Text

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

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% - YES BOTH INT RNG SUR ZERO OR NEGATIVE - NO Determines that an Orange condition exists to go to FRP-S.1. S / U

2. Evaluate CSF-0.2. FIFTH HOTTEST CORE EXIT TC LESS THAN 1200°F - YES RCS SUBCOOLING FROM CORE EXIT TC'S GRTR THAN 16°F{45°F} - YES Determines that this CSF is SAT. S / U 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 ONE SG GRTR THAN 31%{48%} - NO TOTAL AFW FLOW TO ALL SG'S GRTR THAN 395 GPM - YES PRESS IN ALL SG'S LESS THAN 1129 PSIG - YES NAR RNG LVL IN ALL SG'S LESS THAN 82% - YES PRESS IN ALL SG'S LESS THAN 1075 PSIG - YES NAR RNG LVL IN ALL SG'S GRTR THAN 31% - NO Determines that a Yellow condition exists to go to FRP-H.5. S / U

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 Parameter INSTRUMENT Channel I or Train A Channel II or Train B Channel III Channel IV 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 in TMAX mode 329°F 325°F 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 Parameter RCS Loop 2A RCS Loop 2B RCS Loop 2C SG NR Level (all channels) 20% 0% 20% AFW flow 325 GPM 0 GPM 340 GPM SG Pressure (all channels) 800 psig 25 psig 820 psig RCS WR Cold Leg Temperature 420°F 265°F 425°F RCP status Off Off Off UNIT 28/29/200708:33JimL.Hunter(for)09/14/07 UNIT 2UNIT28/29/200708:33 UNIT 2UNIT28/29/200708:33 UNIT 2UNIT28/29/200708:33 FNP-2-CSF-0.1SUBCRITICALITYRevision 12Page 1 of 1POWER RNGLESS THAN 5%NOYESBOTH INTRNG SURZERO OR NEGATIVENOYESBOTHSOURCE RNGENERGIZEDNOYESBOTH SOURCE RNG SUR ZEROORNEGATIVENOYESBOTH INTRNG SURMORE NEGATIVE THAN -0.2DPMNOYESGO TOFRP-S.1GO TOFRP-S.1GO TOFRP-S.2CSFSATCSFSATGO TOFRP-S.2UNIT 28/29/200708:33 FNP-2-CSF-0.2CORE COOLINGRevision 12Page 1 of 1FIFTHHOTTESTCORE EXIT TC LESSTHAN1200FNOYESFIFTH HOTTEST CORE EXITTC LESSTHAN 700°NOYESRCSSUBCOOLINGFROM CORE EXIT TC'S GRTR THAN16° F {45° F}NOYESGO TOFRP-C.1GO TOFRP-C.2GO TOFRP-C.3CSFSATUNIT 2UNIT2UNIT28/29/200708:33 FNP-2-CSF-0.3HEAT SINKRevision 12Page 1 of 1NAR RNGLVL IN ATLEAST ONESG GRTRTHAN 31%{48%}NOYESTOTAL AFWFLOW TOALL SG'SGRTR THAN395 GPMNOYESPRESS INALL SG'SLESS THAN1129 PSIGNOYESNAR RNGLVL IN ALLSG'S LESSTHAN 82%NOYESPRESS INALL SG'SLESS THAN1075 PSIGNOYESNAR RNGLVL IN ALLSG'S GRTRTHAN 31%{48%}NOYESGO TOFRP-H.1GO TOFRP-H.2GO TOFRP-H.3GO TOFRP-H.4GO TOFRP-H.5CSFSATUNIT2UNIT28/29/200708:33 FNP-2-CSF-0.4INTEGRITYRevision 12Page 1 of 2LIMIT ARCS PRESSURE (PSIG)COLD LEG TEMPERATURE (°F)022002560235270285315TEMP DECRIN ALL CL IN LAST 60 MIN LESS THAN 100° FNOYESALL RCS CL TEMPS IN LAST 60 MINGRTR THAN315° FNOYESALL RCS CL TEMPS IN LAST 60 MIN GRTR THAN 285° FNOYESALL RCSPRESS --CL TEMP (INLAST 60 MIN)POINTS TORIGHT OF LIMIT ANOYESALL RCS CLTEMPS GRTR THAN 285° FNOYESRCS PRESSLESS THAN 450 PSIGNOYESALL RCSTEMPS GRTR THAN 325° FNOYESGO TOFRP-P.1GO TOFRP-P.1GO TOFRP-P.2CSFSATGO TOFRP-P.1GO TOFRP-P.2CSF SATCSFSATUNIT 2UNIT2UNIT28/29/200708:33 FNP-2-CSF-0.4INTEGRITYRevision 12Page 2 of 2050010001500 2000 2500 3000200225250275300325350235270285RCS WIDE RANGE PRESSURE(PSIG)RCS COLD LEG WIDE RANGETEMPERATURE (°F)LIMIT ALIMIT AINTEGRITYRED PATHREGIONINTEGRITYORANGE PATHREGIONINTEGRITYYELLOW PATHREGIONINTEGRITYGREEN PATHREGION22002560INTEGRITYRCS PRESSURE - TEMPERATURE CRITERIA315UNIT 2UNIT2UNIT28/29/200708:33 FNP-2-CSF-0.5CONTAINMENTRevision 12Page 1 of 1CTMTPRESSLESSTHAN 27PSIGNOYESCTMTSUMP LVLLESS THAN 7.6FT.NOYESBOTHCTMT RADLESSTHAN 2 R/

hr.NOYESGO TOFRP-Z.1GO TOFRP-Z.1GO TOFRP-Z.2GO TOFRP-Z.3CSFSATCTMTPRESSLESSTHAN 54 PSIGNOYESAt LEAST ONE CTMT SPRAYPUMP RUNNING(FLOW>1000 GPM)NOYESGO TOFRP-Z.1CTMTSUMP LVLLESS THAN 7.6FT.NOYESGO TOFRP-Z.2UNIT 2UNIT2UNIT28/29/200708:33 FNP-2-CSF-0.6INVENTORYRevision 12Page 1 of 1PRZR LVLLESS THAN92%NOYESPRZR LVLGRTR THAN 15%NOYESALL UPPER HEAD AND PLENUMLVLS EQUAL100%NOYESALL UPPER HEAD AND PLENUMLVLS EQUAL100%NOYESGO TOFRP-I.3GO TOFRP-I.1GO TOFRP-I.2GO TOFRP-I.3CSFSATUNIT 2UNIT2UNIT28/29/200708:33 UNIT 28/29/200708:33JimL.Hunter(for)09/14/07 UNIT 2UNIT28/29/200708:33 UNIT 2UNIT28/29/200708:33 UNIT 2UNIT28/29/200708:33 FNP-2-CSF-0.1SUBCRITICALITYRevision 12Page 1 of 1POWER RNGLESS THAN 5%NOYESBOTH INTRNG SURZERO OR NEGATIVENOYESBOTHSOURCE RNGENERGIZEDNOYESBOTH SOURCE RNG SUR ZEROORNEGATIVENOYESBOTH INTRNG SURMORE NEGATIVE THAN -0.2DPMNOYESGO TOFRP-S.1GO TOFRP-S.1GO TOFRP-S.2CSFSATCSFSATGO TOFRP-S.2UNIT 28/29/200708:33 FNP-2-CSF-0.2CORE COOLINGRevision 12Page 1 of 1FIFTHHOTTESTCORE EXIT TC LESSTHAN1200FNOYESFIFTH HOTTEST CORE EXITTC LESSTHAN 700°NOYESRCSSUBCOOLINGFROM CORE EXIT TC'S GRTR THAN16° F {45° F}NOYESGO TOFRP-C.1GO TOFRP-C.2GO TOFRP-C.3CSFSATUNIT 2UNIT2UNIT28/29/200708:33 FNP-2-CSF-0.3HEAT SINKRevision 12Page 1 of 1NAR RNGLVL IN ATLEAST ONESG GRTRTHAN 31%{48%}NOYESTOTAL AFWFLOW TOALL SG'SGRTR THAN395 GPMNOYESPRESS INALL SG'SLESS THAN1129 PSIGNOYESNAR RNGLVL IN ALLSG'S LESSTHAN 82%NOYESPRESS INALL SG'SLESS THAN1075 PSIGNOYESNAR RNGLVL IN ALLSG'S GRTRTHAN 31%{48%}NOYESGO TOFRP-H.1GO TOFRP-H.2GO TOFRP-H.3GO TOFRP-H.4GO TOFRP-H.5CSFSATUNIT2UNIT28/29/200708:33 FNP-2-CSF-0.4INTEGRITYRevision 12Page 1 of 2LIMIT ARCS PRESSURE (PSIG)COLD LEG TEMPERATURE (°F)022002560235270285315TEMP DECRIN ALL CL IN LAST 60 MIN LESS THAN 100° FNOYESALL RCS CL TEMPS IN LAST 60 MINGRTR THAN315° FNOYESALL RCS CL TEMPS IN LAST 60 MIN GRTR THAN 285° FNOYESALL RCSPRESS --CL TEMP (INLAST 60 MIN)POINTS TORIGHT OF LIMIT ANOYESALL RCS CLTEMPS GRTR THAN 285° FNOYESRCS PRESSLESS THAN 450 PSIGNOYESALL RCSTEMPS GRTR THAN 325° FNOYESGO TOFRP-P.1GO TOFRP-P.1GO TOFRP-P.2CSFSATGO TOFRP-P.1GO TOFRP-P.2CSF SATCSFSATUNIT 2UNIT2UNIT28/29/200708:33 FNP-2-CSF-0.4INTEGRITYRevision 12Page 2 of 2050010001500 2000 2500 3000200225250275300325350235270285RCS WIDE RANGE PRESSURE(PSIG)RCS COLD LEG WIDE RANGETEMPERATURE (°F)LIMIT ALIMIT AINTEGRITYRED PATHREGIONINTEGRITYORANGE PATHREGIONINTEGRITYYELLOW PATHREGIONINTEGRITYGREEN PATHREGION22002560INTEGRITYRCS PRESSURE - TEMPERATURE CRITERIA315UNIT 2UNIT2UNIT28/29/200708:33 FNP-2-CSF-0.5CONTAINMENTRevision 12Page 1 of 1CTMTPRESSLESSTHAN 27PSIGNOYESCTMTSUMP LVLLESS THAN 7.6FT.NOYESBOTHCTMT RADLESSTHAN 2 R/

hr.NOYESGO TOFRP-Z.1GO TOFRP-Z.1GO TOFRP-Z.2GO TOFRP-Z.3CSFSATCTMTPRESSLESSTHAN 54 PSIGNOYESAt LEAST ONE CTMT SPRAYPUMP RUNNING(FLOW>1000 GPM)NOYESGO TOFRP-Z.1CTMTSUMP LVLLESS THAN 7.6FT.NOYESGO TOFRP-Z.2UNIT 2UNIT2UNIT28/29/200708:33 FNP-2-CSF-0.6INVENTORYRevision 12Page 1 of 1PRZR LVLLESS THAN92%NOYESPRZR LVLGRTR THAN 15%NOYESALL UPPER HEAD AND PLENUMLVLS EQUAL100%NOYESALL UPPER HEAD AND PLENUMLVLS EQUAL100%NOYESGO TOFRP-I.3GO TOFRP-I.1GO TOFRP-I.2GO TOFRP-I.3CSFSATUNIT 2UNIT2UNIT28/29/200708:33 FNP ILT-38 ADMIN Page 1 of 6 Developer S. Jackson Date: 4/2/15 NRC Approval SEE NUREG 1021 FORM ES-301-3 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:

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 RHR INTAKE FLOW To Minimize Vortexing to determine maximum allowable RHR flowrate. 1) Step 7 of AOP-12.0, 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. RCS level is 122' 8.5".

Determines that maximum RHR flow is < 1750 gpm. Allowable tolerance: < 1600 -1800 gpm. S / U 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 appropriate table of ATTACHMENT 3, TABLE A or TABLE B. 2) ATTACHMENT 3, step 1.1. 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. S / U

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

4. Determine time to core saturation, determine appropriate column of ATTACHMENT 3, TABLE B , ASSUMED INITIAL TEMPERATURE = 120°F : Time to Saturation at midloop (mins)

Time to Saturation 3' below flange (mins)

Time to Saturation full Rx cavity (hours) 4) ATTACHMENT 3, step 1.2. Determines that page from , TABLE B for ASSUMED INITIAL TEMPERATURE = 120°F , column for Time to Saturation at midloop (mins) is required. S / U 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 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 S / U 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 FNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0FIGURE 1FIGURE 1RCS HOT LEG LEVEL vs RHR INTAKE FLOW To Minimize VortexingRCS HOT LEG LEVEL vs RHR INTAKE FLOW To Minimize VortexingRCS HOT LEG LEVEL vs RHR INTAKE FLOWRCS HOT LEG LEVEL vs RHR INTAKE FLOWTo Minimize VortexingTo Minimize Vortexing Page 1 of 1Page 1 of 13/15/201300:29UNIT 1 FNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 3ATTACHMENT 3Time to Core SaturationTime to Core Saturation111Time to Core Saturation:Time to Core Saturation:Time to Core Saturation:1.11.1Tables A and B provide estimates of the time to core boilingTables A and B provide estimates of the time to core boilingfollowing a loss RHR capability for two cases:following a loss RHR capability for two cases:1.1.11.1.1TABLE ATABLE ATABLE A provides a Time to Saturation as a function of time after provides a Time to Saturation as a function of time aftershutdown for a full core immediately after shutdown for ashutdown for a full core immediately after shutdown for arefueling.refueling.1.1.21.1.2TABLE BTABLE BTABLE B provides a Time to Saturation as a function of time after provides a Time to Saturation as a function of time aftershutdown for a core in which one third of the spent fuel has beenshutdown for a core in which one third of the spent fuel has beenreplaced with new fuel.replaced with new fuel.1.21.2Both cases are evaluated for conditions when RCS level is at mid loopBoth 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(122'9"), at three feet below the reactor flange (126'7"), and whenthe reactor cavity is full.the reactor cavity is full.1.31.3Both cases are also evaluated for three assumed initial temperatures:Both cases are also evaluated for three assumed initial temperatures:100100F, 120F, 120F, and 140F, and 140F.F.1.41.4These figures can be used to estimate the amount of time availableThese figures can be used to estimate the amount of time availablefor operator action to restore RHR before additional protectivefor operator action to restore RHR before additional protectivemeasures must be taken.measures must be taken.Page 1 of 7Page 1 of 73/15/201300:29UNIT 1 FNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 3ATTACHMENT 3Time to Core SaturationTime to Core Saturation TABLE BTABLE BTABLE B---POWER UPRATED UNIT---POWER UPRATED UNIT TIME TO SATURATION: ONE THIRD NEW FUEL TIME TO SATURATION: ONE THIRD NEW FUEL ASSUMED INITIAL TEMPERATURE= ASSUMED INITIAL TEMPERATURE=120120FF Time After Time After Time to Saturation Time to Saturation Time to Saturation Time to Saturation Time to SaturationTime to SaturationShutdown (hours)Shutdown (hours)at midloop (mins) at midloop (mins) 3' below flange 3' below flange full Rx cavity full Rx cavity (mins) (mins) (hours) (hours) 100 100 12.8 12.8 17.5 17.5 9.2 9.2 200 200 17.1 17.1 23.4 23.4 12.4 12.4 300 300 20.2 20.2 27.6 27.6 14.6 14.6 400 400 22.5 22.5 30.8 30.8 16.3 16.3 500 500 25.4 25.4 34.8 34.8 18.4 18.4 600 600 28.3 28.3 38.7 38.7 20.5 20.5 700 700 30.5 30.5 41.7 41.7 22.1 22.1 800 800 33.0 33.0 45.2 45.2 23.9 23.9 VOLUME REFERENCE TABLE VOLUME REFERENCE TABLEMIDLOOP VOLUME(FTMIDLOOP VOLUME(FT33) ) 945 945 VOLUME 3FT BELOW FLANGE(FTVOLUME 3FT BELOW FLANGE(FT33) ) 348 348 TOTAL= TOTAL= 1293 1293 VOLUME FULL REACTOR CAVITY(FTVOLUME FULL REACTOR CAVITY(FT33) ) 39750 39750 TOTAL= TOTAL= 41043 41043 Page 6 of 7Page 6 of 73/15/201300:29UNIT 1 FNP-1-AOP-12.0FNP-1-AOP-12.01-02-20131-02-2013Revision 25.0Revision 25.0FARLEY NUCLEAR PLANTFARLEY NUCLEAR PLANTABNORMAL OPERATING PROCEDUREABNORMAL OPERATING PROCEDUREFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTION S S A A FF PROCEDURE USAGE REQUIREMENTS per NMP-AP-003 PROCEDURE USAGE REQUIREMENTS per NMP-AP-003 SECTIONS SECTIONS EE TTContinuous UseContinuous UseContinuous Use ALL ALL YY Reference UseReference UseReference Use RR EEInformation UseInformation UseInformation Use LL AA T T E E D D Approved:Approved: Operations ManagerOperations ManagerDate Issued:Date Issued: 3/15/201300:29UNIT 1DavidLReed(for)01/28/13 FNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0 TABLE OF CONTENTS TABLE OF CONTENTSProcedure ContainsProcedure ContainsNumber of PagesNumber of Pages Body................................... Body................................... 2424Figure 1...............................Figure 1...............................11Attachment 1...........................Attachment 1...........................99Attachment 2...........................Attachment 2...........................44Attachment 3...........................Attachment 3...........................77Attachment 4...........................Attachment 4...........................11Page 1 of 1Page 1 of 13/15/201300:29UNIT 1 FNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0A.A.A.PurposePurposePurposeThis procedure provides actions for response to a malfunction of theThis procedure provides actions for response to a malfunction of theRHR system.RHR system.Actions in this procedure for restoring RHR PUMPs assume electricalActions in this procedure for restoring RHR PUMPs assume electricalpower is available. During loss of electrical power conditions,power is available. During loss of electrical power conditions,FNP-1-AOP-5.0, LOSS OF A OR B TRAIN ELECTRICAL POWER, provides actionsFNP-1-AOP-5.0, LOSS OF A OR B TRAIN ELECTRICAL POWER, provides actionsfor restoration of electrical power which should be performed infor restoration of electrical power which should be performed inaddition to continuing with this procedure.addition to continuing with this procedure.The first part of this procedure deals with the protection of anyThe first part of this procedure deals with the protection of anyrunning RHR pump and isolation of any leakage. If a running train isrunning RHR pump and isolation of any leakage. If a running train ismaintained the procedure is exited. Credit may be taken for RCS Loopsmaintained the procedure is exited. Credit may be taken for RCS Loopsproviding core cooling in place of a running train of RHR. The nextproviding core cooling in place of a running train of RHR. The nextportion deals with restoring a train of RHR while monitoring coreportion deals with restoring a train of RHR while monitoring coretemperatures. If a train cannot be restored actions are taken fortemperatures. If a train cannot be restored actions are taken forprotection of personnel, establishing containment closure, andprotection of personnel, establishing containment closure, andprovides alternate methods of decay heat removal while trying toprovides alternate methods of decay heat removal while trying torestore a train of RHR. Alternate cooling methods include: restore a train of RHR. Alternate cooling methods include: establishing a secondary heat sink if steam generators are available;establishing a secondary heat sink if steam generators are available;feed and bleed cooling and feed and spill cooling.feed and bleed cooling and feed and spill cooling.The intent of feed and bleed cooling is to regain pressurizer levelThe intent of feed and bleed cooling is to regain pressurizer leveland allow steaming through a bleed path to provide core cooling. Thisand allow steaming through a bleed path to provide core cooling. Thisrequires that the RCS be in a configuration that will allow a level inrequires that the RCS be in a configuration that will allow a level inthe pressurizer. the pressurizer. The intent of feed and spill cooling is to allow spillage from the RCSThe intent of feed and spill cooling is to allow spillage from the RCSand locally throttle injection flow to provide core cooling. Thisand locally throttle injection flow to provide core cooling. Thismethod is used when the reactor vessel head is blocked or RCS loopmethod is used when the reactor vessel head is blocked or RCS loopopenings exist.openings exist.This procedure is applicable in modes 4, 5 and 6.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 theContainment 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 theinitiating event unless an operable RHR pump is placed in serviceinitiating event unless an operable RHR pump is placed in servicecooling the RCS cooling the RCS ANDAND the RCS temperature is below 180 the RCS temperature is below 180F.F.Page 1 of 24Page 1 of 243/15/201300:29UNIT 1 FNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0B.B.B.Symptoms or Entry ConditionsSymptoms or Entry ConditionsSymptoms or Entry Conditions111This procedure is entered when a malfunction of the RHR system isThis procedure is entered when a malfunction of the RHR system isThis procedure is entered when a malfunction of the RHR system isindicated by any of the following:indicated by any of the following:indicated by any of the following:1.11.1Trip of any operating RHR pumpTrip of any operating RHR pump1.21.2Excessive RHR system leakageExcessive RHR system leakage1.31.3Evidence of running RHR pump cavitationEvidence of running RHR pump cavitation1.41.4Closure of loop suction valveClosure of loop suction valve1.51.5High RCS or core exit T/C temperatureHigh RCS or core exit T/C temperature1.61.6Procedure could be entered from various annunciator responseProcedure could be entered from various annunciator responseprocedures.procedures.CF3 1A CF3 1A OROR 1B RHR PUMP OVERLOAD TRIP 1B RHR PUMP OVERLOAD TRIP CF4 1A RHR HX OUTLET FLOW LOCF4 1A RHR HX OUTLET FLOW LOCF5 1B RHR HX OUTLET FLOW LOCF5 1B RHR HX OUTLET FLOW LOCG3 1A CG3 1A OROR 1B RHR HX CCW DISCH FLOW HI 1B RHR HX CCW DISCH FLOW HIEA5 1A EA5 1A OROR 1B RHR PUMP CAVITATION 1B RHR PUMP CAVITATIONEB5 MID-LOOP CORE EXIT TEMP HIEB5 MID-LOOP CORE EXIT TEMP HIEC5 RCS LVL HI-LOEC5 RCS LVL HI-LO Page 2 of 24Page 2 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0****************************************************************************************************************************************************************************CAUTIONCAUTION::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 theContainment 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 theinitiating event unless an operable RHR pump is placed in serviceinitiating event unless an operable RHR pump is placed in servicecooling the RCS cooling the RCS ANDAND the RCS temperature is below 180 the RCS temperature is below 180F.F.********************************************************************************************************************************************************************************************************************************************************************************************************************************************************CAUTIONCAUTION::Filling the pressurizer to 100% will cause a loss of nozzle dams dueFilling the pressurizer to 100% will cause a loss of nozzle dams dueto the head of water.to the head of water.****************************************************************************************************************************************************************************NOTE:NOTE:RCS to RHR loop suction valves will be deenergized if RCS TAVG isRCS to RHR loop suction valves will be deenergized if RCS TAVG isless than 180less than 180F.F. 111Check RHR loop suction valves -Check RHR loop suction valves -Check RHR loop suction valves -11Stop any RHR PUMP with closedStop any RHR PUMP with closedOPEN.OPEN.OPEN.loop suction valve(s).loop suction valve(s).1.11.1IFIF required, required, RHR PUMP RHR PUMP 1A 1A 1B 1B THENTHEN adjust charging flow to adjust charging flow tomaintain RCS level.maintain RCS level.1C(1A) RCS LOOP 1C(1A) RCS LOOP TO 1A(1B) RHR PUMP TO 1A(1B) RHR PUMP Q1E11MOV Q1E11MOV [] 8701A[] 8701A[] 8702A[] 8702A [] 8701B[] 8701B[] 8702B[] 8702B1C(1A) RCS LOOP 1C(1A) RCS LOOP TO 1A(1B) RHR PUMP TO 1A(1B) RHR PUMP [] FU-T5[] FU-T5[] FU-G2[] FU-G2LOOP SUCTION POWER LOOP SUCTION POWER [] FV-V2[] FV-V2[] FV-V3[] FV-V3SUPPLY BREAKERS SUPPLY BREAKERS CLOSED(CLOSED(IFIF REQUIRED) REQUIRED) 222IFIFIF the standby RHR train is the standby RHR train is the standby RHR train is NOTNOTNOT22IFIF core cooling provided by the core cooling provided by theaffected affected affected ANDANDAND plant conditions plant conditions plant conditionsSGs, SGs, permit operation, permit operation, permit operation, THENTHEN proceed to step 8. proceed to step 8.THENTHENTHEN place the standby RHR place the standby RHR place the standby RHRtrain in service pertrain in service pertrain in service perFNP-1-SOP-7.0, RESIDUAL HEATFNP-1-SOP-7.0, RESIDUAL HEATFNP-1-SOP-7.0, RESIDUAL HEATREMOVAL SYSTEM.REMOVAL SYSTEM.REMOVAL SYSTEM.Page 3 of 24Page 3 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0NOTE:NOTE:Rapid flow adjustments may cause more severe pump cavitation.Rapid flow adjustments may cause more severe pump cavitation. 333Check RHR PUMPs - NOTCheck RHR PUMPs - NOTCheck RHR PUMPs - NOT33Perform the following:Perform the following:CAVITATING.CAVITATING.CAVITATING.3.13.1Slowly reduce RHR flow rate toSlowly reduce RHR flow rate toThe following parameters shouldThe following parameters shouldeliminate cavitation.eliminate cavitation.be stable and within normalbe stable and within normalranges.ranges.3.23.2IFIF cavitation CANNOT be cavitation CANNOT be[][]RHR flow rate within theRHR flow rate within theeliminated, eliminated, Acceptable Operating Region ofAcceptable Operating Region ofTHENTHEN stop the affected RHR stop the affected RHRFIGURE 1, RCS HOT LEG LEVEL vsFIGURE 1, RCS HOT LEG LEVEL vspump(s).pump(s).RHR INTAKE FLOW To MinimizeRHR INTAKE FLOW To MinimizeVortexing.Vortexing.[][]Discharge pressureDischarge pressure[][]Suction pressureSuction pressure[][]RHR motor ammeter readingsRHR motor ammeter readings[][]No unusual pump noiseNo unusual pump noise 444Check any RHR PUMP - RUNNINGCheck any RHR PUMP - RUNNINGCheck any RHR PUMP - RUNNING44Proceed to step 13.Proceed to step 13. 555Verify RHR flow > 3000 gpm.Verify RHR flow > 3000 gpm.Verify RHR flow > 3000 gpm.55Refer to TechnicalRefer to TechnicalSpecifications 3.9.4 and 3.9.5Specifications 3.9.4 and 3.9.51A(1B)1A(1B)for applicability.for applicability.RHR HDR FLOWRHR HDR FLOW[][]FI 605AFI 605A[][]FI 605BFI 605BPage 4 of 24Page 4 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0****************************************************************************************************************************************************************************CAUTIONCAUTION::Indicated RCS level will rise approximately 1 ft for every 0.5 psiIndicated RCS level will rise approximately 1 ft for every 0.5 psirise in RCS pressure if the indication is not pressure compensated.rise in RCS pressure if the indication is not pressure compensated.********************************************************************************************************************************************************************************************************************************************************************************************************************************************************CAUTIONCAUTION::Only borated water should be added to the RCS to maintain adequateOnly borated water should be added to the RCS to maintain adequateshutdown margin.shutdown margin.**************************************************************************************************************************************************************************** 666Check RCS level ADEQUATECheck RCS level ADEQUATECheck RCS level ADEQUATE6.16.1Compare any available levelCompare any available levelindications.indications.[][]LT 2965A&B/level hoseLT 2965A&B/level hose[][]LI-2384 1B LOOP RCS NR LVLLI-2384 1B LOOP RCS NR LVL[][]LI-2385 1C LOOP RCS NR LVLLI-2385 1C LOOP RCS NR LVL[][]Temporary remote levelTemporary remote levelindicator off of a RCS FT on Aindicator off of a RCS FT on Aor C loopor C loop6.26.2Check RCS level within theCheck RCS level within the6.26.2Raise RCS level.Raise RCS level.Acceptable Operating Region ofAcceptable Operating Region ofFIGURE 1, RCS HOT LEG LEVEL vsFIGURE 1, RCS HOT LEG LEVEL vs6.2.16.2.1Notify personnel inNotify personnel inRHR INTAKE FLOW To MinimizeRHR INTAKE FLOW To Minimizecontainment that RCS levelcontainment that RCS levelVortexing.Vortexing.will be raised.will be raised.6.2.26.2.2Align TechnicalAlign TechnicalRequirements ManualRequirements Manualboration flow path.boration flow path.6.2.36.2.3Raise RCS level to withinRaise RCS level to withinthe Acceptable Operatingthe Acceptable OperatingRegion of FIGURE 1, RCS HOTRegion of FIGURE 1, RCS HOTLEG LEVEL vs RHR INTAKELEG LEVEL vs RHR INTAKEFLOW To Minimize VortexingFLOW To Minimize Vortexingfor the existing RHR flow.for the existing RHR flow.Page 5 of 24Page 5 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0 777Maintain RCS level within theMaintain RCS level within theMaintain RCS level within the77Verify RHR PUMP(s) stopped Verify RHR PUMP(s) stopped ANDANDfollowing limits:following limits:following limits:proceed to step 13.proceed to step 13.[][]Maintain RCS level to withinMaintain RCS level to withinthe Acceptable Operating Regionthe Acceptable Operating Regionof FIGURE 1, RCS HOT LEG LEVELof FIGURE 1, RCS HOT LEG LEVELvs RHR INTAKE FLOW To Minimizevs RHR INTAKE FLOW To MinimizeVortexing for the existing RHRVortexing for the existing RHRflow.flow.[][]Maintain RCS level less thanMaintain RCS level less than123 ft 4 in if personnel are in123 ft 4 in if personnel are inthe channel heads withoutthe channel heads withoutnozzle dams installed.nozzle dams installed.[][]Maintain RCS level less thanMaintain RCS level less than123 ft 9 in if primary manways123 ft 9 in if primary manwaysare removed without nozzle damsare removed without nozzle damsinstalled.installed.[][]Maintain RCS level less thanMaintain RCS level less than123 ft 9 in if seal injection123 ft 9 in if seal injectionis not established and RCPs areis not established and RCPs arenot backseated.not backseated.[][]Maintain RCS level less thanMaintain RCS level less than124 ft if safety injection124 ft if safety injectioncheck valves are disassembled.check valves are disassembled.Page 6 of 24Page 6 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0****************************************************************************************************************************************************************************CAUTIONCAUTION::IFIF the leaking RHR train can the leaking RHR train can NOTNOT be identified, be identified, THENTHEN both trains both trainsshould be assumed leaking.should be assumed leaking.**************************************************************************************************************************************************************************** 888Check RHR system - INTACTCheck RHR system - INTACTCheck RHR system - INTACT88Isolate RHR leakage.Isolate RHR leakage.[][]Stable RCS level.Stable RCS level.8.18.1Isolate affected RHR train(s)Isolate affected RHR train(s)[][]No unexpected rise inNo unexpected rise infrom RCS.from RCS.containment sump level.containment sump level.[][]No RHR HX room sump levelNo RHR HX room sump level8.1.18.1.1Stop affected RHR pump(s).Stop affected RHR pump(s).rising.rising.[][]No RHR pump room sump levelNo RHR pump room sump level8.1.28.1.2Verify closed affected RHRVerify closed affected RHRrising.rising.train valves.train valves.[][]No waste gas processing roomNo waste gas processing roomsump level risingsump level rising[][]No rising area radiationNo rising area radiationAffected RHR Train Affected RHR Train A A B B monitormonitor[][]No unexplained rise in PRTNo unexplained rise in PRT1C(1A) RCS LOOP 1C(1A) RCS LOOP level or temperature.level or temperature.TO 1A(1B) RHR PUMP TO 1A(1B) RHR PUMP [] 8701A[] 8701A[] 8702A[] 8702AQ1E11MOV Q1E11MOV [] 8701B[] 8701B[] 8702B[] 8702B 1C(1A) RCS LOOP 1C(1A) RCS LOOP TO 1A(1B) RHR PUMP TO 1A(1B) RHR PUMP [] FU-T5[] FU-T5[] FU-G2[] FU-G2LOOP SUCTION POWER LOOP SUCTION POWER [] FV-V2[] FV-V2[] FV-V3[] FV-V3SUPPLY BREAKERS SUPPLY BREAKERS CLOSED CLOSED 1A(1B) RHR HX TO RCS1A(1B) RHR HX TO RCS COLD LEGS ISO COLD LEGS ISO [] 8888A[] 8888A[] 8888B[] 8888BQ1E11MOV Q1E11MOV 1A(1B) RHR TO RCS 1A(1B) RHR TO RCS HOT LEGS XCON HOT LEGS XCON [] 8887A[] 8887A[] 8887B[] 8887BQ1E11MOV Q1E11MOV 8.28.2Isolate source of any RHR/RCSIsolate source of any RHR/RCSleakage.leakage. 999Check core cooling provided byCheck core cooling provided byCheck core cooling provided by99Proceed to step 13.Proceed to step 13.RHR or SGs.RHR or SGs.RHR or SGs. 101010Check RCS temperature stable orCheck RCS temperature stable orCheck RCS temperature stable or1010Proceed to step 13.Proceed to step 13.lowering.lowering.lowering.Page 7 of 24Page 7 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0 111111Verify low pressure letdownVerify low pressure letdownVerify low pressure letdownaligned to operating RHR train:aligned to operating RHR train:aligned to operating RHR train:11.111.1Determine RHR train that lowDetermine RHR train that lowpressure letdown is aligned.pressure letdown is aligned.11.211.2IFIF required, required, THENTHEN align low pressure align low pressureletdown to the operating RHRletdown to the operating RHRtrain using FNP-1-SOP-7.0,train using FNP-1-SOP-7.0,RESIDUAL HEAT REMOVAL SYSTEMRESIDUAL HEAT REMOVAL SYSTEM 121212Go to procedure and step inGo to procedure and step inGo to procedure and step ineffect.effect.effect.****************************************************************************************************************************************************************************CAUTIONCAUTION::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 theContainment 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 theinitiating event unless an operable RHR pump is placed in serviceinitiating event unless an operable RHR pump is placed in servicecooling the RCS and the RCS temperature is below 180 F.cooling the RCS and the RCS temperature is below 180 F.**************************************************************************************************************************************************************************** 131313Begin establishing containmentBegin establishing containmentBegin establishing containment1313IFIF in mode 6, in mode 6, closure using FNP-1-STP-18.4,closure using FNP-1-STP-18.4,closure using FNP-1-STP-18.4,THENTHEN refer to Technical refer to TechnicalCONTAINMENT MID-LOOP CONTAINMENT MID-LOOP CONTAINMENT MID-LOOP ANDANDAND/OR/OR/ORSpecifications 3.9.4 and 3.9.5Specifications 3.9.4 and 3.9.5REFUELING INTEGRITYREFUELING INTEGRITYREFUELING INTEGRITYfor other containment isolationfor other containment isolationVERIFICATION VERIFICATION VERIFICATION ANDANDAND CONTAINMENT CONTAINMENT CONTAINMENTrequirements.requirements.CLOSURE.CLOSURE.CLOSURE.Page 8 of 24Page 8 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0 141414Monitor time to coreMonitor time to coreMonitor time to coresaturation.saturation.saturation.14.114.1Check time to core saturationCheck time to core saturation14.114.1Determine time to coreDetermine time to corefrom the current Shutdownfrom the current Shutdownsaturation:saturation:Safety Assessment.Safety Assessment.Use ATTACHMENT 3, Time toUse ATTACHMENT 3, Time toCore SaturationCore SaturationORORMonitor any available coreMonitor any available coreexit thermocouples for aexit thermocouples for aheat up trend.heat up trend.14.214.2Monitor RCS temperature trendMonitor RCS temperature trendduring the performance of thisduring the performance of thisprocedure.procedure.14.2.114.2.1Check vacuum degas systemCheck vacuum degas system14.2.114.2.1IFIF vacuum refill in vacuum refill inNOTNOT in service. in service.progress maintaining aprogress maintaining avacuum on the RCS, vacuum on the RCS, THENTHEN break vacuum on the break vacuum on theRCS using FNP-0-SOP-74.0,RCS using FNP-0-SOP-74.0,OPERATION OF THE RCVRSOPERATION OF THE RCVRSSKID. (155' CTMT)SKID. (155' CTMT)NOTE:NOTE:Step 14.2.2 is a continuing action step.Step 14.2.2 is a continuing action step.14.2.214.2.2IFIF RCS level decreases to RCS level decreases to less than 121 ft 11 in less than 121 ft 11 in ANDANDcore exit T/Cs are greatercore exit T/Cs are greaterthan 200than 200F, F, THENTHEN proceed to step 21. proceed to step 21.14.314.3IFIF applicable, applicable, THENTHEN review the current review the currentshutdown safety assessment ofshutdown safety assessment ofFNP-0-UOP-4.0 forFNP-0-UOP-4.0 forapplicability of other outageapplicability of other outageAbnormal Operating Procedures.Abnormal Operating Procedures. 151515Begin venting any RHR trainsBegin venting any RHR trainsBegin venting any RHR trainswhich have experienced evidencewhich have experienced evidencewhich have experienced evidenceof cavitation using ATTACHMENTof cavitation using ATTACHMENTof cavitation using ATTACHMENT1, RHR PUMP VENTING.1, RHR PUMP VENTING.1, RHR PUMP VENTING.Page 9 of 24Page 9 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0 161616Suspend any boron dilution inSuspend any boron dilution inSuspend any boron dilution inprogress. (IN 91-54)progress. (IN 91-54)progress. (IN 91-54) 171717IFIFIF the charging system is still the charging system is still the charging system is stillin service, in service, in service, THENTHENTHEN align the RWST to the align the RWST to the align the RWST to therunning Charging pump.running Charging pump.running Charging pump.OperableOperable CHG PUMPCHG PUMP 1A 1A 1B(A TRN)1B(A TRN)1B(B TRN)1B(B TRN) 1C 1C RWST TO RWST TO CHG PUMPCHG PUMP Q1E21LCVQ1E21LCV[] 115B[] 115B[] 115B [] 115B [] 115D [] 115D [] 115D[] 115D****************************************************************************************************************************************************************************CAUTIONCAUTION::The RCS tygon level hose and LT 2965A&B utilize the same level tap. The RCS tygon level hose and LT 2965A&B utilize the same level tap. These are not independent indications.These are not independent indications.****************************************************************************************************************************************************************************181818Check for two independent RCSCheck for two independent RCSCheck for two independent RCSlevel indications.level indications.level indications. 18.118.1Compare available levelCompare available levelindications.indications.[][]LT 2965A&B/level hoseLT 2965A&B/level hose[][]LI-2384 1B LOOP RCS NR LVLLI-2384 1B LOOP RCS NR LVL[][]LI-2385 1C LOOP RCS NR LVLLI-2385 1C LOOP RCS NR LVL[][]Temporary remote levelTemporary remote levelindicator off of a RCS FT on Aindicator off of a RCS FT on Aor C loopor C loop18.218.2Check RCS level greater thanCheck RCS level greater than18.218.2Raise RCS level.Raise RCS level.123 ft 3 in.123 ft 3 in.18.2.118.2.1Notify personnel inNotify personnel incontainment that RCS levelcontainment that RCS levelwill be raised.will be raised.18.2.218.2.2Align Technical Align Technical Requirements ManualRequirements Manualboration flow path.boration flow path.18.2.318.2.3Raise RCS level to greaterRaise RCS level to greaterthan 123 ft 3 in.than 123 ft 3 in.Step 18 continued on next page.Step 18 continued on next page.Page 10 of 24Page 10 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.018.318.3Maintain RCS level within theMaintain RCS level within thefollowing limits:following limits:[][]Maintain RCS level less thanMaintain RCS level less than123 ft 4 in if personnel are123 ft 4 in if personnel arein the channel heads withoutin the channel heads withoutnozzle dams installed.nozzle dams installed.[][]Maintain RCS level less thanMaintain RCS level less than123 ft 9 in if primary manways123 ft 9 in if primary manwaysare removed without nozzleare removed without nozzledams installed.dams installed.[][]Maintain RCS level less thanMaintain RCS level less than123 ft 9 in if seal injection123 ft 9 in if seal injectionis not established and RCPsis not established and RCPsare not backseated.are not backseated.[][]Maintain RCS level less thanMaintain RCS level less than124 ft if safety injection124 ft if safety injectioncheck valves are disassembled.check valves are disassembled.****************************************************************************************************************************************************************************CAUTIONCAUTION::The standby RHR train may be lost due to cavitation if it is placedThe standby RHR train may be lost due to cavitation if it is placedin service without adequate RCS level.in service without adequate RCS level.********************************************************************************************************************************************************************************************************************************************************************************************************************************************************CAUTIONCAUTION::Starting an RHR PUMP may cause RCS level to fall due to shrink orStarting an RHR PUMP may cause RCS level to fall due to shrink orvoid collapse.void collapse.****************************************************************************************************************************************************************************NOTE:NOTE:The term "standby RHR train" refers to the train most readilyThe term "standby RHR train" refers to the train most readilyavailable to restore RHR cooling.available to restore RHR cooling.191919WHENWHENWHEN RCS level greater than RCS level greater than RCS level greater than1919IFIF unable to establish at least unable to establish at least123 ft 3 in, 123 ft 3 in, 123 ft 3 in, one train of RHR, one train of RHR, THENTHENTHEN place standby RHR train in place standby RHR train in place standby RHR train inTHENTHEN proceed to step 21 while proceed to step 21 whileservice.service.service.continuing efforts to restorecontinuing efforts to restoreat least one train of RHR.at least one train of RHR.19.119.1Verify CCW PUMP in standbyVerify CCW PUMP in standbytrain - STARTED.train - STARTED.Step 19 continued on next page.Step 19 continued on next page.Page 11 of 24Page 11 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.019.219.2Verify CCW - ALIGNED TOVerify CCW - ALIGNED TOSTANDBY RHR HEAT EXCHANGER.STANDBY RHR HEAT EXCHANGER.Standby RHR TrainStandby RHR Train A A B B CCW TO CCW TO 1A(1B) RHR HX 1A(1B) RHR HX Q1P17MOV Q1P17MOV [] 3185A[] 3185A[] 3185B[] 3185B19.319.3Verify the followingVerify the followingconditions satisfied. conditions satisfied. 19.3.119.3.1RWST TO 1A(1B) RHR PUMPRWST TO 1A(1B) RHR PUMPQ1E11MOV8809A and B closed.Q1E11MOV8809A and B closed.19.3.219.3.21A(1B) RHR HX TO CHG PUMP1A(1B) RHR HX TO CHG PUMPSUCT Q1E11MOV8706A and BSUCT Q1E11MOV8706A and Bclosed.closed.19.3.319.3.3RCS pressure less thanRCS pressure less than402.5 psig.402.5 psig.19.3.419.3.4PRZR vapor spacePRZR vapor spacetemperature less thantemperature less than475475F.F.Step 19 continued on next page.Step 19 continued on next page.Page 12 of 24Page 12 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0NOTE:NOTE:RCS to RHR loop suction valves will be deenergized if RCS TAVG isRCS to RHR loop suction valves will be deenergized if RCS TAVG isless than 180less than 180F.F.19.419.4Verify standby RHR train loopVerify standby RHR train loopsuction valves - OPEN.suction valves - OPEN.Standby RHR Train Standby RHR Train A A B B 1C(1A) RCS LOOP 1C(1A) RCS LOOP to 1A(1B) RHR PUMP to 1A(1B) RHR PUMP Q1E11MOV Q1E11MOV [] 8701A[] 8701A[] 8702A[] 8702A [] 8701B[] 8701B[] 8702B[] 8702B1C(1A) RCS LOOP 1C(1A) RCS LOOP TO 1A(1B) RHR PUMP TO 1A(1B) RHR PUMP [] FU-T5[] FU-T5[] FU-G2[] FU-G2LOOP SUCTION POWER LOOP SUCTION POWER [] FV-V2[] FV-V2[] FV-V3[] FV-V3SUPPLY BREAKERS SUPPLY BREAKERS CLOSE(CLOSE(IFIF REQUIRED) REQUIRED) Step 19 continued on next page.Step 19 continued on next page.Page 13 of 24Page 13 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.019.519.5Check standby RHR trainCheck standby RHR traindischarge flow path available.discharge flow path available.19.5.119.5.1Verify standby RHR train -Verify standby RHR train -ALIGNED TO RCS COLD LEGS.ALIGNED TO RCS COLD LEGS. RHR Train RHR Train A A B B RHR HX TO RCS RHR HX TO RCS COLD LEGS ISO COLD LEGS ISO [] 8888A[] 8888A[] 8888B[] 8888BQ1E11MOVQ1E11MOVOPEN OPEN NOTE:NOTE:The RHR HX bypass valves will fail closed and the RHR HX dischargeThe RHR HX bypass valves will fail closed and the RHR HX dischargevalves will fail open upon loss of air to the AUX BLDG.valves will fail open upon loss of air to the AUX BLDG.19.5.219.5.2Verify standby RHR train HXVerify standby RHR train HXBYP FLOW - ADJUSTED TO 15%BYP FLOW - ADJUSTED TO 15%OPEN.OPEN.Standby RHR TrainStandby RHR Train A A B B 1A(1B) RHR HX 1A(1B) RHR HX BYP FLOW BYP FLOW FK FK [] 605A[] 605A[] 605B[] 605B19.5.319.5.3Verify standby RHR train HXVerify standby RHR train HX19.5.319.5.3Close standby RHR train -Close standby RHR train -discharge valve - ADJUSTEDdischarge valve - ADJUSTEDTO RCS COLD LEGS ISOTO RCS COLD LEGS ISOCLOSED.CLOSED.valves. (121 ft, AUX BLDGvalves. (121 ft, AUX BLDGpiping penetration room)piping penetration room)Standby RHR Train Standby RHR Train A A B B 1A(1B) RHR HX TO RCS1A(1B) RHR HX TO RCS RHR Train RHR Train A A B B DISCH VLV DISCH VLV HIK HIK [] 603A[] 603A[] 603B[] 603BRHR HX TO RCS RHR HX TO RCS COLD LEGS ISO COLD LEGS ISO [] 8888A[] 8888A[] 8888B[] 8888BQ1E11MOV Q1E11MOV Step 19 continued on next page.Step 19 continued on next page.Page 14 of 24Page 14 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.019.619.6Verify standby RHR train pumpVerify standby RHR train pumpminiflow valve - OPEN.miniflow valve - OPEN.Standby RHR TrainStandby RHR Train A A B B 1A(1B) RHR PUMP 1A(1B) RHR PUMP MINIFLOW MINIFLOW Q1E11FCV Q1E11FCV [] 602A[] 602A[] 602B[] 602B19.719.7Start RHR PUMP in standbyStart RHR PUMP in standbytrain.train.19.819.8Control standby RHR train RHRControl standby RHR train RHR19.819.8IFIF unable to control standby unable to control standbyHX bypass valve to obtainHX bypass valve to obtainRHR train flow with RHR HXRHR train flow with RHR HXdesired flow.desired flow.bypass valve, bypass valve, THENTHEN locally control RHR HX TO locally control RHR HX TORCS COLD LEGS ISO valves. RCS COLD LEGS ISO valves. Standby RHR Train Standby RHR Train A A B B (121 ft, AUX BLDG piping(121 ft, AUX BLDG piping1A(1B) RHR HX 1A(1B) RHR HX penetration room)penetration room)BYP FLOW BYP FLOW FK FK [] 605A[] 605A[] 605B[] 605B RHR Train RHR Train A A B B RHR HX TO RCS RHR HX TO RCS COLD LEGS ISO COLD LEGS ISO [] 8888A[] 8888A[] 8888B[] 8888BQ1E11MOV Q1E11MOV 202020IFIFIF RHR restored, RHR restored, RHR restored, 2020Continue efforts to restore atContinue efforts to restore atTHENTHENTHEN go to procedure and step go to procedure and step go to procedure and stepleast one RHR train whileleast one RHR train whilein effect.in effect.in effect.continuing with this procedure.continuing with this procedure.Page 15 of 24Page 15 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0 212121Initiate protective measuresInitiate protective measuresInitiate protective measuresfor personnel in containment.for personnel in containment.for personnel in containment.21.121.1Evacuate all nonessentialEvacuate all nonessentialpersonnel from containment.personnel from containment.21.221.2Ensure HP monitors essentialEnsure HP monitors essentialpersonnel remaining inpersonnel remaining incontainment for the following:containment for the following:[][]Changing containmentChanging containmentconditions which could requireconditions which could requireevacuation of all personnel.evacuation of all personnel.[][]Use of extra protectiveUse of extra protectiveclothing if needed.clothing if needed.[][]Use of respirators if needed.Use of respirators if needed.21.321.3Monitor containment radiationMonitor containment radiationmonitors for changingmonitors for changingconditions.conditions.[][]R-2 CTMT 155 ftR-2 CTMT 155 ft[][]R-7 SEAL TABLER-7 SEAL TABLE[][]R-27A CTMT HIGH RANGE (BOP)R-27A CTMT HIGH RANGE (BOP)[][]R-27B CTMT HIGH RANGE (BOP)R-27B CTMT HIGH RANGE (BOP)Page 16 of 24Page 16 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0 222222Start all available Start all available Start all available containment coolerscontainment coolerscontainment coolers 22.122.1Determine which containmentDetermine which containmentcoolers have Service Watercoolers have Service Wateraligned.aligned.[][]Q1E12H001AQ1E12H001A[][]Q1E12H001BQ1E12H001B[][]Q1E12H001CQ1E12H001C[][]Q1E12H001DQ1E12H001D22.222.2Start Containment coolers withStart Containment coolers with22.222.2Start Containment coolers withStart Containment coolers withservice water aligned and withservice water aligned and withservice water aligned and withservice water aligned and withpower available in FAST speed.power available in FAST speed.power available in SLOW speed.power available in SLOW speed.[][]1A CTMT CLR FAN FAST SPEED1A CTMT CLR FAN FAST SPEED[][]1A CTMT CLR FAN SLOW SPEED1A CTMT CLR FAN SLOW SPEEDQ1E12H001A to START Q1E12H001A to START Q1E12H001A to START Q1E12H001A to START (BKR EA10)(BKR EA10)(BKR ED15)(BKR ED15)[][]1B CTMT CLR FAN FAST SPEED1B CTMT CLR FAN FAST SPEED[][]1B CTMT CLR FAN SLOW SPEED1B CTMT CLR FAN SLOW SPEEDQ1E12H001B to START Q1E12H001B to START Q1E12H001B to START Q1E12H001B to START (BKR EB05) (BKR EB05) (BKR ED16)(BKR ED16)[][]1C CTMT CLR FAN FAST SPEED1C CTMT CLR FAN FAST SPEED[][]1C CTMT CLR FAN SLOW SPEED1C CTMT CLR FAN SLOW SPEEDQ1E12H001C to START Q1E12H001C to START Q1E12H001C to START Q1E12H001C to START (BKR EB06) (BKR EB06) (BKR EE08)(BKR EE08)[][]1D CTMT CLR FAN FAST SPEED1D CTMT CLR FAN FAST SPEED[][]1D CTMT CLR FAN SLOW SPEED1D CTMT CLR FAN SLOW SPEEDQ1E12H001C to START Q1E12H001C to START Q1E12H001D to START Q1E12H001D to START (BKR EC12) (BKR EC12) (BKR EE16)(BKR EE16)22.322.3Check discharge damper open onCheck discharge damper open on22.322.3STOP any containment coolerSTOP any containment coolerany started containmentany started containmentwhose discharge damper failswhose discharge damper failscooler.cooler.to indicate OPEN.to indicate OPEN.[][]CTMT CLR 1A DISCH 3186ACTMT CLR 1A DISCH 3186Aindicates OPEN.indicates OPEN.[][]CTMT CLR 1B DISCH 3186BCTMT CLR 1B DISCH 3186Bindicates OPEN.indicates OPEN.[][]CTMT CLR 1C DISCH 3186CCTMT CLR 1C DISCH 3186Cindicates OPEN.indicates OPEN.[][]CTMT CLR 1D DISCH 3186dCTMT CLR 1D DISCH 3186dindicates OPEN.indicates OPEN. 232323IFIFIF not previously started, not previously started, not previously started, THENTHENTHEN begin venting any RHR begin venting any RHR begin venting any RHRtrain(s) which have experiencedtrain(s) which have experiencedtrain(s) which have experiencedevidence of cavitation usingevidence of cavitation usingevidence of cavitation usingATTACHMENT 1, RHR PUMP VENTING.ATTACHMENT 1, RHR PUMP VENTING.ATTACHMENT 1, RHR PUMP VENTING.Page 17 of 24Page 17 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0NOTE:NOTE:Steps 24 and 25 should be performed in conjunction with the remainderSteps 24 and 25 should be performed in conjunction with the remainderof this procedure.of this procedure. 242424Check SGs available.Check SGs available.Check SGs available.2424Proceed to step 26.Proceed to step 26.Check SG primary nozzle damsCheck SG primary nozzle dams- REMOVED.- REMOVED.Check SG primary manways -Check SG primary manways -INSTALLED.INSTALLED.Check SG secondary handholeCheck SG secondary handholecovers - INSTALLED.covers - INSTALLED.NOTE:NOTE:Establishing a secondary heat sink will reduce RCS heat up andEstablishing a secondary heat sink will reduce RCS heat up andpressurization rate to provide more time for recovery actions.pressurization rate to provide more time for recovery actions. 252525Verify secondary heat sinkVerify secondary heat sinkVerify secondary heat sinkestablished.established.established.25.125.1Maintain wide range level inMaintain wide range level inall available SGs greater thanall available SGs greater than75% using FNP-1-SOP-22.0,75% using FNP-1-SOP-22.0,AUXILIARY FEEDWATER SYSTEM.AUXILIARY FEEDWATER SYSTEM.25.225.2IFIF SG steam space intact, SG steam space intact, THENTHEN open atmospheric relief open atmospheric reliefvalves to prevent SGvalves to prevent SGpressurization.pressurization.1A(1B,1C) MS ATMOS1A(1B,1C) MS ATMOSREL VLVREL VLV[][]PC 3371A adjustedPC 3371A adjusted[][]PC 3371B adjustedPC 3371B adjusted[][]PC 3371C adjustedPC 3371C adjusted25.325.3IFIF SGBD system available, SGBD system available, ANDANDAFW system available, AFW system available, THENTHEN establish blowdown from establish blowdown fromavailable SGs usingavailable SGs usingFNP-1-SOP-16.3, STEAMFNP-1-SOP-16.3, STEAMGENERATOR FILLING ANDGENERATOR FILLING ANDDRAINING.DRAINING.Page 18 of 24Page 18 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0 262626Evaluate event classificationEvaluate event classificationEvaluate event classificationand notification requirementsand notification requirementsand notification requirementsusing NMP-EP-110, EMERGENCYusing NMP-EP-110, EMERGENCYusing NMP-EP-110, EMERGENCYCLASSIFICATION DETERMINATIONCLASSIFICATION DETERMINATIONCLASSIFICATION DETERMINATIONAND INITIAL ACTION, NMP-EP-111,AND INITIAL ACTION, NMP-EP-111,AND INITIAL ACTION, NMP-EP-111,EMERGENCY NOTIFICATIONS, andEMERGENCY NOTIFICATIONS, andEMERGENCY NOTIFICATIONS, andFNP-0-EIP-8, NON-EMERGENCYFNP-0-EIP-8, NON-EMERGENCYFNP-0-EIP-8, NON-EMERGENCYNOTIFICATIONS.NOTIFICATIONS.NOTIFICATIONS. 272727Verify RCS isolated.Verify RCS isolated.Verify RCS isolated.27.127.1Close RHR TO LTDN HX HIK 142.Close RHR TO LTDN HX HIK 142.27.227.2Close LTDN LINE ISOClose LTDN LINE ISOQ1E21LCV459 and Q1E21LCV460.Q1E21LCV459 and Q1E21LCV460.27.327.3Close EXC LTDN LINE ISO VLVClose EXC LTDN LINE ISO VLVQ1E21HV8153 and Q1E21HV8154.Q1E21HV8153 and Q1E21HV8154.27.427.4Dispatch personnel to isolateDispatch personnel to isolateall known RCS drain paths.all known RCS drain paths.27.527.5Dispatch personnel to isolateDispatch personnel to isolateany RCS leakage.any RCS leakage. 282828Dispatch personnel to close hotDispatch personnel to close hotDispatch personnel to close hotleg recirculation valveleg recirculation valveleg recirculation valvedisconnects. (139 ft, AUX BLDGdisconnects. (139 ft, AUX BLDGdisconnects. (139 ft, AUX BLDGrad-side)rad-side)rad-side)CHG PUMP TOCHG PUMP TORCS HOT LEGSRCS HOT LEGSQ1E21MOV8886(8884)Q1E21MOV8886(8884)[][]Q1R18B029-A (Master Z key)Q1R18B029-A (Master Z key)[][]Q1R18B033-B (Master Z key)Q1R18B033-B (Master Z key) 292929Check core cooling.Check core cooling.Check core cooling.29.129.1Check RCS level LESS thanCheck RCS level LESS than29.129.1Return to step 1.0.Return to step 1.0.121 ft 11 in 121 ft 11 in ANDAND core exit core exitT/Cs GREATER than 200T/Cs GREATER than 200F.F.Page 19 of 24Page 19 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0NOTE:NOTE:Maintaining RCS level is the primary concern. RCS makeup should beMaintaining RCS level is the primary concern. RCS makeup should berestored as soon as possible through any available makeup path.restored as soon as possible through any available makeup path.RCS makeup flow requirements can exceed 90 gpm due to boil off ifRCS makeup flow requirements can exceed 90 gpm due to boil off ifan adequate hot leg vent is established.an adequate hot leg vent is established. 303030WHENWHENWHEN RHR flow restored, RHR flow restored, RHR flow restored, THENTHENTHEN proceed to step 40. proceed to step 40. proceed to step 40. 313131Check any CHG PUMP - AVAILABLE.Check any CHG PUMP - AVAILABLE.Check any CHG PUMP - AVAILABLE.3131Establish RWST gravity drainEstablish RWST gravity drainusing ATTACHMENT 2, RWST TO RCSusing ATTACHMENT 2, RWST TO RCSGRAVITY FEED.GRAVITY FEED.31.131.1WHENWHEN gravity drain gravity drainestablished, established, THENTHEN proceed to step 37. proceed to step 37. 323232Verify operable CHG PUMPVerify operable CHG PUMPVerify operable CHG PUMPminiflow valves - OPEN.miniflow valves - OPEN.miniflow valves - OPEN.1A(1B,1C) CHG PUMP1A(1B,1C) CHG PUMPMINIFLOW ISOMINIFLOW ISO[][]Q1E21MOV8109AQ1E21MOV8109A[][]Q1E21MOV8109BQ1E21MOV8109B[][]Q1E21MOV8109CQ1E21MOV8109C 333333Verify CHG PUMP miniflowVerify CHG PUMP miniflowVerify CHG PUMP miniflowisolation valve - OPEN.isolation valve - OPEN.isolation valve - OPEN.CHG PUMPCHG PUMPMINIFLOW ISOMINIFLOW ISO[][]Q1E21MOV8106Q1E21MOV8106 343434Verify RWST to CHG PUMP valveVerify RWST to CHG PUMP valveVerify RWST to CHG PUMP valvefor operable CHG PUMP - OPEN.for operable CHG PUMP - OPEN.for operable CHG PUMP - OPEN.OperableOperable CHG PUMPCHG PUMP 1A 1A 1B(A TRN)1B(A TRN)1B(B TRN)1B(B TRN) 1C 1C RWST TO RWST TO CHG PUMPCHG PUMP Q1E21LCVQ1E21LCV[] 115B[] 115B[] 115B [] 115B [] 115D [] 115D [] 115D[] 115D 353535Verify operable CHG PUMP -Verify operable CHG PUMP -Verify operable CHG PUMP -STARTED.STARTED.STARTED.Page 20 of 24Page 20 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0 363636Verify required injection pathVerify required injection pathVerify required injection pathisolation valve - OPEN.isolation valve - OPEN.isolation valve - OPEN. Q1E21MOV8803A Q1E21MOV8803A HHSI TO RCS CL ISO HHSI TO RCS CL ISO Q1E21MOV8803B Q1E21MOV8803B HHSI TO RCS CL ISO HHSI TO RCS CL ISO Q1E21MOV8885 Q1E21MOV8885 CHG PUMP RECIRC TO CHG PUMP RECIRC TO RCS COLD LEGS RCS COLD LEGS Q1E21MOV8884 Q1E21MOV8884 CHG PUMP RECIRC TO CHG PUMP RECIRC TO RCS HOT LEGS RCS HOT LEGS Q1E21MOV8886 Q1E21MOV8886 CHG PUMP RECIRC TO CHG PUMP RECIRC TO RCS HOT LEGS RCS HOT LEGS Page 21 of 24Page 21 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0****************************************************************************************************************************************************************************CAUTIONCAUTION::Reactor vessel level may be much lower than indicated if no hot legReactor vessel level may be much lower than indicated if no hot legvent path is available.vent path is available.********************************************************************************************************************************************************************************************************************************************************************************************************************************************************CAUTIONCAUTION::RCS pressurization may cause SG nozzle dam failure. This will causeRCS pressurization may cause SG nozzle dam failure. This will causea rapid loss of RCS inventory and the creation of a RCS spilla rapid loss of RCS inventory and the creation of a RCS spillpathway.pathway.****************************************************************************************************************************************************************************373737IFIFIF RCS configuration will allow RCS configuration will allow RCS configuration will allow3737IFIF RCS configuration will RCS configuration will NOTNOTa level in the pressurizer, a level in the pressurizer, a level in the pressurizer, allow a level in theallow a level in theTHENTHENTHEN establish feed and bleed establish feed and bleed establish feed and bleedpressurizer, pressurizer, cooling. cooling. cooling. THENTHEN establish feed and spill establish feed and spillcooling as follows. cooling as follows. 37.137.1Verify RCS bleed pathVerify RCS bleed pathavailable as follows.available as follows.a)a)Locally control requiredLocally control requiredinjection path isolationinjection path isolationVerify all pressurizerVerify all pressurizervalve to maintain core exitvalve to maintain core exitsafety valves - REMOVED.safety valves - REMOVED.T/Cs less than 200T/Cs less than 200F.F.ORORb)b)Proceed to step 38.Proceed to step 38.Verify pressurizer manway -Verify pressurizer manway -REMOVED.REMOVED.ORORVerify both PRZR PORVs andVerify both PRZR PORVs andPRZR PORV ISOs - OPEN.PRZR PORV ISOs - OPEN.Step 37 continued on next page.Step 37 continued on next page.Page 22 of 24Page 22 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.037.237.2WHENWHEN pressurizer level greater pressurizer level greater37.237.2Locally control requiredLocally control requiredthan 7% (136 ft 9 in), than 7% (136 ft 9 in), injection path isolation valveinjection path isolation valveTHENTHEN establish normal establish normalto maintain pressurizer levelto maintain pressurizer levelcharging.charging.greater than 7% (136 ft 9 in).greater than 7% (136 ft 9 in).37.2.137.2.1Verify charging pumpVerify charging pumpminiflow valves - OPEN.miniflow valves - OPEN.1A(1B,1C) CHG PUMP1A(1B,1C) CHG PUMPMINIFLOW ISOMINIFLOW ISO[][]Q1E21MOV8109AQ1E21MOV8109A[][]Q1E21MOV8109BQ1E21MOV8109B[][]Q1E21MOV8109CQ1E21MOV8109CCHG PUMPCHG PUMPMINIFLOW ISOMINIFLOW ISO[][]Q1E21MOV8106Q1E21MOV810637.2.237.2.2Manually close chargingManually close chargingflow control valve.flow control valve.CHG FLOWCHG FLOW[][]FK 122FK 12237.2.337.2.3Verify charging pumpVerify charging pumpdischarge flow path -discharge flow path -ALIGNED.ALIGNED.CHG PUMPCHG PUMPDISCH HDR ISODISCH HDR ISO[][]Q1E21MOV8132A openQ1E21MOV8132A open[][]Q1E21MOV8132B openQ1E21MOV8132B open[][]Q1E21MOV8133A openQ1E21MOV8133A open[][]Q1E21MOV8133B openQ1E21MOV8133B openCHG PUMPS TOCHG PUMPS TOREGENERATIVE HXREGENERATIVE HX[][]Q1E21MOV8107 openQ1E21MOV8107 open[][]Q1E21MOV8108 openQ1E21MOV8108 openStep 37 continued on next page.Step 37 continued on next page.Page 23 of 24Page 23 of 243/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.037.2.437.2.4Verify only one chargingVerify only one chargingline valve - OPEN.line valve - OPEN.RCS NORMALRCS NORMALCHG LINECHG LINE[][]Q1E21HV8146Q1E21HV8146RCS ALTRCS ALTCHG LINECHG LINE[][]Q1E21HV8147Q1E21HV814737.2.537.2.5Maintain pressurizer levelMaintain pressurizer levelgreater than 7% (136 ftgreater than 7% (136 ft9 in).9 in).CHG FLOWCHG FLOW[][]FK 122 adjustedFK 122 adjusted37.2.637.2.6Close required injectionClose required injectionpath isolation valve.path isolation valve. 383838Maintain RCS feed and bleed Maintain RCS feed and bleed Maintain RCS feed and bleed 3838Maintain RCS feed and spillMaintain RCS feed and spillcooling until at least one RHRcooling until at least one RHRcooling until at least one RHRcooling until at least one RHRcooling until at least one RHRtrain restored.train restored.train restored.train restored.train restored. 393939Check RHR - RESTORED.Check RHR - RESTORED.Check RHR - RESTORED.3939Return to step 37.Return to step 37. 404040Maintain RCS at desired level.Maintain RCS at desired level.Maintain RCS at desired level. 414141Begin RCS cooldown usingBegin RCS cooldown usingBegin RCS cooldown usingFNP-1-SOP-7.0, RESIDUAL HEATFNP-1-SOP-7.0, RESIDUAL HEATFNP-1-SOP-7.0, RESIDUAL HEATREMOVAL SYSTEM.REMOVAL SYSTEM.REMOVAL SYSTEM. 424242WHENWHENWHEN core exit T/Cs stable at core exit T/Cs stable at core exit T/Cs stable atdesired temperature, desired temperature, desired temperature, THENTHENTHEN go to procedure and step go to procedure and step go to procedure and stepin effect.in effect.in effect.-END- -END- Page 24 of 24Page 24 of 243/15/201300:29UNIT 1 FNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0FIGURE 1FIGURE 1RCS HOT LEG LEVEL vs RHR INTAKE FLOW To Minimize VortexingRCS HOT LEG LEVEL vs RHR INTAKE FLOW To Minimize VortexingRCS HOT LEG LEVEL vs RHR INTAKE FLOWRCS HOT LEG LEVEL vs RHR INTAKE FLOWTo Minimize VortexingTo Minimize Vortexing Page 1 of 1Page 1 of 13/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 1ATTACHMENT 1RHR PUMP VENTINGRHR PUMP VENTING****************************************************************************************************************************************************************************CAUTIONCAUTION::Installation of vent rigs must not delay venting operations if onlyInstallation of vent rigs must not delay venting operations if onlythe air bound train is available for service. Contamination shouldthe air bound train is available for service. Contamination shouldbe minimized but contamination control must not interfere withbe minimized but contamination control must not interfere withventing.venting.**************************************************************************************************************************************************************************** 111IFIFIF both trains of RHR are air both trains of RHR are air both trains of RHR are airbound bound bound OROROR unavailable, unavailable, unavailable, THENTHENTHEN proceed to step 4 proceed to step 4 proceed to step 4NOTE:NOTE:Vent rigs may be routed to either floor drains or poly bottles.Vent rigs may be routed to either floor drains or poly bottles. 222IFIFIF 1A RHR PUMP AIR bound, 1A RHR PUMP AIR bound, 1A RHR PUMP AIR bound, THENTHENTHEN install vent rigs on A install vent rigs on A install vent rigs on Atrain RHR system.train RHR system.train RHR system.2.12.1Install vent rig at 1A RHRInstall vent rig at 1A RHRPUMP SEAL COOLER OUTLET VENTPUMP SEAL COOLER OUTLET VENTISO Q1E11V080C. (83 ft, AUXISO Q1E11V080C. (83 ft, AUXBLDG 1A RHR PUMP room)BLDG 1A RHR PUMP room)2.22.2Install vent rig at 1A RHR HXInstall vent rig at 1A RHR HXOUTLET VENT ISO Q1E11V068C. OUTLET VENT ISO Q1E11V068C. (83 ft, AUX BLDG RHR HX room)(83 ft, AUX BLDG RHR HX room)2.32.3Install vent rig at 1C RCSInstall vent rig at 1C RCSLOOP TO 1A RHR PUMP HDR VENTLOOP TO 1A RHR PUMP HDR VENTISO Q1E11V064C. (100 ft, AUXISO Q1E11V064C. (100 ft, AUXBLDG piping penetration room,BLDG piping penetration room,PEN #16)PEN #16)2.42.4Install vent rig at 1A RHR HXInstall vent rig at 1A RHR HXTO RCS COLD LEGS HDR VENT ISOTO RCS COLD LEGS HDR VENT ISOQ1E11V055B. (121 ft, AUX BLDGQ1E11V055B. (121 ft, AUX BLDGpiping penetration room, PENpiping penetration room, PEN#15)#15)Page 1 of 9Page 1 of 93/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 1ATTACHMENT 1 333IFIFIF 1B RHR PUMP air bound, 1B RHR PUMP air bound, 1B RHR PUMP air bound, THENTHENTHEN install vent rigs on B install vent rigs on B install vent rigs on Btrain RHR system.train RHR system.train RHR system.3.13.1Install vent rig at 1B RHRInstall vent rig at 1B RHRPUMP SEAL COOLER OUTLET VENTPUMP SEAL COOLER OUTLET VENTISO Q1E11V080D. (83 ft, AUXISO Q1E11V080D. (83 ft, AUXBLDG 1B RHR PUMP room)BLDG 1B RHR PUMP room)3.23.2Install vent rig at 1B RHR HXInstall vent rig at 1B RHR HXOUTLET VENT ISO Q1E11V068D. OUTLET VENT ISO Q1E11V068D. (83 ft, AUX BLDG RHR HX room)(83 ft, AUX BLDG RHR HX room)3.33.3Install vent rig at 1A RCSInstall vent rig at 1A RCSLOOP TO 1B RHR PUMP HDR VENTLOOP TO 1B RHR PUMP HDR VENTISO Q1E11V064D. (100 ft, AUXISO Q1E11V064D. (100 ft, AUXBLDG piping penetration room,BLDG piping penetration room,PEN #18)PEN #18)3.43.4Install vent rig at 1B RHR HXInstall vent rig at 1B RHR HXTO RCS COLD LEGS HDR VENT ISOTO RCS COLD LEGS HDR VENT ISOQ1E11V058B. (121 ft, AUX BLDGQ1E11V058B. (121 ft, AUX BLDGpiping penetration room, PENpiping penetration room, PEN#17)#17)Page 2 of 9Page 2 of 93/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 1ATTACHMENT 1****************************************************************************************************************************************************************************CAUTIONCAUTION::Using the RCS as a makeup source for RHR system inventory lost duringUsing the RCS as a makeup source for RHR system inventory lost duringventing (per RNO), will result in a loss of RCS inventory andventing (per RNO), will result in a loss of RCS inventory andtherefore a lowering of RCS level. This could jeopardize the othertherefore a lowering of RCS level. This could jeopardize the othertrain of RHR, if it is in operation.train of RHR, if it is in operation.****************************************************************************************************************************************************************************NOTE:NOTE:The intent of aligning the RWST to the air bound train when the RCSThe intent of aligning the RWST to the air bound train when the RCSloop suctions are open is to make up for inventory lost when venting,loop suctions are open is to make up for inventory lost when venting,however, this action also initiates gravity flow from the RWST. however, this action also initiates gravity flow from the RWST. Close coordination will be required between the control room operatorClose coordination will be required between the control room operatormonitoring RCS level and the operator controlling the RWST supplymonitoring RCS level and the operator controlling the RWST supplylocally.locally. 444Align a source of make up toAlign a source of make up toAlign a source of make up tothe air bound train.the air bound train.the air bound train.4.14.1Locally, throttle open RWSTLocally, throttle open RWST4.14.1Open RCS supply to air boundOpen RCS supply to air boundsupply to air bound trainsupply to air bound traintrain.train.until it is just off theuntil it is just off theclosed seat. (83 ft el, RHRclosed seat. (83 ft el, RHRPUMP Rm)PUMP Rm)Air Bound Train Air Bound Train A A B B 1C(1A) RCS LOOP 1C(1A) RCS LOOP TO 1A(1B) RHR PUMPTO 1A(1B) RHR PUMP Air Bound TrainAir Bound Train A A B B Q1E11MOV Q1E11MOV []8701A[]8701A[]8702A[]8702ARWST TO RWST TO []8701B[]8701B[]8702B[]8702B1A(1B) RHR PUMP1A(1B) RHR PUMP Q1E11MOV Q1E11MOV []8809A[]8809A[]8809B[]8809BPage 3 of 9Page 3 of 93/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 1ATTACHMENT 1 555IFIFIF 1A RHR PUMP air bound, 1A RHR PUMP air bound, 1A RHR PUMP air bound, THENTHENTHEN perform the following. perform the following. perform the following.5.15.1Open 1A RHR PUMP SEAL COOLEROpen 1A RHR PUMP SEAL COOLEROUTLET VENTS Q1E11V080C andOUTLET VENTS Q1E11V080C andQ1E11V080A. (83 ft, AUX BLDGQ1E11V080A. (83 ft, AUX BLDG1A RHR PUMP room)1A RHR PUMP room)5.25.2WHENWHEN air free water is seen, air free water is seen, THENTHEN close 1A RHR PUMP SEAL close 1A RHR PUMP SEALCOOLER OUTLET VENTS Q1E11V080CCOOLER OUTLET VENTS Q1E11V080Cand Q1E11V080A. (83 ft, AUXand Q1E11V080A. (83 ft, AUXBLDG 1A RHR PUMP room)BLDG 1A RHR PUMP room)5.35.3Open 1A RHR HX OUTLET VENTSOpen 1A RHR HX OUTLET VENTSQ1E11V068C and Q1E11V068A. Q1E11V068C and Q1E11V068A. (83 ft, AUX BLDG RHR HX room)(83 ft, AUX BLDG RHR HX room)5.45.4WHENWHEN air free water is seen, air free water is seen, THENTHEN close 1A RHR HX OUTLET close 1A RHR HX OUTLETVENTS Q1E11V068C andVENTS Q1E11V068C andQ1E11V068A. (83 ft, AUX BLDGQ1E11V068A. (83 ft, AUX BLDGRHR HX room)RHR HX room)5.55.5Open 1C RCS LOOP TO 1A RHROpen 1C RCS LOOP TO 1A RHRPUMP HDR VENTS Q1E11V064C andPUMP HDR VENTS Q1E11V064C andQ1E11V064A. (100 ft, AUX BLDGQ1E11V064A. (100 ft, AUX BLDGpiping penetration room, PENpiping penetration room, PEN#16)#16)5.65.6WHENWHEN air free water is seen, air free water is seen, THENTHEN close 1C RCS LOOP TO 1A close 1C RCS LOOP TO 1ARHR PUMP HDR VENTS Q1E11V064CRHR PUMP HDR VENTS Q1E11V064Cand Q1E11V064A. (100 ft, AUXand Q1E11V064A. (100 ft, AUXBLDG piping penetration room)BLDG piping penetration room)5.75.7Open 1A RHR HX TO RCS COLDOpen 1A RHR HX TO RCS COLDLEGS HDR VENTS Q1E11V055B andLEGS HDR VENTS Q1E11V055B andQ1E11VO55A. (121 ft, AUX BLDGQ1E11VO55A. (121 ft, AUX BLDGpiping penetration room, PENpiping penetration room, PEN#15)#15)5.85.8WHENWHEN air free water is seen, air free water is seen, THENTHEN close 1A RHR HX TO RCS close 1A RHR HX TO RCSCOLD LEGS HDR VENTS Q1E11V055BCOLD LEGS HDR VENTS Q1E11V055Band Q1E11VO55A. (121 ft, AUXand Q1E11VO55A. (121 ft, AUXBLDG piping penetration room)BLDG piping penetration room)Page 4 of 9Page 4 of 93/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 1ATTACHMENT 1 666IFIFIF 1B RHR PUMP air bound, 1B RHR PUMP air bound, 1B RHR PUMP air bound, THENTHENTHEN perform the following. perform the following. perform the following.6.16.1Open 1B RHR PUMP SEAL COOLEROpen 1B RHR PUMP SEAL COOLEROUTLET VENTS Q1E11V080D andOUTLET VENTS Q1E11V080D andQ1E11V080B. (83 ft, AUX BLDGQ1E11V080B. (83 ft, AUX BLDG1B RHR PUMP room)1B RHR PUMP room)6.26.2WHENWHEN air free water is seen, air free water is seen, THENTHEN close 1B RHR PUMP SEAL close 1B RHR PUMP SEALCOOLER OUTLET VENTS Q1E11V080DCOOLER OUTLET VENTS Q1E11V080Dand Q1E11V080B. (83 ft, AUXand Q1E11V080B. (83 ft, AUXBLDG 1B RHR PUMP room)BLDG 1B RHR PUMP room)6.36.3Open 1B RHR HX OUTLET VENTSOpen 1B RHR HX OUTLET VENTSQ1E11V068D and Q1E11V068B. Q1E11V068D and Q1E11V068B. (83 ft, AUX BLDG RHR HX room)(83 ft, AUX BLDG RHR HX room)6.46.4WHENWHEN air free water is seen, air free water is seen, THENTHEN close 1B RHR HX OUTLET close 1B RHR HX OUTLETVENTS Q1E11V068D andVENTS Q1E11V068D andQ1E11V068B. (83 ft, AUX BLDGQ1E11V068B. (83 ft, AUX BLDGRHR HX room)RHR HX room)6.56.5Open 1A RCS LOOP TO 1B RHROpen 1A RCS LOOP TO 1B RHRPUMP HDR VENTS Q1E11V064D andPUMP HDR VENTS Q1E11V064D andQ1E11V064B. (100 ft, AUX BLDGQ1E11V064B. (100 ft, AUX BLDGpiping penetration room, PENpiping penetration room, PEN#18)#18)6.66.6WHENWHEN air free water is seen, air free water is seen, THENTHEN close 1A RCS LOOP TO 1B close 1A RCS LOOP TO 1BRHR PUMP HDR VENTS Q1E11V064DRHR PUMP HDR VENTS Q1E11V064Dand Q1E11V064B. (100 ft, AUXand Q1E11V064B. (100 ft, AUXBLDG piping penetration room)BLDG piping penetration room)6.76.7Open 1B RHR HX TO RCS COLDOpen 1B RHR HX TO RCS COLDLEGS HDR VENTS Q1E11V058B andLEGS HDR VENTS Q1E11V058B andQ1E11VO58A. (121 ft, AUX BLDGQ1E11VO58A. (121 ft, AUX BLDGpiping penetration room, PENpiping penetration room, PEN#17)#17)6.86.8WHENWHEN air free water is seen, air free water is seen, THENTHEN close 1B RHR HX TO RCS close 1B RHR HX TO RCSCOLD LEGS HDR VENTS Q1E11V058BCOLD LEGS HDR VENTS Q1E11V058Band Q1E11VO58A. (121 ft, AUXand Q1E11VO58A. (121 ft, AUXBLDG piping penetration room)BLDG piping penetration room)Page 5 of 9Page 5 of 93/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 1ATTACHMENT 1 777IFIFIF RWST aligned to air bound RWST aligned to air bound RWST aligned to air bound77IFIF RCS aligned to air bound RCS aligned to air boundtrain, train, train, train, train, THENTHENTHEN prepare the air bound pump prepare the air bound pump prepare the air bound pumpTHENTHEN prepare the air bound pump prepare the air bound pumpfor starting as follows.for starting as follows.for starting as follows.for starting as follows.for starting as follows.7.17.1Verify closed RCS supply toVerify closed RCS supply toa)a)Verify air bound train RHRVerify air bound train RHRair bound train.air bound train.HX BYP FLOW - ADJUSTED TOHX BYP FLOW - ADJUSTED TO15% OPEN.15% OPEN.Air Bound Train Air Bound Train A A B B 1C(1A) RCS LOOP 1C(1A) RCS LOOP Air Bound Train Air Bound Train A A B B TO 1A(1B) RHR PUMPTO 1A(1B) RHR PUMP 1A(1B) RHR HX 1A(1B) RHR HX Q1E11MOV Q1E11MOV []8701A[]8701A[]8702A[]8702ABYP FLOW BYP FLOW []8701B[]8701B[]8702B[]8702BFK FK []605A[]605A[]605B[]605B7.27.2Verify air bound train RHR HXVerify air bound train RHR HXb)b)Verify air bound train RHR Verify air bound train RHR BYP FLOW - ADJUSTED TO 15%BYP FLOW - ADJUSTED TO 15%HX discharge valve -HX discharge valve -OPEN.OPEN.ADJUSTED CLOSED.ADJUSTED CLOSED.Air Bound Train Air Bound Train A A B B Air Bound Train Air Bound Train A A B B 1A(1B) RHR HX 1A(1B) RHR HX 1A(1B) RHR HX TO RCS1A(1B) RHR HX TO RCS BYP FLOW BYP FLOW DISCH VLV DISCH VLV FK FK []605A[]605A[]605B[]605BHIK HIK []603A[]603A[]603B[]603B7.37.3Verify air bound train RHR HXVerify air bound train RHR HXc)c)Proceed to step 8.Proceed to step 8.discharge valve - ADJUSTEDdischarge valve - ADJUSTEDCLOSED.CLOSED.Air Bound Train Air Bound Train A A B B 1A(1B) RHR HX TO RCS1A(1B) RHR HX TO RCS DISCH VLV DISCH VLV HIK HIK []603A[]603A[]603B[]603B7.47.4Open fully RWST supply to airOpen fully RWST supply to airbound train.bound train.Air Bound Train Air Bound Train A A B B RWST TO RWST TO 1A(1B) RHR PUMP 1A(1B) RHR PUMP Q1E11MOV Q1E11MOV []8809A[]8809A[]8809B[]8809BPage 6 of 9Page 6 of 93/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 1ATTACHMENT 1****************************************************************************************************************************************************************************CAUTIONCAUTION::Excessive start/stop cycling of RHR PUMPs may cause motor damage.Excessive start/stop cycling of RHR PUMPs may cause motor damage.**************************************************************************************************************************************************************************** 888Run air bound RHR PUMP for 10Run air bound RHR PUMP for 10Run air bound RHR PUMP for 10seconds.seconds.seconds. 999IFIFIF 1A RHR PUMP was run for 10 1A RHR PUMP was run for 10 1A RHR PUMP was run for 10seconds, seconds, seconds, THENTHENTHEN perform the following. perform the following. perform the following.9.19.1Open 1A RHR PUMP SEAL COOLEROpen 1A RHR PUMP SEAL COOLEROUTLET VENTS Q1E11V080C andOUTLET VENTS Q1E11V080C andQ1E11V080A. (83 ft, AUX BLDGQ1E11V080A. (83 ft, AUX BLDG1A RHR PUMP room)1A RHR PUMP room)9.29.2WHENWHEN air free water is seen, air free water is seen, THENTHEN close 1A RHR PUMP SEAL close 1A RHR PUMP SEALCOOLER OUTLET VENTS Q1E11V080CCOOLER OUTLET VENTS Q1E11V080Cand Q1E11V080A. (83 ft, AUXand Q1E11V080A. (83 ft, AUXBLDG 1A RHR PUMP room)BLDG 1A RHR PUMP room)9.39.3Open 1A RHR HX OUTLET VENTSOpen 1A RHR HX OUTLET VENTSQ1E11V068C and Q1E11V068A. Q1E11V068C and Q1E11V068A. (83 ft, AUX BLDG RHR HX room)(83 ft, AUX BLDG RHR HX room)9.49.4WHENWHEN air free water is seen, air free water is seen, THENTHEN close 1A RHR HX OUTLET close 1A RHR HX OUTLETVENTS Q1E11V068C andVENTS Q1E11V068C andQ1E11V068A. (83 ft, AUX BLDGQ1E11V068A. (83 ft, AUX BLDGRHR HX room)RHR HX room)9.59.5Open 1C RCS LOOP TO 1A RHROpen 1C RCS LOOP TO 1A RHRPUMP HDR VENTS Q1E11V064C andPUMP HDR VENTS Q1E11V064C andQ1E11V064A. (100 ft, AUX BLDGQ1E11V064A. (100 ft, AUX BLDGpiping penetration room, PENpiping penetration room, PEN#16)#16)9.69.6WHENWHEN air free water is seen, air free water is seen, THENTHEN close 1C RCS LOOP TO 1A close 1C RCS LOOP TO 1ARHR PUMP HDR VENTS Q1E11V064CRHR PUMP HDR VENTS Q1E11V064Cand Q1E11V064A. (100 ft, AUXand Q1E11V064A. (100 ft, AUXBLDG piping penetration room)BLDG piping penetration room)Step 9 continued on next page.Step 9 continued on next page.Page 7 of 9Page 7 of 93/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 1ATTACHMENT 19.79.7Open 1A RHR HX TO RCS COLDOpen 1A RHR HX TO RCS COLDLEGS HDR VENTS Q1E11V055B andLEGS HDR VENTS Q1E11V055B andQ1E11VO55A. (121 ft, AUX BLDGQ1E11VO55A. (121 ft, AUX BLDGpiping penetration room, PENpiping penetration room, PEN#15)#15)9.89.8WHENWHEN air free water is seen, air free water is seen, THENTHEN close 1A RHR HX TO RCS close 1A RHR HX TO RCSCOLD LEGS HDR VENTS Q1E11V055BCOLD LEGS HDR VENTS Q1E11V055Band Q1E11VO55A. (121 ft, AUXand Q1E11VO55A. (121 ft, AUXBLDG piping penetration room)BLDG piping penetration room) 101010IFIFIF 1B RHR PUMP was run for 10 1B RHR PUMP was run for 10 1B RHR PUMP was run for 10seconds, seconds, seconds, THENTHENTHEN perform the following. perform the following. perform the following.10.110.1Open 1B RHR PUMP SEAL COOLEROpen 1B RHR PUMP SEAL COOLEROUTLET VENTS Q1E11V080D andOUTLET VENTS Q1E11V080D andQ1E11V080B. (83 ft, AUX BLDGQ1E11V080B. (83 ft, AUX BLDG1B RHR PUMP room)1B RHR PUMP room)10.210.2WHENWHEN air free water is seen, air free water is seen, THENTHEN close 1B RHR PUMP SEAL close 1B RHR PUMP SEALCOOLER OUTLET VENTS Q1E11V080DCOOLER OUTLET VENTS Q1E11V080Dand Q1E11V080B. (83 ft, AUXand Q1E11V080B. (83 ft, AUXBLDG 1B RHR PUMP room)BLDG 1B RHR PUMP room)10.310.3Open 1B RHR HX OUTLET VENTSOpen 1B RHR HX OUTLET VENTSQ1E11V068D and Q1E11V068B. Q1E11V068D and Q1E11V068B. (83 ft, AUX BLDG RHR HX room)(83 ft, AUX BLDG RHR HX room)10.410.4WHENWHEN air free water is seen, air free water is seen, THENTHEN close 1B RHR HX OUTLET close 1B RHR HX OUTLETVENTS Q1E11V068D andVENTS Q1E11V068D andQ1E11V068B. (83 ft, AUX BLDGQ1E11V068B. (83 ft, AUX BLDGRHR HX room)RHR HX room)10.510.5Open 1A RCS LOOP TO 1B RHROpen 1A RCS LOOP TO 1B RHRPUMP HDR VENTS Q1E11V064D andPUMP HDR VENTS Q1E11V064D andQ1E11V064B. (100 ft, AUX BLDGQ1E11V064B. (100 ft, AUX BLDGpiping penetration room, PENpiping penetration room, PEN#18)#18)Step 10 continued on next page.Step 10 continued on next page.Page 8 of 9Page 8 of 93/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 1ATTACHMENT 110.610.6WHENWHEN air free water is seen, air free water is seen, THENTHEN close 1A RCS LOOP TO 1B close 1A RCS LOOP TO 1BRHR PUMP HDR VENTS Q1E11V064DRHR PUMP HDR VENTS Q1E11V064Dand Q1E11V064B. (100 ft, AUXand Q1E11V064B. (100 ft, AUXBLDG piping penetration room)BLDG piping penetration room)10.710.7Open 1B RHR HX TO RCS COLDOpen 1B RHR HX TO RCS COLDLEGS HDR VENTS Q1E11V058B andLEGS HDR VENTS Q1E11V058B andQ1E11VO58A. (121 ft, AUX BLDGQ1E11VO58A. (121 ft, AUX BLDGpiping penetration room, PENpiping penetration room, PEN#17)#17)10.810.8WHENWHEN air free water is seen, air free water is seen, THENTHEN close 1B RHR HX TO RCS close 1B RHR HX TO RCSCOLD LEGS HDR VENTS Q1E11V058BCOLD LEGS HDR VENTS Q1E11V058Band Q1E11VO58A. (121 ft, AUXand Q1E11VO58A. (121 ft, AUXBLDG piping penetration room)BLDG piping penetration room) 111111IFIFIF no air seen, no air seen, no air seen, 1111Return to step 8.Return to step 8.THENTHENTHEN notify control room that notify control room that notify control room thatventing is complete.venting is complete.venting is complete. 121212WHENWHENWHEN desired, desired, desired, THENTHENTHEN remove RHR vent rigs. remove RHR vent rigs. remove RHR vent rigs. 131313WHENWHENWHEN desired, desired, desired, THENTHENTHEN verify vent lines capped. verify vent lines capped. verify vent lines capped. 141414Notify control room thatNotify control room thatNotify control room thatATTACHMENT 1 is complete.ATTACHMENT 1 is complete.ATTACHMENT 1 is complete.-END- -END- Page 9 of 9Page 9 of 93/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 2ATTACHMENT 2RWST TO RCS GRAVITY FEEDRWST TO RCS GRAVITY FEED****************************************************************************************************************************************************************************CAUTIONCAUTION::Gravity feed may not be sufficient to prevent core uncovery if aGravity feed may not be sufficient to prevent core uncovery if asecondary heat sink or a hot leg vent path is not available.secondary heat sink or a hot leg vent path is not available.****************************************************************************************************************************************************************************NOTE:NOTE:ATTACHMENT 2, FIGURE 1 and ATTACHMENT 2, FIGURE 2 provide expectedATTACHMENT 2, FIGURE 1 and ATTACHMENT 2, FIGURE 2 provide expectedgravity feed flow rates.gravity feed flow rates.RWST TO 1A(1B) RHR PUMP Q1E11MOV8809A and Q1E11MOV8809B may beRWST TO 1A(1B) RHR PUMP Q1E11MOV8809A and Q1E11MOV8809B may belocally adjusted to control gravity feed flow at the Shiftlocally adjusted to control gravity feed flow at the ShiftSupervisor's discretion.Supervisor's discretion. 111IFIFIF A train RHR to RCS hot leg A train RHR to RCS hot leg A train RHR to RCS hot leg11IFIF B train RHR to RCS hot leg B train RHR to RCS hot legflow path available, flow path available, flow path available, flow path available, flow path available, THENTHENTHEN perform the following. perform the following. perform the following.THENTHEN perform the following. perform the following.1.11.1Open 1C RCS LOOP TO 1A RHROpen 1C RCS LOOP TO 1A RHRa)a)Open 1A RCS LOOP TO 1B RHROpen 1A RCS LOOP TO 1B RHRPUMP Q1E11MOV8701A andPUMP Q1E11MOV8701A andPUMP Q1E11MOV8702A andPUMP Q1E11MOV8702A andQ1E11MOV8701B.Q1E11MOV8701B.Q1E11MOV8702B.Q1E11MOV8702B.1.21.2Open RWST TO 1A RHR PUMPOpen RWST TO 1A RHR PUMPb)b)Open RWST TO 1B RHR PUMPOpen RWST TO 1B RHR PUMPQ1E11MOV8809A to establishQ1E11MOV8809A to establishQ1E11MOV8809B to establishQ1E11MOV8809B to establishgravity feed.gravity feed.gravity feed.gravity feed. 222IFIFIF gravity feed established, gravity feed established, gravity feed established, THENTHENTHEN proceed to step 4. proceed to step 4. proceed to step 4.Page 1 of 4Page 1 of 43/15/201300:29UNIT 1 StepStepStepAction/Expected ResponseAction/Expected ResponseAction/Expected ResponseResponse NOT ObtainedResponse NOT ObtainedResponse NOT ObtainedFNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 2ATTACHMENT 2 333IFIFIF A train RHR to RCS cold leg A train RHR to RCS cold leg A train RHR to RCS cold leg33IFIF B train RHR to RCS cold leg B train RHR to RCS cold legflow path available, flow path available, flow path available, flow path available, flow path available, THENTHENTHEN perform the following. perform the following. perform the following.THENTHEN perform the following. perform the following.3.13.1Verify 1C RCS LOOP TO 1A RHRVerify 1C RCS LOOP TO 1A RHRa)a)Verify 1A RCS LOOP TO 1BVerify 1A RCS LOOP TO 1BPUMP Q1E11MOV8701A andPUMP Q1E11MOV8701A andRHR PUMP Q1E11MOV8702A andRHR PUMP Q1E11MOV8702A andQ1E11MOV8701B - CLOSED.Q1E11MOV8701B - CLOSED.Q1E11MOV8702B - CLOSED.Q1E11MOV8702B - CLOSED.3.23.2Verify 1A RHR PUMP MINIFLOWVerify 1A RHR PUMP MINIFLOWb)b)Verify 1B RHR PUMP MINIFLOWVerify 1B RHR PUMP MINIFLOWQ1E11FCV602A - OPEN.Q1E11FCV602A - OPEN.Q1E11FCV602B - OPEN.Q1E11FCV602B - OPEN.3.33.3Verify 1A RHR HX TO RCS COLDVerify 1A RHR HX TO RCS COLDc)c)Verify 1B RHR HX TO RCSVerify 1B RHR HX TO RCSLEGS ISO Q1E11MOV8888A - OPEN.LEGS ISO Q1E11MOV8888A - OPEN.COLD LEGS ISO Q1E11MOV8888BCOLD LEGS ISO Q1E11MOV8888B- OPEN.- OPEN.3.43.4Open RWST TO 1A RHR PUMPOpen RWST TO 1A RHR PUMPQ1E11MOV8809A to establishQ1E11MOV8809A to establishd)d)Open RWST TO 1B RHR PUMPOpen RWST TO 1B RHR PUMPgravity feed.gravity feed.Q1E11MOV8809B to establishQ1E11MOV8809B to establishgravity feed.gravity feed. 444Notify control room thatNotify control room thatNotify control room thatATTACHMENT 2 is complete.ATTACHMENT 2 is complete.ATTACHMENT 2 is complete.-END- -END- Page 2 of 4Page 2 of 43/15/201300:29UNIT 1 FNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 2ATTACHMENT 2FIGURE 1FIGURE 1 Page 3 of 4Page 3 of 43/15/201300:29UNIT 1 FNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 2ATTACHMENT 2FIGURE 2FIGURE 2 Page 4 of 4Page 4 of 43/15/201300:29UNIT 1 FNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 3ATTACHMENT 3Time to Core SaturationTime to Core Saturation111Time to Core Saturation:Time to Core Saturation:Time to Core Saturation:1.11.1Tables A and B provide estimates of the time to core boilingTables A and B provide estimates of the time to core boilingfollowing a loss RHR capability for two cases:following a loss RHR capability for two cases:1.1.11.1.1TABLE ATABLE ATABLE A provides a Time to Saturation as a function of time after provides a Time to Saturation as a function of time aftershutdown for a full core immediately after shutdown for ashutdown for a full core immediately after shutdown for arefueling.refueling.1.1.21.1.2TABLE BTABLE BTABLE B provides a Time to Saturation as a function of time after provides a Time to Saturation as a function of time aftershutdown for a core in which one third of the spent fuel has beenshutdown for a core in which one third of the spent fuel has beenreplaced with new fuel.replaced with new fuel.1.21.2Both cases are evaluated for conditions when RCS level is at mid loopBoth 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(122'9"), at three feet below the reactor flange (126'7"), and whenthe reactor cavity is full.the reactor cavity is full.1.31.3Both cases are also evaluated for three assumed initial temperatures:Both cases are also evaluated for three assumed initial temperatures:100100F, 120F, 120F, and 140F, and 140F.F.1.41.4These figures can be used to estimate the amount of time availableThese figures can be used to estimate the amount of time availablefor operator action to restore RHR before additional protectivefor operator action to restore RHR before additional protectivemeasures must be taken.measures must be taken.Page 1 of 7Page 1 of 73/15/201300:29UNIT 1 FNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 3ATTACHMENT 3Time to Core SaturationTime to Core Saturation TABLE ATABLE ATABLE A---POWER UPRATED UNIT---POWER UPRATED UNIT TIME TO SATURATION: TIME TO SATURATION: FULL COREFULL CORE ASSUMED INITIAL TEMPERATURE= ASSUMED INITIAL TEMPERATURE=100100FF Time After Time After Time to Saturation Time to Saturation Time to Saturation Time to Saturation Time to SaturationTime to SaturationShutdown (hours)Shutdown (hours)at midloop (mins) at midloop (mins) 3' below flange 3' below flange full Rx cavity full Rx cavity (mins) (mins) (hours) (hours) 40 40 7.7 7.7 10.5 10.5 5.6 5.6 60 60 8.7 8.7 11.9 11.9 6.3 6.3 80 80 9.5 9.5 13.0 13.0 6.9 6.9 100 100 10.4 10.4 14.2 14.2 7.5 7.5 120 120 11.3 11.3 15.4 15.4 8.2 8.2 140 140 11.9 11.9 16.3 16.3 8.6 8.6 160 160 12.7 12.7 17.4 17.4 9.2 9.2 180 180 13.3 13.3 18.2 18.2 9.6 9.6 200 200 13.9 13.9 19.0 19.0 10.1 10.1 336 336 17.1 17.1 23.4 23.4 12.4 12.4 504 504 20.8 20.8 28.5 28.5 15.1 15.1 VOLUME REFERENCE TABLE VOLUME REFERENCE TABLEMIDLOOP VOLUME(FTMIDLOOP VOLUME(FT33) ) 945 945 VOLUME 3FT BELOW FLANGE(FTVOLUME 3FT BELOW FLANGE(FT33) ) 348 348 TOTAL= TOTAL= 1293 1293 VOLUME FULL REACTOR CAVITY(FTVOLUME FULL REACTOR CAVITY(FT33) ) 39750 39750 TOTAL= TOTAL= 41043 41043 Page 2 of 7Page 2 of 73/15/201300:29UNIT 1 FNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 3ATTACHMENT 3Time to Core SaturationTime to Core Saturation TABLE ATABLE ATABLE A---POWER UPRATED UNIT---POWER UPRATED UNIT TIME TO SATURATION: TIME TO SATURATION: FULL COREFULL CORE ASSUMED INITIAL TEMPERATURE= ASSUMED INITIAL TEMPERATURE=120120FF Time After Time After Time to Saturation Time to Saturation Time to Saturation Time to Saturation Time to SaturationTime to SaturationShutdown (hours)Shutdown (hours)at midloop (mins) at midloop (mins) 3' below flange 3' below flange full Rx cavity full Rx cavity (mins) (mins) (hours) (hours) 40 40 6.3 6.3 8.6 8.6 4.5 4.5 60 60 7.1 7.1 9.8 9.8 5.2 5.2 80 80 7.8 7.8 10.6 10.6 5.6 5.6 100 100 8.5 8.5 11.7 11.7 6.2 6.2 120 120 9.2 9.2 12.6 12.6 6.7 6.7 140 140 9.8 9.8 13.4 13.4 7.1 7.1 160 160 10.4 10.4 14.2 14.2 7.5 7.5 180 180 10.9 10.9 14.9 14.9 7.9 7.9 200 200 11.4 11.4 15.6 15.6 8.2 8.2 336 336 14.0 14.0 19.1 19.1 10.1 10.1 504 504 17.0 17.0 23.3 23.3 12.3 12.3 VOLUME REFERENCE TABLE VOLUME REFERENCE TABLEMIDLOOP VOLUME(FTMIDLOOP VOLUME(FT33) ) 945 945 VOLUME 3FT BELOW FLANGE(FTVOLUME 3FT BELOW FLANGE(FT33) ) 348 348 TOTAL= TOTAL= 1293 1293 VOLUME FULL REACTOR CAVITY(FTVOLUME FULL REACTOR CAVITY(FT33) ) 39750 39750 TOTAL= TOTAL= 41043 41043 Page 3 of 7Page 3 of 73/15/201300:29UNIT 1 FNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 3ATTACHMENT 3Time to Core SaturationTime to Core Saturation TABLE ATABLE ATABLE A---POWER UPRATED UNIT---POWER UPRATED UNIT TIME TO SATURATION: TIME TO SATURATION: FULL COREFULL CORE ASSUMED INITIAL TEMPERATURE= ASSUMED INITIAL TEMPERATURE=140140FF Time After Time After Time to Saturation Time to Saturation Time to Saturation Time to Saturation Time to SaturationTime to SaturationShutdown (hours)Shutdown (hours)at midloop (mins) at midloop (mins) 3' below flange 3' below flange full Rx cavity full Rx cavity (mins) (mins) (hours) (hours) 40 40 4.9 4.9 6.7 6.7 3.5 3.5 60 60 5.6 5.6 7.6 7.6 4.0 4.0 80 80 6.1 6.1 8.3 8.3 4.4 4.4 100 100 6.6 6.6 9.1 9.1 4.8 4.8 120 120 7.2 7.2 9.8 9.8 5.2 5.2 140 140 7.6 7.6 10.4 10.4 5.5 5.5 160 160 8.1 8.1 11.1 11.1 5.9 5.9 180 180 8.5 8.5 11.6 11.6 6.1 6.1 200 200 8.9 8.9 12.1 12.1 6.4 6.4 336 336 10.9 10.9 14.9 14.9 7.9 7.9 504 504 13.3 13.3 18.2 18.2 9.6 9.6 VOLUME REFERENCE TABLE VOLUME REFERENCE TABLEMIDLOOP VOLUME(FTMIDLOOP VOLUME(FT33) ) 945 945 VOLUME 3FT BELOW FLANGE(FTVOLUME 3FT BELOW FLANGE(FT33) ) 348 348 TOTAL= TOTAL= 1293 1293 VOLUME FULL REACTOR CAVITY(FTVOLUME FULL REACTOR CAVITY(FT33) ) 39750 39750 TOTAL= TOTAL= 41043 41043 Page 4 of 7Page 4 of 73/15/201300:29UNIT 1 FNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 3ATTACHMENT 3Time to Core SaturationTime to Core Saturation TABLE BTABLE BTABLE B---POWER UPRATED UNIT---POWER UPRATED UNIT TIME TO SATURATION: ONE THIRD NEW FUEL TIME TO SATURATION: ONE THIRD NEW FUEL ASSUMED INITIAL TEMPERATURE= ASSUMED INITIAL TEMPERATURE=100100FF Time After Time After Time to Saturation Time to Saturation Time to Saturation Time to Saturation Time to SaturationTime to SaturationShutdown (hours)Shutdown (hours)at midloop (mins) at midloop (mins) 3' below flange 3' below flange full Rx cavity full Rx cavity (mins) (mins) (hours) (hours) 100 100 15.6 15.6 21.4 21.4 11.3 11.3 200 200 20.9 20.9 28.5 28.5 15.1 15.1 300 300 24.7 24.7 33.7 33.7 17.8 17.8 400 400 27.5 27.5 37.6 37.6 19.9 19.9 500 500 31.1 31.1 42.5 42.5 22.5 22.5 600 600 34.5 34.5 47.3 47.3 25.0 25.0 700 700 37.2 37.2 51.0 51.0 27.0 27.0 800 800 40.4 40.4 55.3 55.3 29.2 29.2 VOLUME REFERENCE TABLE VOLUME REFERENCE TABLEMIDLOOP VOLUME(FTMIDLOOP VOLUME(FT33) ) 945 945 VOLUME 3FT BELOW FLANGE(FTVOLUME 3FT BELOW FLANGE(FT33) ) 348 348 TOTAL= TOTAL= 1293 1293 VOLUME FULL REACTOR CAVITY(FTVOLUME FULL REACTOR CAVITY(FT33) ) 39750 39750 TOTAL= TOTAL= 41043 41043 Page 5 of 7Page 5 of 73/15/201300:29UNIT 1 FNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 3ATTACHMENT 3Time to Core SaturationTime to Core Saturation TABLE BTABLE BTABLE B---POWER UPRATED UNIT---POWER UPRATED UNIT TIME TO SATURATION: ONE THIRD NEW FUEL TIME TO SATURATION: ONE THIRD NEW FUEL ASSUMED INITIAL TEMPERATURE= ASSUMED INITIAL TEMPERATURE=120120FF Time After Time After Time to Saturation Time to Saturation Time to Saturation Time to Saturation Time to SaturationTime to SaturationShutdown (hours)Shutdown (hours)at midloop (mins) at midloop (mins) 3' below flange 3' below flange full Rx cavity full Rx cavity (mins) (mins) (hours) (hours) 100 100 12.8 12.8 17.5 17.5 9.2 9.2 200 200 17.1 17.1 23.4 23.4 12.4 12.4 300 300 20.2 20.2 27.6 27.6 14.6 14.6 400 400 22.5 22.5 30.8 30.8 16.3 16.3 500 500 25.4 25.4 34.8 34.8 18.4 18.4 600 600 28.3 28.3 38.7 38.7 20.5 20.5 700 700 30.5 30.5 41.7 41.7 22.1 22.1 800 800 33.0 33.0 45.2 45.2 23.9 23.9 VOLUME REFERENCE TABLE VOLUME REFERENCE TABLEMIDLOOP VOLUME(FTMIDLOOP VOLUME(FT33) ) 945 945 VOLUME 3FT BELOW FLANGE(FTVOLUME 3FT BELOW FLANGE(FT33) ) 348 348 TOTAL= TOTAL= 1293 1293 VOLUME FULL REACTOR CAVITY(FTVOLUME FULL REACTOR CAVITY(FT33) ) 39750 39750 TOTAL= TOTAL= 41043 41043 Page 6 of 7Page 6 of 73/15/201300:29UNIT 1 FNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 3ATTACHMENT 3Time to Core SaturationTime to Core Saturation TABLE BTABLE BTABLE B---POWER UPRATED UNIT---POWER UPRATED UNIT TIME TO SATURATION: ONE THIRD NEW FUEL TIME TO SATURATION: ONE THIRD NEW FUEL ASSUMED INITIAL TEMPERATURE= ASSUMED INITIAL TEMPERATURE=140140FF Time After Time After Time to Saturation Time to Saturation Time to Saturation Time to Saturation Time to SaturationTime to SaturationShutdown (hours)Shutdown (hours)at midloop (mins) at midloop (mins) 3' below flange 3' below flange full Rx cavity full Rx cavity (mins) (mins) (hours) (hours) 100 100 10.0 10.0 13.6 13.6 7.2 7.2 200 200 13.3 13.3 18.2 18.2 9.6 9.6 300 300 15.7 15.7 21.5 21.5 11.4 11.4 400 400 17.5 17.5 24.0 24.0 12.7 12.7 500 500 19.8 19.8 27.1 27.1 14.3 14.3 600 600 22.0 22.0 30.1 30.1 15.9 15.9 700 700 23.7 23.7 32.5 32.5 17.2 17.2 800 800 25.7 25.7 35.2 35.2 18.6 18.6 VOLUME REFERENCE TABLE VOLUME REFERENCE TABLEMIDLOOP VOLUME(FTMIDLOOP VOLUME(FT33) ) 945 945 VOLUME 3FT BELOW FLANGE(FTVOLUME 3FT BELOW FLANGE(FT33) ) 348 348 TOTAL= TOTAL= 1293 1293 VOLUME FULL REACTOR CAVITY(FTVOLUME FULL REACTOR CAVITY(FT33) ) 39750 39750 TOTAL= TOTAL= 41043 41043 -END- -END- Page 7 of 7Page 7 of 73/15/201300:29UNIT 1 FNP-1-AOP-12.0FNP-1-AOP-12.0RESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRESIDUAL HEAT REMOVAL SYSTEM MALFUNCTIONRevision 25.0Revision 25.0ATTACHMENT 4ATTACHMENT 4REFERENCES/COMMITMENTSREFERENCES/COMMITMENTS1110007011 Commmitment completed by Rev 1&2 of this procedure0007011 Commmitment completed by Rev 1&2 of this procedure0007011 Commmitment completed by Rev 1&2 of this procedure2220007012 PROCEDURE STEPS, step 19 Caution prior to the step0007012 PROCEDURE STEPS, step 19 Caution prior to the step0007012 PROCEDURE STEPS, step 19 Caution prior to the step3330007013 PROCEDURE STEPS, step 150007013 PROCEDURE STEPS, step 150007013 PROCEDURE STEPS, step 154440007230, 0007236 Entire procedure fulfills these commitments0007230, 0007236 Entire procedure fulfills these commitments0007230, 0007236 Entire procedure fulfills these commitments5550007569 PROCEDURE STEPS, step 21.10007569 PROCEDURE STEPS, step 21.10007569 PROCEDURE STEPS, step 21.16660007570 PROCEDURE STEPS, step 220007570 PROCEDURE STEPS, step 220007570 PROCEDURE STEPS, step 227770007583 PROCEDURE STEPS, step 310007583 PROCEDURE STEPS, step 310007583 PROCEDURE STEPS, step 318880007584, 0007594, 0009103 Entire procedure fulfills these commitments0007584, 0007594, 0009103 Entire procedure fulfills these commitments0007584, 0007594, 0009103 Entire procedure fulfills these commitments-END- -END- Page 1 of 1Page 1 of 13/15/201300:29UNIT 1 FNP ILT-38 ADMIN Page 1 of 6 Developer S Jackson Date: 4/2/15 NRC Approval SEE NUREG 1021 FORM ES-301-3 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:

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 RO's 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 RO's 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 ELEMENTS: STANDARDS: RESULTS (CIRCLE) START TIME

1. Evaluate the status of Operator A. Operator A is determined to have 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. S / U

2. Evaluate the status of Operator B. Operator B is determined to have 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. S / U

3. Evaluate the status of Operator C. Operator C is determined to have 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. S / U 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 RO's 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 RO's 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 Management Procedure License Administration NMP-TR-406 Version 6.2 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 individual's 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 Operator's 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 plant's 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 Management Procedure License Administration NMP-TR-406 Version 6.2 Page 11 of 28 the plant's 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 individual's 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 hour's 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 Operator's license is placed in an 'Inactive' condition.

Southern Nuclear Operating Company Nuclear Management Procedure License Administration NMP-TR-406 Version 6.2 Page 12 of 28 5.5.5 An ACTIVE license shall require a Licensed Operator to either: Maintain NMP-TR-406-F01 OR Complete NMP-TR-406-F02 OR NMP-TR-406-F03 OR 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: Maintain Medical Certification. Maintain Medical Certification for respirator use per the applicable Medical Services procedures. Have Dosimetry available. 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. Be current in Licensed Operator Continuing Training (LOCT) as demonstrated by showing qualification complete in the Learning Management System (LMS). Be current in respirator medical per the LMS qualifications "S-MEDRES49" OR "S-MEDRES50". Be current in Respirator Training per the LMS Qualification. 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 Management Procedure License Administration NMP-TR-406 Version 6.2 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 Director's 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 71A, 71B, & 71C. Obtains normalized current values (Curve 71A-C) and records them on Attachment 1 of STP-7.0. S / U *2. Record data for power range detector A and detector B from Data sheet 2. Values from PRNI pictures for detector A and detector B of NI-41, 42, & 43 displays recorded on Attachment 1 of STP-7.0. S / U *3. Calculate upper and lower quadrant power tilt ratios. Upper ratio calculated at 1.01 to 1.014 Lower ratio calculated at 1.01 to 1.02 S / U 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 quadrant power tilt ratio. Greater of the above two values Lower: 1.01 to 1.02 entered. S / U 5. Records power level. Current avg power level recorded. S / U *6. Determines acceptance criteria MET. Determination made that acceptance criteria is MET. S / U FNP ILT-38 ADMIN Page 3 of 4 EVALUATION CHECKLIST RESULTS: ELEMENTS: STANDARDS: (CIRCLE) 7. Reports to Shift Supervisor that acceptance criteria is NOT met. Reports to Shift Supervisor that acceptance criteria is MET. QPTR. (CUE: Shift Supervisor acknowledges). S / U 8. Fills out Surveillance Test Review sheet per attached key. Fills out Surveillance Test Review sheet per attached key. S / U 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 PRNI's.

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.

Printed 10/28/2013 at 18:55:00 FARLEYUnit 1SAFETY 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 DateEffective Date: OPERATIONS Responsible Department Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 2 of 15 Printed 10/28/2013 at 18:55:00 VERSION SUMMARY PVR 23.0 DESCRIPTION Updated to fleet template and writer's guide Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 3 of 15 Printed 10/28/2013 at 18:55:00 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 Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 4 of 15 Printed 10/28/2013 at 18:55:00 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 Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 5 of 15 3.0 INITIAL CONDITIONS (continued) Printed 10/28/2013 at 18:55:00 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. ......................................................................................... ______

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 6 of 15 Printed 10/28/2013 at 18:55:00 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.

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 7 of 15 Printed 10/28/2013 at 18:55:00 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 Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 8 of 15 Printed 10/28/2013 at 18:55:00 ATTACHMENT 1Page 1 of 5Quadrant 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. ...................................................................................................................... ______

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 9 of 15 ATTACHMENT 1 Page 2 of 5 Quadrant Power Tilt Ratio Calculation without Plant Computer Printed 10/28/2013 at 18:55:00 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. ........................................... ______

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 Printed 10/28/2013 at 18:55:00 Calculation Sheet Calculation Performed Using: Meter Data/DVM Data (Circle One) UPPER QUADRANT POWER TILT POWER RANGE B Drawer UPPER DET Indicated Current ÷ *UPPER DET 100% Current =UPPER DET Calibrated Output N41 Detector A ÷ N41T = Total Number Operable Upper Detectors Maximum Upper Detector Calibrated Output Upper Quadrant Power Tilt Ratio N42 Detector A ÷ N42T = N43 Detector A ÷ N43T = 1 N44 Detector A ÷ N44T = Average Upper Detector Calibrated Output X = Total Upper Detector Calibrated Output = ÷ = 1 X = *Obtained from Curve 71(A, B, C, D), 0% AFD Current 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 Printed 10/28/2013 at 18:55:00 Calculation Sheet Calculation Performed Using: Meter Data/DVM Data (Circle One) LOWER QUADRANT POWER TILT POWER RANGE B Drawer LOWER DET Indicated Current ÷ *LOWER DET 100% Current = LOWER DET Calibrated Output N41 Detector B ÷ N41B = Total Number Operable Lower Detectors Maximum Lower Detector Calibrated Output Lower Quadrant Power Tilt Ratio N42 Detector B ÷ N42B = N43 Detector B ÷ N43B = 1 N44 Detector B ÷ N44B = Average Lower Detector Calibrated Output X = Total Lower Detector Calibrated Output = ÷ = 1 X = *Obtained from Curve 71(A, B, C, D), 0% AFD Current Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 12 of 15 ATTACHMENT 1 Page 5 of 5 Quadrant Power Tilt Ratio Calculation without Plant Computer Printed 10/28/2013 at 18:55:00 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 Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 13 of 15 Printed 10/28/2013 at 18:55:00 ATTACHMENT 2Page 1 of 2Using 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 Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 14 of 15 ATTACHMENT 2 Page 2 of 2 Using A DVM To Obtain Detector Current Values Printed 10/28/2013 at 18:55:00 NOTE The following formula is used to calculate detector currents: CurrentDetectorCalculatedValue"Current%100,AFD%0"71Curve083.2VoltageDetectorMeasured=x .............. 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 BDetector A Detector B Detector A Detector BN41T 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 Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 15 of 15 Printed 10/28/2013 at 18:55:00 ATTACHMENT 3Page 1 of 1Surveillance Test Review Sheet TECHNICAL SPECIFICATION REFERENCE SR 3.2.4.1 MODE(S) REQUIRING TEST: 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

FARLEYUnit 1SAFETY RELATED FNP-1-STP-7.0 Quadrant Power Tilt Ratio Calculation Special Considerations: PROCEDURE LEVEL OF USE CLASSIFICATION PER NMP-AP-003 CATEGORY SECTIONS Continuous ALL Reference NONE Information NONE VERSION SUMMARY PVR 23.0 DESCRIPTION TABLE OF CONTENTS 1.0 PURPOSE**2.0 PRECAUTIONS AND LIMITATIONS (SR 3.2.4.1)3.0 INITIAL CONDITIONS (OR 1-98-498)(OR 1-98-498)(OR 1-98-498)NOTE

3.0 INITIAL CONDITIONS (continued)

NOTE 4.0 INSTRUCTIONS 4.1 QPTR Determination Using The IPC. NOTES OpenCheck**go toClickIncludeGo to NOTE 4.2 QPTR Determination Using Manual Calculation: CalculateGo to4.3 Determination Of QPTR Acceptance Criteria: NOTE (NL-10-0406, dated 2/26/2010)CheckACCEPTANCE CRITERIA NOTE 5.0 ACCEPTANCE CRITERIA 6.0 RECORDS QA Record (X) Non-QA Record (X)Record Generated Retention Time R-Type

7.0 REFERENCES

Quadrant Power Tilt Ratio Calculation without Plant Computer NOTE **ObtainEnterNOTE Performenter********CAUTION enterEnter Quadrant Power Tilt Ratio Calculation without Plant Computer Calculate***RecordACCEPTANCE CRITERIA Record Quadrant Power Tilt Ratio Calculation without Plant Computer Calculation Sheet UPPER QUADRANT POWER TILT POWER RANGE B Drawer UPPER DET Indicated Current ÷ *UPPER DET 100% Current =UPPER DET Calibrated Output ÷ =÷ =÷ =÷ =X =÷= X =

Quadrant Power Tilt Ratio Calculation without Plant Computer Calculation Sheet LOWER QUADRANT POWER TILT POWER RANGE B Drawer LOWER DET Indicated Current ÷ *LOWER DET 100% Current = LOWER DET Calibrated Output ÷ =÷ =÷ =÷ =X =÷= X =

Quadrant Power Tilt Ratio Calculation without Plant Computer Calculation Sheet ACCEPTANCE CRITERIA Using A DVM To Obtain Detector Current Values NOTE CAUTIONS **connectNOTE connectRecordconnectRecord Using A DVM To Obtain Detector Current Values NOTE CurrentDetectorCalculatedValue"Current%100,AFD%0"71Curve083.2VoltageDetectorMeasured=xperformCalculateRecord Surveillance Test Review Sheet

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 applicant's 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 71A, 71B, & 71C. Obtains normalized current values (Curve 71A-C) and records them on Attachment 1 of STP-7.0. S / U *2. Record data for power range detector A and detector B from Data sheet 2. Values from PRNI pictures for detector A and detector B of NI-41, 42, & 43 displays recorded on Attachment 1 of STP-7.0. S / U *3. Calculate upper and lower quadrant power tilt ratios. Upper ratio calculated at 1.03 to 1.04 Lower ratio calculated at 1.01 to 1.02 S / U *4. Enter the greater of the upper or lower quadrant power tilt ratio. Greater of the above two values Lower: 1.03 to 1.04 entered. S / U 5. Records power level. Current avg power level recorded: 72-73%. S / U *6. Determines acceptance criteria NOT MET. Determination made that acceptance criteria is NOT MET. S / U 7. Reports to Shift Supervisor that acceptance criteria is NOT met. Reports to Shift Supervisor that acceptance criteria is NOT MET. (CUE: Shift Supervisor acknowledges). S / U FNP ILT-38 ADMIN Page 3 of 6 EVALUATION CHECKLIST RESULTS: ELEMENTS: STANDARDS: (CIRCLE) 8. Fills out Surveillance Test Review sheet per attached key. Fills out Surveillance Test Review sheet per attached key. (If applicant states they would write a CR then CUE: CR#123456 has been written) S / U TECH SPEC EVALUATION: (The Tech Spec will be in the examiner's key package) *9. Evaluates Tech Spec 3.2.4 - Quadrant Power Tilt Ratio (QPTR). The QTPR shall be < 1.02. Determines LCO 3.2.4 Condition A applies but no power reduction is required. S / U 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 PRNI's. 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 facility's 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.

Printed 10/28/2013 at 18:55:00 FARLEYUnit 1SAFETY 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 DateEffective Date: OPERATIONS Responsible Department Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 2 of 15 Printed 10/28/2013 at 18:55:00 VERSION SUMMARY PVR 23.0 DESCRIPTION Updated to fleet template and writer's guide Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 3 of 15 Printed 10/28/2013 at 18:55:00 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 Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 4 of 15 Printed 10/28/2013 at 18:55:00 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 Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 5 of 15 3.0 INITIAL CONDITIONS (continued) Printed 10/28/2013 at 18:55:00 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. ......................................................................................... ______

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 6 of 15 Printed 10/28/2013 at 18:55:00 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.

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 7 of 15 Printed 10/28/2013 at 18:55:00 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 Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 8 of 15 Printed 10/28/2013 at 18:55:00 ATTACHMENT 1Page 1 of 5Quadrant 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. ...................................................................................................................... ______

Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 9 of 15 ATTACHMENT 1 Page 2 of 5 Quadrant Power Tilt Ratio Calculation without Plant Computer Printed 10/28/2013 at 18:55:00 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. ........................................... ______

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 Printed 10/28/2013 at 18:55:00 Calculation Sheet Calculation Performed Using: Meter Data/DVM Data (Circle One) UPPER QUADRANT POWER TILT POWER RANGE B Drawer UPPER DET Indicated Current ÷ *UPPER DET 100% Current =UPPER DET Calibrated Output N41 Detector A ÷ N41T = Total Number Operable Upper Detectors Maximum Upper Detector Calibrated Output Upper Quadrant Power Tilt Ratio N42 Detector A ÷ N42T = N43 Detector A ÷ N43T = 1 N44 Detector A ÷ N44T = Average Upper Detector Calibrated Output X = Total Upper Detector Calibrated Output = ÷ = 1 X = *Obtained from Curve 71(A, B, C, D), 0% AFD Current 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 Printed 10/28/2013 at 18:55:00 Calculation Sheet Calculation Performed Using: Meter Data/DVM Data (Circle One) LOWER QUADRANT POWER TILT POWER RANGE B Drawer LOWER DET Indicated Current ÷ *LOWER DET 100% Current = LOWER DET Calibrated Output N41 Detector B ÷ N41B = Total Number Operable Lower Detectors Maximum Lower Detector Calibrated Output Lower Quadrant Power Tilt Ratio N42 Detector B ÷ N42B = N43 Detector B ÷ N43B = 1 N44 Detector B ÷ N44B = Average Lower Detector Calibrated Output X = Total Lower Detector Calibrated Output = ÷ = 1 X = *Obtained from Curve 71(A, B, C, D), 0% AFD Current Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 12 of 15 ATTACHMENT 1 Page 5 of 5 Quadrant Power Tilt Ratio Calculation without Plant Computer Printed 10/28/2013 at 18:55:00 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 Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 13 of 15 Printed 10/28/2013 at 18:55:00 ATTACHMENT 2Page 1 of 2Using 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 Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 14 of 15 ATTACHMENT 2 Page 2 of 2 Using A DVM To Obtain Detector Current Values Printed 10/28/2013 at 18:55:00 NOTE The following formula is used to calculate detector currents: CurrentDetectorCalculatedValue"Current%100,AFD%0"71Curve083.2VoltageDetectorMeasured=x .............. 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 BDetector A Detector B Detector A Detector BN41T 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 Quadrant Power Tilt Ratio Calculation FNP-1-STP-7.0FARLEY Version 23.0Unit 1 Page 15 of 15 Printed 10/28/2013 at 18:55:00 ATTACHMENT 3Page 1 of 1Surveillance Test Review Sheet TECHNICAL SPECIFICATION REFERENCE SR 3.2.4.1 MODE(S) REQUIRING TEST: 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

QPTR3.2.4Farley Units 1 and 2 3.2.4-1 Amendment No. 146 (Unit 1) Amendment No. 137 (Unit 2) 3.2 POWER DISTRIBUTION LIMITS 3.2.4 QUADRANT POWER TILT RATIO (QPTR) LCO 3.2.4 The QPTR shall be 1.02. APPLICABILITY: MODE 1 with THERMAL POWER 50% RTP. ACTIONSCONDITION REQUIRED ACTION COMPLETION TIME A. QPTR not within limit. A.1 Limit THERMAL POWER to 3% below RTP for each 1% of QPTR > 1.00. ANDA.2 Determine QPTR. ANDA.3 Perform SR 3.2.1.1 and SR 3.2.2.1. AND2 hours after each QPTR determination Once per 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months s24 hours after achieving equilibrium conditions with THERMAL POWER limited by Required Action A.1 ANDOnce per 7 days thereafter (continued)

QPTR3.2.4Farley Units 1 and 2 3.2.4-2 Amendment No. 146 (Unit 1) Amendment No. 137 (Unit 2) ACTIONSCONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.4 Reevaluate safety analyses and confirm results remain valid for duration of operation under this condition. ANDA.5 ----------NOTES----------- 1. Perform Required Action A.5 only after Required Action A.4 is completed. 2. Required Action A.6 shall be completed if Required Action A.5 is performed. -------------------------------- Normalize excore detectors to restore QPTR to within limits. ANDPrior to increasing THERMAL POWER above the limit of Required Action A.1 Prior to increasing THERMAL POWER above the limit of Required Action A.1 (continued)

QPTR 3.2.4Farley Units 1 and 2 3.2.4-3 Amendment No. 146 (Unit 1) Amendment No. 137 (Unit 2) ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.6 -----------NOTE------------ Perform Required Action A.6 only after Required Action A.5 is completed. -------------------------------- Perform SR 3.2.1.1 and SR 3.2.2.1. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after achieving equilibrium conditions at RTP ORWithin 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months after increasing THERMAL POWER above the limit of Required Action A.1 B. Required Action and associated Completion Time not met. B.1 Reduce THERMAL POWER to < 50% RTP. 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months QPTR 3.2.4Farley Units 1 and 2 3.2.4-4 Amendment No. 185 (Unit 1) Amendment No. 180 (Unit 2) SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 ------------------------------NOTES------------------------------ 1. 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. 2. SR 3.2.4.2 may be performed in lieu of this Surveillance. ---------------------------------------------------------------------- Verify QPTR is within limit by calculation. In accordance with the Surveillance Frequency Control ProgramSR 3.2.4.2 ------------------------------NOTE------------------------------- Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after input from one or more Power Range Neutron Flux channels are inoperable with THERMAL POWER > 75% RTP. ---------------------------------------------------------------------- Confirm that the normalized symmetric power distribution is consistent with QPTR. In accordance with the Surveillance Frequency Control Program FARLEYUnit 1SAFETY RELATED FNP-1-STP-7.0 Quadrant Power Tilt Ratio Calculation Special Considerations: PROCEDURE LEVEL OF USE CLASSIFICATION PER NMP-AP-003 CATEGORY SECTIONS Continuous ALL Reference NONE Information NONE VERSION SUMMARY PVR 23.0 DESCRIPTION TABLE OF CONTENTS 1.0 PURPOSE**2.0 PRECAUTIONS AND LIMITATIONS (SR 3.2.4.1)3.0 INITIAL CONDITIONS (OR 1-98-498)(OR 1-98-498)(OR 1-98-498)NOTE

3.0 INITIAL CONDITIONS (continued)

NOTE 4.0 INSTRUCTIONS 4.1 QPTR Determination Using The IPC. NOTES OpenCheck**go toClickIncludeGo to NOTE 4.2 QPTR Determination Using Manual Calculation: CalculateGo to4.3 Determination Of QPTR Acceptance Criteria: NOTE (NL-10-0406, dated 2/26/2010)CheckACCEPTANCE CRITERIA NOTE 5.0 ACCEPTANCE CRITERIA 6.0 RECORDS QA Record (X) Non-QA Record (X)Record Generated Retention Time R-Type

7.0 REFERENCES

Quadrant Power Tilt Ratio Calculation without Plant Computer NOTE **ObtainEnterNOTE Performenter********CAUTION enterEnter Quadrant Power Tilt Ratio Calculation without Plant Computer Calculate***RecordACCEPTANCE CRITERIA Record Quadrant Power Tilt Ratio Calculation without Plant Computer Calculation Sheet UPPER QUADRANT POWER TILT POWER RANGE B Drawer UPPER DET Indicated Current ÷ *UPPER DET 100% Current =UPPER DET Calibrated Output ÷ =÷ =÷ =÷ =X =÷= X =

Quadrant Power Tilt Ratio Calculation without Plant Computer Calculation Sheet LOWER QUADRANT POWER TILT POWER RANGE B Drawer LOWER DET Indicated Current ÷ *LOWER DET 100% Current = LOWER DET Calibrated Output ÷ =÷ =÷ =÷ =X =÷= X =

Quadrant Power Tilt Ratio Calculation without Plant Computer Calculation Sheet ACCEPTANCE CRITERIA Using A DVM To Obtain Detector Current Values NOTE CAUTIONS **connectNOTE connectRecordconnectRecord Using A DVM To Obtain Detector Current Values NOTE CurrentDetectorCalculatedValue"Current%100,AFD%0"71Curve083.2VoltageDetectorMeasured=xperformCalculateRecord Surveillance Test Review Sheet

QPTR3.2.4Farley Units 1 and 2 3.2.4-1 Amendment No. 146 (Unit 1) Amendment No. 137 (Unit 2) 3.2 POWER DISTRIBUTION LIMITS 3.2.4 QUADRANT POWER TILT RATIO (QPTR) LCO 3.2.4 The QPTR shall be 1.02. APPLICABILITY: MODE 1 with THERMAL POWER 50% RTP. ACTIONSCONDITION REQUIRED ACTION COMPLETION TIME A. QPTR not within limit. A.1 Limit THERMAL POWER to 3% below RTP for each 1% of QPTR > 1.00. ANDA.2 Determine QPTR. ANDA.3 Perform SR 3.2.1.1 and SR 3.2.2.1. AND2 hours after each QPTR determination Once per 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months s24 hours after achieving equilibrium conditions with THERMAL POWER limited by Required Action A.1 ANDOnce per 7 days thereafter (continued)

QPTR3.2.4Farley Units 1 and 2 3.2.4-2 Amendment No. 146 (Unit 1) Amendment No. 137 (Unit 2) ACTIONSCONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.4 Reevaluate safety analyses and confirm results remain valid for duration of operation under this condition. ANDA.5 ----------NOTES----------- 1. Perform Required Action A.5 only after Required Action A.4 is completed. 2. Required Action A.6 shall be completed if Required Action A.5 is performed. -------------------------------- Normalize excore detectors to restore QPTR to within limits. ANDPrior to increasing THERMAL POWER above the limit of Required Action A.1 Prior to increasing THERMAL POWER above the limit of Required Action A.1 (continued)

QPTR 3.2.4Farley Units 1 and 2 3.2.4-3 Amendment No. 146 (Unit 1) Amendment No. 137 (Unit 2) ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.6 -----------NOTE------------ Perform Required Action A.6 only after Required Action A.5 is completed. -------------------------------- Perform SR 3.2.1.1 and SR 3.2.2.1. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after achieving equilibrium conditions at RTP ORWithin 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months after increasing THERMAL POWER above the limit of Required Action A.1 B. Required Action and associated Completion Time not met. B.1 Reduce THERMAL POWER to < 50% RTP. 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months QPTR 3.2.4Farley Units 1 and 2 3.2.4-4 Amendment No. 185 (Unit 1) Amendment No. 180 (Unit 2) SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 ------------------------------NOTES------------------------------ 1. 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. 2. SR 3.2.4.2 may be performed in lieu of this Surveillance. ---------------------------------------------------------------------- Verify QPTR is within limit by calculation. In accordance with the Surveillance Frequency Control ProgramSR 3.2.4.2 ------------------------------NOTE------------------------------- Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after input from one or more Power Range Neutron Flux channels are inoperable with THERMAL POWER > 75% RTP. ---------------------------------------------------------------------- Confirm that the normalized symmetric power distribution is consistent with QPTR. In accordance with the Surveillance Frequency Control Program FNP ILT-38 ADMIN Page 1 of 10 Developer S Jackson Date: 4/9/15 NRC Approval SEE NUREG 1021 FORM ES-301-3 A.3 RO - SRO TITLE: Determine the correct RWP, total projected dose And determine if an oil addition and venting can be performed to the 2A RHR pump without exceeding limits defined. EVALUATION LOCATION: SIMULATOR CONTROL ROOM 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 perform the following for the task of adding oil to the 2A RHR pump and venting the suction: Identify the location of Q2E11V100A Identify the correct RWP to perform the task. Calculate the total projected dose for the job. Determine if the task can or cannot be performed without exceeding Administrative Limits or RWP limits on a single entry, and if NOT then state the reason. Examinee: Overall JPM Performance: Satisfactory Unsatisfactory Evaluator Comments (attach additional sheets if necessary) EXAMINER:

FNP ILT-38 ADMIN Page 2 of 10 CONDITIONS When I tell you to begin, you are to Determine the correct RWP, total projected dose And determine if an oil addition and venting can be performed to the 2A RHR pump without exceeding limits defined. The conditions under which this task is to be performed are: 1. You are a trainee on shift and will be accomplishing the following task under instruction. 2. You are qualified as a Fully Documented Radiation Worker. 3. You will be draining and adding oil to the 2A RHR Pump Motor upper and lower reservoirs and venting the suction of the 2A RHR. 4. All needed tools, oil, and equipment have been staged. 5. All necessary briefings to perform the task have been completed. 6. Your accumulated dose for this year to date is 1260 mRem. 7. Contamination levels: All areas are less than ALPHA 3 levels and < 200 dpm/100 cm2. 8. The following tasks are required to be performed:

TASK TIME REQUIRED DOSE RATE 1 Drain and fill the RHR pump motor (upper reservoir) 5 min 25 mR/hr 2 Drain and fill the RHR pump motor (lower reservoir) 15 min 60 mR/hr 3 Remove pipe cap, attach hose to Q2E11V100A, and open the vent valves, Q2E11V100A and Q2E11V100B until air free water issues from the vent. 25 min 120 mR/hr Note: Assume no additional dose received while traveling between tasks. 9. Your task is to perform all of the following and DOCUMENT your conclusions on the table provided: a. Identify the location (room) of Q2E11V100A, CTMT SUMP TO 2A RHR PUMP HDR VENT ISO. b. Select the correct RWP to use for this task. c. For yourself ONLY, calculate the Total projected dose to perform this task. d. Determine whether the task can or cannot be performed without exceeding the Farley Administrative Dose Limit or RWP limits. If the task cannot be performed, then state the reason. INITIATING CUE: "IF you have no questions, you may begin."

FNP ILT-38 ADMIN Page 3 of 10 EVALUATION CHECKLIST RESULTS: ELEMENTS: STANDARDS: (CIRCLE) START TIME

1. Identifies the location Q2E11V100A Using MAXIMO, or FNP-2-SOP-7.0A or other methods, identifies the location of Q2E11V100A.

e.g.: 83' Foot elevation in the 2A RHR pump room OR Room 2131 S / U

2. Determines RWP to use.

Reviews the dose rates and identifies that the highest General Area dose rate for the jobs to be performed is 120 mR/hr.

Determines that the task will require a High Radiation Area entry. References the RWPs and determines that RWP 15-0101 is a Training RWP, but it cannot be used for a High Radiation Area entry.

Determines that RWP 15-0503 has allowance for OPS Training in High Radiation Areas, and is the correct RWP to use. S / U Total dose from task calculation: Dose-upper oil addition + Dose-lower oil addition + Dose-venting = Total dose for the task 1. 5 minutes

25 mRem/ hr

1 hr/60 minutes = 2.08 mRem (dose at jobsite) {2 - 2.1} 2. 15 minutes

60 mRem/ hr

1 hr/60 minutes = 15 mRem (dose at jobsite) { no range } 3. 25 minutes

120 mRem/ hr

1 hr/60 minutes = 50 mRem (dose at jobsite) { no range } 2.08 + 15 + 50 = Total Dose = 67 to 67.1 mRem total FNP ILT-38 ADMIN Page 4 of 10 EVALUATION CHECKLIST RESULTS: ELEMENTS: STANDARDS: (CIRCLE)

3. Calculates total projected dose. Calculates dose received while performing the job. Documents the total of 67 mRem {RANGE 67 - 67.1 mRem} S / U

4. Determine if any dose limits will be exceeded by performing the task. Determines if allowable dose limits will be exceed: - Admin dose limit Total dose = 1260 + 67.1 = 1327.1 mR 1327.1 mR < Admin dose limit of 2000 mR.

- RWP Task dose limit 67.1 mR < RWP 15-0503 Task dose limit of 90 mR - RWP Task dose rate limit 120 mR/hr < RWP 15-0503 Task dose rate limit of 140 mR/hr. Determines that dose limits of the RWP will not be exceeded.

IDENTIFIES that the task actions can be completed as assigned by circling YES. S / U Total ANNUAL dose: (1260 accumulated) + 67.1 = 1327.1 mR {1327 - 1327.1}

FNP Administrative Annual Dose limit from FNP-0-M-001, Southern Nuclear Company Joseph M. Farley Nuclear Plant Health Physics Manual, is 2000 mR for a Fully Documented Radiation worker. STOP TIME Terminate when all elements of the task have been completed.

FNP ILT-38 ADMIN Page 5 of 10 CRITICAL ELEMENTS: Critical Elements are denoted with an asterisk () before the element number. GENERAL

REFERENCES:

1. FNP-0-M-001, v19.0 2. KA: G2.3.4 - 3.2 / 3.7 G2.3.7 - 3.5 / 3.6 GENERAL TOOLS AND EQUIPMENT: 1. Calculator 2. RWP 12-0503 and 12-0101 (For Training USE ONLY) 3. Health Physics Manual, FNP-0-M-001, v19.0.

Critical ELEMENT justification: STEP Evaluation 1. Critical: Task completion: required to determine proper location for the task given 2. Critical: Task completion: required to determine proper Radiation Work Permit for the task given. 3. Critical: Task completion: required to determine the total projected dose. 4. Critical: Task completion: required to identify that the task can be done within limits permitting task completion.

FNP ILT-38 ADMIN Page 6 of 10 KEY Determination of Task Performance Q2E11V100A, CTMT SUMP TO 2A RHR PUMP HDR VENT is located: 2A RHR Pump RM {Also acceptable: RM 2131} (Room) CORRECT RWP to use (CIRCLE the correct RWP) 15-0101 15-0503 Projected dose for this task *67 to 67.1 mRem {range of 67-67.1 mRem} Can you complete this task without exceeding limits? (CIRCLE ONE) YES* NO REASON, if applicable: N/A FNP ILT-35 ADMIN HANDOUT Pg 1 of 2 A.3 CONDITIONS When I tell you to begin, you are to Determine the correct RWP, total projected dose And determine if an oil addition and venting can be performed to the 2A RHR pump without exceeding limits defined. The conditions under which this task is to be performed are: 1. You are a trainee on shift and will be accomplishing the following task under instruction. 2. You are qualified as a Fully Documented Radiation Worker. 3. You will be draining and adding oil to the 2A RHR Pump Motor upper and lower reservoirs and venting the suction of the 2A RHR. 4. All needed tools, oil, and equipment have been staged. 5. All necessary briefings to perform the task have been completed. 6. Your accumulated dose for this year to date is 1260 mRem. 7. Contamination levels: All areas are less than ALPHA 3 levels and < 200 dpm/100 cm2. 8. The following tasks are required to be performed:

TASK TIME REQUIRED DOSE RATE 1 Drain and fill the RHR pump motor (upper reservoir) 5 min 25 mR/hr 2 Drain and fill the RHR pump motor (lower reservoir) 15 min 60 mR/hr 3 Remove pipe cap, attach hose to Q2E11V100A, and open the vent valves, Q2E11V100A and Q2E11V100B until air free water issues from the vent. 25 min 120 mR/hr Note: Assume no additional dose received while traveling between tasks. 9. Your task is to perform all of the following and DOCUMENT your conclusions on the table provided: a. Identify the location (room) of Q2E11V100A, CTMT SUMP TO 2A RHR PUMP HDR VENT ISO. b. Select the correct RWP to use for this task. c. For yourself ONLY, calculate the Total projected dose to perform this task. d. Determine whether the task can or cannot be performed without exceeding the Farley Administrative Dose Limit or RWP limits. If the task cannot be performed, then state the reason.

FNP ILT-35 ADMIN HANDOUT Pg 2 of 2 Determination of Task Performance Q2E11V100A, CTMT SUMP TO 2A RHR PUMP HDR VENT ISO, is located: (Room) CORRECT RWP to use (CIRCLE the correct RWP) 15-0101 15-0503 Projected dose for this task Can you complete this task without exceeding limits? (CIRCLE ONE) YES NO REASON, if applicable:

99FOR TRAINING USE ONLY~~~ by NRC EXAM WRITER

Radiological ConditionsTASKS~RadiationWork Permit15-0503FOR TRAINING USE ONLY05 FNP HLT-38 ADMIN Page 1 of 6 A.4 SRO TITLE: CLASSIFY AN EMERGENCY EVENT PER NMP-EP-110, EMERGENCY CLASSIFICATION DETERMINATION AND COMPLETE SELECTED PORTIONS OF NMP-EP-111-F10, EMERGENCY NOTIFICATION FORM. PROGRAM APPLICABLE: SOT SOCT OLT X LOCT ACCEPTABLE EVALUATION METHOD: X PERFORM X SIMULATE DISCUSS EVALUATION LOCATION: X SIMULATOR X CONTROL ROOM X CLASSROOM PROJECTED TIME: 20 MIN SIMULATOR IC NUMBER: N/A ALTERNATE PATH ____ TIME CRITICAL X PRA THIS JPM IS TIME CRITICAL 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 be able to: 1. Classify an Emergency Event per NMP-EP-110, Emergency Classification Determination and Initial Action, and complete Checklist 1, Classification Determination. Examinee: Overall JPM Performance: Satisfactory Unsatisfactory Evaluator Comments (attach additional sheets if necessary) EXAMINER: Developer S Jackson Date: 4/10/15 NRC Approval SEE NUREG 1021 FORM ES-301-3 FNP HLT-38 ADMIN Page 2 of 6 CONDITIONS When I tell you to begin, you are to CLASSIFY AN EMERGENCY EVENT PER NMP-EP-110, EMERGENCY CLASSIFICATION DETERMINATION. This task is to be performed based on the following information:

A rampdown was initiated on Unit 2 due to high RCS activity.

Current conditions are as follows:

a. Chemistry reports that RCS gross activity is 105/µCi/gm. b. R-4 has risen from 2 mr/hr to 200 mr/hr c. R-2 is 900 mr/hr d. R-7 is 450 mr/hr e. The plant initiated a manual Safety Injection based on excessive RCS leakage. f. Pressurizer pressure is stable at 1900 psig and Pressurizer level is stable with 200 gpm HHSI flow. g. RCS Tavg is 539ºF & decreasing slowly. h. Portions of this JPM contain Time Critical Elements. NOTE: The classification should NOT be based on ED discretion. Your task is to classify the event and fill out NMP-EP-110, Checklist 1, Classification Determination Form, through step 5.

Part 2 Administer this portion of the JPM after completion of the above task. JPM DIRECTIONS: 1. Provide student with Part 2 HANDOUT and NMP-EP-111-F10. CONDITIONS Based on your previously provided conditions, complete items 4, 5, 6 and 10 of NMP-EP-111-F10, Emergency Notification Form. This task is NOT TIME CRITICAL.

FNP HLT-38 ADMIN Page 3 of 6 EVALUATION CHECKLIST RESULTS: ELEMENTS: STANDARDS: (CIRCLE) TIME CRITICAL START TIME NOTE: THE TIME IT TAKES TO CLASSIFY THE EVENT IS TIME CRITICAL AND MUST BE COMPLETED IN 15 MINUTES. NOTE: THE CRITICAL TASK IS TO PROPERLY CLASSIFY THE LEVEL OF THE EMERGENCY AS AN ALERT *1. Classify the event. Event classified as an ALERT per NMP-EP-110-GL01. See Key at the end of the JPM. S / U TIME CRITICAL STOP TIME NOTE: THE STEPS BELOW ARE FROM NMP-EP-111-F10, SNC EMERGENCY NOTIFICATIONS FORM (ENF). NOTE: EAL# AND EAL DESCRIPTION ARE NOT CRITICAL AS LONG AS THE STATE AND LOCAL EMAs KNOW THE LEVEL OF EMERGENCY. *2. Step 4 EMERGENCY CLASSIFICATION: Selects [B] ALERT EAL # FA1 EAL

Description:

S / U Loss or Potential Loss of either Fuel Clad or RCS *3. Step 5 Selects [A] None S / U PROTECTIVE ACTION RECOMMENDATIONS: *4. Step 6 EMERGENCY RELEASE: Selects [A] None S / U FNP HLT-38 ADMIN Page 4 of 6 *5. Step 10 Selects [A] DECLARATION S / U Enters Time from NMP-EP-110, Checklist 1, Step 5. Enters Date from NMP-EP-110, Checklist 1, Step 5. S / U

S / U Terminate JPM when initial notification form is completed CRITICAL ELEMENTS: Critical Elements are denoted with an Asterisk (*) before the element number. GENERAL

REFERENCES:

1. NMP-EP-110, ver 7.1 2. NMP-EP-110-GL01, ver 7 3. NMP-EP-111, ver 9 4. KA: G2.4.41 RO-2.3 SRO-4.1 GENERAL TOOLS AND EQUIPMENT: 1. NMP-EP-110, ver 7.1 2. NMP-EP-110-GL01, ver 7 (EAL BOARD) 3. NMP-EP-111-F10, ver 7.1 4. NMP-EP-111, ver 9 Critical ELEMENT justification: 1. Critical - Proper Classification is required to allow State and Local EMAs to take appropriate actions. Additionally, the site has required actions based on classification. 2. Critical - Communication of the proper Classification is required to allow State and Local EMAs to take appropriate actions. 3. Critical - Issuance of PARs that are not required may put the public at risk during possible evacuation. This could include panic, vehicle accidents etc. 4. Critical - Incorrectly alerting EMAs of a release that is not occurring may put the public at risk during possible evacuation. 5. Critical - Task completion. information provided is essential for correct Emergency Notification form being correctly filled out. COMMENTS:

FNP HLT-38 ADMIN HANDOUT Page 1 of 2 A.4 SRO CONDITIONS When I tell you to begin, you are to CLASSIFY AN EMERGENCY EVENT PER NMP-EP-110, EMERGENCY CLASSIFICATION DETERMINATION. This task is to be performed based on the following information:

A rampdown was initiated on Unit 2 due to high RCS activity. Current conditions are as follows:

a. b. R-4 has risen from 2 mr/hr to 200 mr/hr c. R-2 is 900 mr/hr d. R-7 is 450 mr/hr e. The plant initiated a manual Safety Injection based on excessive RCS leakage. f. Pressurizer pressure is stable at 1900 psig and Pressurizer level is stable with 200 gpm HHSI flow. g. RCS Tavg is 539ºF & decreasing slowly. h. Portions of this JPM contain Time Critical Elements. NOTE: The classification should NOT be based on ED discretion. Your task is to classify the event and fill out NMP-EP-110, Checklist 1, Classification Determination From, through step 5.

FNP HLT-38 ADMIN HANDOUT Page 2 of 2 A.4 SRO PART 2 CONDITIONS Based on your previously provided conditions, complete items 4, 5, 6 and 10 of NMP-EP-111-F10, Emergency Notification Form. This task is NOT TIME CRITICAL.

Emergency Classification Determination and Initial Action NMP-EP-110SNC Version 7.1Unit S Page 12 of 22Printed 07/17/2014 at 07:53:00 ATTACHMENT 1Page 1 of 1Checklist 1 - Classification Determination NOTE Key Parameters should be allowed to stabilize to accurately represent plant conditions prior to classifying an event Initial ActionsCompleted by 1.Determine the appropriate Initiating Condition Matrix for classification of the event based on the current operating mode: HOT IC/EAL Matrix Evaluation Chart (Go To Step 2) to evaluate the Barriers) COLD IC/EAL Matrix Evaluation Chart (Go To Step 3)Both HOT & COLD IC/EAL Matrix Evaluation Chart apply (Go To Step 2)____________ 2.Evaluate the status of the fission product barrier using Figure 1, Fission Product Barrier Evaluation. a.Select the condition of each fission product barrier: LOSS POTENTIAL LOSS INTACT Fuel Cladding Integrity Reactor Coolant System Containment Integrity ____________ b.Determine the highest applicable fission product barrier Initiating Condition (IC): ____________ (select one) FG1 FS1 FA1 FU1 None 3.Evaluate AND determine the highest applicable IC/EAL using the Matrix Evaluation Chart(s) identified in step 1 THEN Go To step 4.Hot IC#________ Unit___ and/or Cold IC# __________ Unit___ or None ____________ 4.Check the highest emergency classification level identified from either step 2b or 3: ClassificationBased on IC# Classification Based on IC# General Alert Site-Area NOUE None N/A Remarks (Identify the specific EAL, as needed): ____________ 5.Declare the event by approving the Emergency Classification. Date: / / Time: Emergency Director____________ 6.ObtainMeteorological Data (not required prior to event declaration):Wind Direction (from)_____ Wind Speed_____ Stability Class_____ Precipitation______ ____________ 7.Initiate Attachment 2, Checklist 2 - Emergency Plan Initiation.____________

Southern Nuclear Operating Company Emergency ImplementingProcedure SNC Emergency Notifications Form (ENF) NMP-EP-111-F10 Version 1.0 Page 1 of 1 EMERGENCY RELEASE DATA NOT REQUIRED IF LINE 6 A IS SELECTED. 14. RELEASE CHARACTERIZATION: TYPE: A Elevated B Mixed C Ground UNITS: A Ci B Ci/sec C Ci/secMAGNITUDE: Noble Gases:__________ Iodines:___________ Particulates:__________ Other: ____________ FORM: A Airborne B Liquid Start Time __________ Date ___/_____/____Stop Time _________ Date ___/_____/____ Start Time __________ Date ___/_____/____Stop Time _________ Date ___/_____/____ 15. PROJECTION PARAMETERS: Projection period: ________Hours Estimated Release Duration ________Hours Projection performed: Time _________ Date ___/_____/____ Accident Type: ________ 16. PROJECTED DOSE: DISTANCE TEDE (mrem)Adult Thyroid CDE (mrem) Site boundary 2 Miles 5 Miles 10 Miles 17. APPROVED BY: ____________________________ Title _____________________ Time ________Date___/_____/____ NOTIFIED BY: ___________________________ RECEIVED BY: ___________________________ Time ________Date___/_____/____ (To be completed by receiving organization) 1. A DRILL B ACTUAL EVENT MESSAGE # _______ 2. A INITIAL B FOLLOW-UP NOTIFICATION: TIME________DATE_____/_____/__ AUTHENTICATION #_______ 3. SITE: _______________________ Confirmation Phone #_________________4. EMERGENCY CLASSIFICATION: A UNUSUAL EVENT B ALERT C SITE AREA EMERGENCY D GENERAL EMERGENCY BASED ON EAL# ____________ EAL DESCRIPTION:___________________________________________________________

__________________________________________________________________________________________________________________________________________________________________________________________________________________5. PROTECTIVE ACTION RECOMMENDATIONS: A NONE B EVACUATE _________________________________________________________________________________________ C SHELTER __________________________________________________________________________________________ D Advise Remainder of EPZ to Monitor Local Radio/TV Stations/Tone Alert Radios for Additional Information and Consider the use of KI (potassium iodide) in accordance with State plans and policy. E OTHER____________________________________________________________________________________________ 6. EMERGENCY RELEASE: A None B Is Occurring C Has Occurred 7. RELEASE SIGNIFICANCE: A Not applicable B Within normal operating limits C Above normal operating limits D Under evaluation 8. EVENT PROGNOSIS: A Improving B Stable C Degrading 9. METEOROLOGICAL DATA: Wind Direction from _______ degrees* WindSpeed _______mph*(*May not be available for Initial Notifications)* Precipitation _______* Stability Class* A B C D E F G 10. A DECLARATION B TERMINATION Time ________________ Date _____/______/_______ 11. AFFECTED UNIT(S): 1 2 All 12. UNIT STATUS: (Unaffected Unit(s) Status Not Required for Initial Notifications) A U1 _____% Power Shutdown at Time ____________ Date ___/_____/____ B U2 _____% Power Shutdown at Time ____________ Date ___/_____/____ 13. REMARKS:____________________________________________________________________________________________

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Emergency Classification Determination and Initial Action NMP-EP-110SNC Version 7.1Unit S Page 12 of 22Printed 07/17/2014 at 07:53:00 ATTACHMENT 1Page 1 of 1Checklist 1 - Classification Determination NOTE Key Parameters should be allowed to stabilize to accurately represent plant conditions prior to classifying an event Initial ActionsCompleted by 1.Determine the appropriate Initiating Condition Matrix for classification of the event based on the current operating mode: HOT IC/EAL Matrix Evaluation Chart (Go To Step 2) to evaluate the Barriers) COLD IC/EAL Matrix Evaluation Chart (Go To Step 3)Both HOT & COLD IC/EAL Matrix Evaluation Chart apply (Go To Step 2)____________ 2.Evaluate the status of the fission product barrier using Figure 1, Fission Product Barrier Evaluation. a.Select the condition of each fission product barrier: LOSS POTENTIAL LOSS INTACT Fuel Cladding Integrity Reactor Coolant System Containment Integrity ____________ b.Determine the highest applicable fission product barrier Initiating Condition (IC): ____________ (select one) FG1 FS1 FA1 FU1 None 3.Evaluate AND determine the highest applicable IC/EAL using the Matrix Evaluation Chart(s) identified in step 1 THEN Go To step 4.Hot IC#________ Unit___ and/or Cold IC# __________ Unit___ or None ____________ 4.Check the highest emergency classification level identified from either step 2b or 3: ClassificationBased on IC# Classification Based on IC# General Alert Site-Area NOUE None N/A Remarks (Identify the specific EAL, as needed): ____________ 5.Declare the event by approving the Emergency Classification. Date: / / Time: Emergency Director____________ 6.ObtainMeteorological Data (not required prior to event declaration):Wind Direction (from)_____ Wind Speed_____ Stability Class_____ Precipitation______ ____________ 7.Initiate Attachment 2, Checklist 2 - Emergency Plan Initiation.____________

Southern Nuclear Operating Company Emergency ImplementingProcedure SNC Emergency Notifications Form (ENF) NMP-EP-111-F10 Version 1.0 Page 1 of 1 EMERGENCY RELEASE DATA NOT REQUIRED IF LINE 6 A IS SELECTED. 14. RELEASE CHARACTERIZATION: TYPE: A Elevated B Mixed C Ground UNITS: A Ci B Ci/sec C Ci/secMAGNITUDE: Noble Gases:__________ Iodines:___________ Particulates:__________ Other: ____________ FORM: A Airborne B Liquid Start Time __________ Date ___/_____/____Stop Time _________ Date ___/_____/____ Start Time __________ Date ___/_____/____Stop Time _________ Date ___/_____/____ 15. PROJECTION PARAMETERS: Projection period: ________Hours Estimated Release Duration ________Hours Projection performed: Time _________ Date ___/_____/____ Accident Type: ________ 16. PROJECTED DOSE: DISTANCE TEDE (mrem)Adult Thyroid CDE (mrem) Site boundary 2 Miles 5 Miles 10 Miles 17. APPROVED BY: ____________________________ Title _____________________ Time ________Date___/_____/____ NOTIFIED BY: ___________________________ RECEIVED BY: ___________________________ Time ________Date___/_____/____ (To be completed by receiving organization) 1. A DRILL B ACTUAL EVENT MESSAGE # _______ 2. A INITIAL B FOLLOW-UP NOTIFICATION: TIME________DATE_____/_____/__ AUTHENTICATION #_______ 3. SITE: _______________________ Confirmation Phone #_________________4. EMERGENCY CLASSIFICATION: A UNUSUAL EVENT B ALERT C SITE AREA EMERGENCY D GENERAL EMERGENCY BASED ON EAL# ____________ EAL DESCRIPTION:___________________________________________________________

__________________________________________________________________________________________________________________________________________________________________________________________________________________5. PROTECTIVE ACTION RECOMMENDATIONS: A NONE B EVACUATE _________________________________________________________________________________________ C SHELTER __________________________________________________________________________________________ D Advise Remainder of EPZ to Monitor Local Radio/TV Stations/Tone Alert Radios for Additional Information and Consider the use of KI (potassium iodide) in accordance with State plans and policy. E OTHER____________________________________________________________________________________________ 6. EMERGENCY RELEASE: A None B Is Occurring C Has Occurred 7. RELEASE SIGNIFICANCE: A Not applicable B Within normal operating limits C Above normal operating limits D Under evaluation 8. EVENT PROGNOSIS: A Improving B Stable C Degrading 9. METEOROLOGICAL DATA: Wind Direction from _______ degrees* WindSpeed _______mph*(*May not be available for Initial Notifications)* Precipitation _______* Stability Class* A B C D E F G 10. A DECLARATION B TERMINATION Time ________________ Date _____/______/_______ 11. AFFECTED UNIT(S): 1 2 All 12. UNIT STATUS: (Unaffected Unit(s) Status Not Required for Initial Notifications) A U1 _____% Power Shutdown at Time ____________ Date ___/_____/____ B U2 _____% Power Shutdown at Time ____________ Date ___/_____/____ 13. REMARKS:____________________________________________________________________________________________

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FNP ILT-38 ADMIN Page 1 of 5 Developer S. Jackson Date: 4/2/15 NRC Approval SEE NUREG 1021 FORM ES-301-3 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:

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% - YES BOTH INT RNG SUR ZERO OR NEGATIVE - NO Determines that an Orange condition exists to go to FRP-S.1. S / U

2. Evaluate CSF-0.2. FIFTH HOTTEST CORE EXIT TC LESS THAN 1200°F - YES RCS SUBCOOLING FROM CORE EXIT TC'S GRTR THAN 16°F{45°F} - YES Determines that this CSF is SAT. S / U 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 ONE SG GRTR THAN 31%{48%} - NO TOTAL AFW FLOW TO ALL SG'S GRTR THAN 395 GPM - YES PRESS IN ALL SG'S LESS THAN 1129 PSIG - YES NAR RNG LVL IN ALL SG'S LESS THAN 82% - YES PRESS IN ALL SG'S LESS THAN 1075 PSIG - YES NAR RNG LVL IN ALL SG'S GRTR THAN 31% - NO Determines that a Yellow condition exists to go to FRP-H.5. S / U

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.