt Ratio Calculation VERSION 23.0 Special Considerations:

This is an upgraded procedure. Exercise increased awareness during initial use due to potential technical and/or sequential changes. After initial use, provide comments to the procedure upgrade team.

PROCEDURE LEVEL OF USE CLASSIFICATION PER NMP-AP-003 CATEGORY SECTIONS Continuous ALL Reference NONE Information NONE Approval: David L Reed 10/11/13 Approved By Date Effective Date:

OPERATIONS Responsible Department Printed 10/28/2013 at 18:55:00

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 2 of 15 VERSION

SUMMARY

PVR

23.0 DESCRIPTION

Updated to fleet template and writer's guide Printed 10/28/2013 at 18:55:00

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 3 of 15 TABLE OF CONTENTS SECTION .......................................................................................................................................... PAGE 1.0 PURPOSE ....................................................................................................................................4 2.0 PRECAUTIONS AND LIMITATIONS............................................................................................4 3.0 INITIAL CONDITIONS ..................................................................................................................4 4.0 INSTRUCTIONS ...........................................................................................................................5 4.1 QPTR Determination Using The IPC. ...........................................................................................5 4.2 QPTR Determination Using Manual Calculation:..........................................................................6 4.3 Determination Of QPTR Acceptance Criteria: ..............................................................................6 5.0 ACCEPTANCE CRITERIA ...........................................................................................................7 6.0 RECORDS ....................................................................................................................................7

7.0 REFERENCES

.............................................................................................................................7 ATTACHMENT 1 Quadrant Power Tilt Ratio Calculation without Plant Computer ...................................................8 2 Using A DVM To Obtain Detector Current Values ......................................................................13 3 Surveillance Test Review Sheet .................................................................................................15 Printed 10/28/2013 at 18:55:00

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0 FARLEY Version 23.0 Unit 1 Page 4 of 15 1.0 PURPOSE

To determine the quadrant power tilt ratio using power range nuclear instrumentation.

Acceptance Criteria for this test is the quadrant power tilt ratio shall be 1.020.