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301 Administrative JPMs
	ML14351A086
Person / Time
Site:	Farley
Issue date:	12/17/2014
From:	; NRC/RGN-II
To:	; Southern Nuclear Operating Co
Shared Package
ML14351A112	List: ML14351A054; ML14351A065; ML14351A071; ML14351A080; ML14351A083; ML14351A086; ML14351A088; ML14351A093; ML14351A094; ML14351A102; ML14351A103; ML14351A106; ML14351A109;
References
	FNP ILT 37 ADMIN 50-348/OL-14, 50-364/OL-14
	Download: ML14351A086 (169)
	v • d • e

FNP ILT 37 ADMIN Page 1 of 11 Developer S. Jackson 05/12/14 NRC Approval SEE NUREG 1021 FORM ES-301-3 A.1.a.R, Conduct of Operations - RO ONLY A.1.a.R TITLE: Calculate Required Turbine Load Reduction.

PROGRAM APPLICABLE: SOT SOCT OLT X LOCT ACCEPTABLE EVALUATION METHOD: X PERFORM SIMULATE DISCUSS EVALUATION LOCATION: SIMULATOR CONTROL ROOM X CLASSROOM PROJECTED TIME: 15 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 of the task by reviewing the completed form.

2. Provide the examinee with the required materials to perform this JPM.

TASK STANDARD:

Calculate the required load reduction due to the loss of a 500kV Line.

Determine the minimum required ramp rate to achieve the necessary load reduction.

Examinee:

Overall JPM Performance:

Satisfactory Unsatisfactory Evaluator Comments (attach additional sheets if necessary)

EXAMINER:

FNP ILT-37 ADMIN A.1.a.R Page 2 of 11 CONDITIONS When I tell you to begin, you are to: Calculate Required Turbine Load Reduction. The conditions under which this task is to be performed are:

a. At 0800, Plant Farley received information that the Farley-Snowdoun 500kV line had been removed from service.

b. The Shift Manager directed to initiate a load reduction on Unit 1 ONLY.

c. The ramp was started at 0810.

d. The following information was given:

i.

Unit 1 - 913 mWe.

ii.

Unit 2 - 922 mWe.

iii.

Control Area System Load Level - 23.2 GW.

iv.

The Shunt Reactor was out of service.

v.

The Capacitor Bank was in service.

vi.

The Unit 1 PSS was out of service.

vii.

The Unit 2 PSS was in service.

e. You are required to perform Steps 4.1 through 4.5 of FNP-1-UOP-3.1, Appendix 5 and determine:

i.

The MINIMUM load reduction required.

ii.

The MINIMUM ramp rate which was used to achieve the desired load reduction using 0810 as the starting time.

INITIATING CUE: You may begin.

EVALUATION CHECKLIST RESULTS:

ELEMENTS:

STANDARDS:

(CIRCLE)

START TIME

1. Step 4.1: Contact the ACC to determine the control area system load level, shunt reactor status, and capacitor bank status.

1) Fills in the following data:

a. Control Area System Load Level -

23.2 GW

b. Shunt Reactor in service / out of service

c. Capacitor Bank in service / out of service S / U

2. Step 4.2: Determine the total plant gross MW output from each units DEH display:

2) Fills in the following data:

a. Unit 1 MW - 913

b. Unit 2 MW - 922 S / U

FNP ILT-37 ADMIN A.1.a.R Page 3 of 11 EVALUATION CHECKLIST RESULTS:

ELEMENTS:

STANDARDS:

(CIRCLE)

3. Step 4.3: Determine the PSS status for each unit.

3) Fills in the following data:

a. Unit 1 PSS in service / out of service

b. Unit 2 PSS in service / out of service S / U

4. Determine the total plant MW limitation from Table 1 (Farley - Raccoon Creek), or Table 2 (Farley - Snowdoun) based on the total plant gross MW, and the PSSs status.

4) Using Table 2:

a. 1325 MW S / U NOTE: There are several ways to mathematically calculate the MINIMUM required load reduction.

The evaluator should only determine whether or not the amount of load reduction is correct.

5. Determines MINIMUM required load reduction:

5) Calculates:

X + 922MW = 1325MW X = 403MW 913MW - 403MW = 510MW S / U NOTE: There are several ways to mathematically calculate the MINIMUM required ramp rate. The evaluator should only determine whether or not the ramp rate is correct to achieve required load reduction in stated ramp time.

Step 4.5 states that the load reduction required by Appendix 5 must be completed within 30 minutes of the initiating condition. Since, the initiating condition occurred at 0800 and the ramp began at 0810 then there are 20 minutes left to achieve the required load reduction.

6. Determines MINIMUM ramp rate required:

6) Calculates:

510MW ÷ 20min = 25.5MW/min

( Range 25.5 - 26 MW/min)

S / U TERMINATE After calculations are completed.

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

FNP ILT-37 ADMIN A.1.a.R Page 4 of 11 GENERAL

REFERENCES:

1. FNP-1-UOP-3.1, Appendix 5, v117

2. KA: G2.1.20 - 4.6 / 4.6 G2.1.25 - 3.9 / 4.2 GENERAL TOOLS AND EQUIPMENT:

1. FNP-1-UOP-3.1, Appendix 5, v117

2. Pen/Pencil/Calculator Critical ELEMENT justification:

STEP Evaluation 1 - 4.

5.

6.

NOT Critical - Required for calculation of required load reduction and ramp rate but if Elements 5 and 6 are correct then these are not critical.

Critical - Task Objective. Per AI2004204794, FNP has committed to complying with Appendix 5 load limits.

Critical - Task Objective. Per AI2004204794, FNP has committed to complying with Appendix 5 load limits within the required time of 30 minutes.

COMMENTS:

FNP ILT-37 ADMIN A.1.a.R HANDOUT Pg 1 of 1 CONDITIONS When I tell you to begin, you are to: Calculate Required Turbine Load Reduction. The conditions under which this task is to be performed are:

a. At 0800, Plant Farley received information that the Farley-Snowdoun 500kV line had been removed from service.

b. The Shift Manager directed to initiate a load reduction on Unit 1 ONLY.

c. The ramp was started at 0810.

d. The following information was given:

i.

Unit 1 - 913 mWe.

ii.

Unit 2 - 922 mWe.

iii.

Control Area System Load Level - 23.2 GW.

iv.

The Shunt Reactor was out of service.

v.

The Capacitor Bank was in service.

vi.

The Unit 1 PSS was out of service.

vii.

The Unit 2 PSS was in service.

e. You are required to perform Steps 4.1 through 4.5 of FNP-1-UOP-3.1, Appendix 5 and determine:

i.

The MINIMUM load reduction required.

ii.

The MINIMUM ramp rate which was used to achieve the desired load reduction using 0810 as the starting time.

MINIMUM LOAD REDUCTION REQUIRED MINIMUM RAMP RATE

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-UOP-3.1 117.0 2/17/2014 09:56:37 POWER OPERATION Page Number 61 of 78 APPENDIX 5 LOAD LIMITATIONS WITH A 500 kV TRANSMISSION LINE OUT OF SERVICE Page 1 of 4 1.0 Purpose This procedure provides the load limits to be followed with a 500 kV transmission line out of service, and both units on line. Limits are given for having both units Power System Stabilizers (PSS) in, or out of service, and for having either PSS out of service.

2.0 Initial Conditions 2.1 Unit 1 and Unit 2 are tied to the grid.

2.2 One of the following 500kV transmission lines is out of service.

Farley - Raccoon Creek Farley - Snowdoun 3.0 Precautions and Limitations 3.1 The Alabama Control Center (ACC) should be notified the times a PSS is removed from service, and when it is returned to service.

3.2 The control area system load level is the value used in the tables. This is defined as the total system load within the Southern Company footprint and not just the load associated with the Southern Company plants.

3.3 All transmission lines and both PSSs (power system stabilizers) are normally in service at Farley, and the maximum generation capability is 1910 MW gross. Tables 1 and 2 provide the recommended maximum total plant generation for abnormal operating conditions with a 500 kV transmission line out of service to ensure that power oscillations are properly damped and that transient stability will be maintained.

The results assume that the shunt reactor is off for the system load levels studied.

Having the shunt reactor on would improve system stability. The results also assume that the capacitor bank is not in service for system load levels equal to or below 25 GW. If the system load level is less than 25 GW and the capacitor is on, the Alabama Control Center (ACC) could be contacted to see if the capacitor could be turned off. If it cannot be turned off, then consult Note 1 at the end of the appropriate table. These tables provide recommended total gross generation levels which are independent of the generation amount of each unit.

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-UOP-3.1 117.0 2/17/2014 09:56:37 POWER OPERATION Page Number 62 of 78 Appendix 5 Page 2 of 4 3.4 The load levels in the tables are based upon bounding system conditions used in stability studies. Exceptions to this guidance are permissible provided that expected system conditions, including generation dispatch, shunt reactor status, capacitor bank status, and Farley MW output, are evaluated on a case-by-case basis and the evaluation demonstrates that adequate damping of oscillations would occur and that transient stability will be maintained under those conditions for the next contingency.

3.5 There are no load limitations for any of the following conditions:

One of the 230kV transmission lines are out of service One of the 500/230kV Auto Bank Transformers is out of service CAUTION The tables included in this figure are only valid when the Pulse Wheel Input is selected as the input source for the Unit 2 PSS.

3.6 The two tables provide limitations based on the following PSS settings:

Unit 1 PSS gain of 7.8 Unit 2 set for the pulse wheel input (speed) with a gain of 4.4 pu (gain dial setting 5.3) 3.7 Limits with a 500 kV line out and with one or both Farley PSS off are highly dependent on system conditions including the dispatch of other units on the system.

Due to these sensitivities, limits involving one or both PSS off at Farley should be studied on a case-by-case basis. Limits are provided in Note 2 of the tables below with worst case assumptions of system conditions. These limits should provide a safe operating point until further studies can be performed with the expected system load levels, system topology, and generation dispatch.

3.8 A special stability study can be requested to be performed by SCS Transmission Planning by contacting the PCC Reliability Desk operator, if conditions are met in this appendix, and the condition may last for several days. The special stability study may raise the total plant MW limitation based on actual system conditions. It takes approximately four (4) hours to perform and obtain the results from the special stability study.

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-UOP-3.1 117.0 2/17/2014 09:56:37 POWER OPERATION Page Number 63 of 78 Appendix 5 Page 3 of 4 4.0 Instructions 4.1 Contact the ACC to determine the control area system load level, shunt reactor status, and capacitor bank status.

Control Area System Load Level GW Shunt Reactor in service / out of service Capacitor Bank in service / out of service 4.2 Determine the total plant gross MW output from each units DEH display:

Unit 1 MW Unit 2 MW 4.3 Determine the PSS status for each unit.

Unit 1 PSS in service / out of service Unit 2 PSS in service / out of service 4.4 Determine the total plant MW limitation from Table 1 (Farley - Raccoon Creek), or Table 2 (Farley - Snowdoun) based on the total plant gross MW, and the PSSs status.

Total plant MW limitation MW NOTE Entry into FNP-1-AOP-17.1, RAPID TURBINE POWER REDUCTION may be required.

4.5 IF plant gross MW output (as determined in Step 4.2) exceeds the total plant MW limitation (as determined in Step 4.4) conditions are met, THEN the total plant MW limitation value has to be met within 30 minutes from the initiating condition(s). (AI 2004204794) 4.6 IF the unit is operated with the PSS out of service, THEN notify the ACC within thirty (30) minutes. (NERC Requirement) 4.7 IF the control area system load level is less than or equal to 16 GW, AND the shunt reactor is off service, THEN contact the ACC to see if the shunt reactor could be placed in service.

4.8 IF the control area system load level is less than 25 GW, AND the capacitor bank is on service, THEN contact the ACC to see if the capacitor bank can be removed from service.

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-UOP-3.1 117.0 2/17/2014 09:56:37 POWER OPERATION Page Number 64 of 78 Appendix 5 Page 4 of 4 4.9 IF the shunt reactor cannot be placed in service, OR the capacitor bank cannot be removed from service, THEN ensure Note 1 is applied at the end of the appropriate table.

4.10 IF the transmission line will be out of service for several days, AND the plant gross MW output has been de-rated per Step 4.5, THEN contact the PCC Reliability Desk operator, AND have them request SCS Transmission Planning to perform a special stability study to determine if the total plant MW limitation can be raised in Step 4.4.

(CR 2007112628, CR 2009113189) 4.11 Contact the ACC to determine when the control area system load level is projected to change, which would result in an additional total plant MW limitation.

Projected Control Area System Load Level GW Time for the Projected Control Area System Load Level change 4.12 IF plant gross MW output exceeds the total plant MW limitation conditions are met, THEN the total plant MW limitation value has to be met within 30 minutes from the initiating condition(s).

(AI 2004204794) 4.13 Continue the communications with the ACC to evaluate the control area system load, and the total plant MW limitation.

4.14 WHEN the transmission line in Step 2.2 has been returned to service, THEN the units can return to normal, full power operation.

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-UOP-3.1 117.0 2/17/2014 09:56:37 POWER OPERATION Page Number 65 of 78 TABLE 1 Farley-Raccoon Creek 500 kV Out Column A Column B Column C Control Area System Load Level PSS Unit 1 (NOTE 2)

PSS Unit 2 (NOTE 2)

Total Plant MW Total Plant MW with shunt reactor OFF Total Plant MW with capacitor bank ON (NOTE 1) 14 to < 16 GW Out Out 1350 MW 1350 MW 1350 MW In Out 1350 MW 1350 MW 1350 MW Out In 1350 MW 1350 MW 1350 MW In In 1910 MW 1910 MW 1910 MW 16 to < 18 GW Out Out 1350 MW 1350 MW 1350 MW In Out 1350 MW 1350 MW 1350 MW Out In 1350 MW 1350 MW 1350 MW In In 1910 MW 1910 MW 1910 MW 18 to < 20 GW Out Out 1350 MW 1350 MW 1350 MW In Out 1350 MW 1350 MW 1350 MW Out In 1350 MW 1350 MW 1350 MW In In 1910 MW 1910 MW 1910 MW 20 to < 22 GW Out Out 1350 MW 1350 MW 1350 MW In Out 1350 MW 1350 MW 1350 MW Out In 1350 MW 1350 MW 1350 MW In In 1910 MW 1910 MW 1910 MW 22 to < 24 GW Out Out 1350 MW 1350 MW 1350 MW In Out 1350 MW 1350 MW 1350 MW Out In 1350 MW 1350 MW 1350 MW In In 1910 MW 1910 MW 1910 MW 24 GW Out Out 1350 MW 1350 MW 1350 MW In Out 1350 MW 1350 MW 1350 MW Out In 1350 MW 1350 MW 1350 MW In In 1910 MW 1910 MW 1910 MW NOTES (1) If the capacitor bank is on for load levels of less than or equal to 25 GW, the plant generation does not need to be reduced. These limits have been calculated and provided in Column C.

(2) If a PSS is out of service for one of the Farley units, the recommended generation limit is 1350 MW until further study of the actual system conditions can be made. The additional reduction based on shunt reactor / capacitor bank status does not apply with a PSS out of service. The PSS out of service limits were calculated very conservatively, and no further reduction factors are needed.

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-UOP-3.1 117.0 2/17/2014 09:56:37 POWER OPERATION Page Number 66 of 78 TABLE 2 Farley-Snowdoun 500 kV Out Column A Column B Column C Control Area System Load Level PSS Unit 1 (Note 4)

PSS Unit 2 (Note 4)

Total Plant MW Total Plant MW with shunt reactor OFF Total Plant MW with capacitor bank ON (Note 3) 14 to < 16 GW Out Out 1325 MW 1325 MW 1325 MW In Out 1325 MW 1325 MW 1325 MW Out In 1325 MW 1325 MW 1325 MW In In 1910 MW 1910 MW 1900 MW 16 to < 18 GW Out Out 1325 MW 1325 MW 1325 MW In Out 1325 MW 1325 MW 1325 MW Out In 1325 MW 1325 MW 1325 MW In In 1910 MW 1910 MW 1900 MW 18 to < 20 GW Out Out 1325 MW 1325 MW 1325 MW In Out 1325 MW 1325 MW 1325 MW Out In 1325 MW 1325 MW 1325 MW In In 1910 MW 1910 MW 1900 MW 20 to < 22 GW Out Out 1325 MW 1325 MW 1325 MW In Out 1325 MW 1325 MW 1325 MW Out In 1325 MW 1325 MW 1325 MW In In 1910 MW 1910 MW 1900 MW 22 to < 24 GW Out Out 1325 MW 1325 MW 1325 MW In Out 1325 MW 1325 MW 1325 MW Out In 1325 MW 1325 MW 1325 MW In In 1910 MW 1910 MW 1900 MW 24 GW Out Out 1325 MW 1325 MW 1325 MW In Out 1325 MW 1325 MW 1325 MW Out In 1325 MW 1325 MW 1325 MW In In 1910 MW 1910 MW 1900 MW NOTES (3) If the capacitor bank is on for load levels of less than or equal to 25 GW and both PSSs are in service, then the plant generation should be reduced an additional 10 MW below the numbers given in Column A of this table. These limits have been calculated and provided in Column C.

(4) If a PSS is out of service for one of the Farley units, the recommended generation limit is 1325 MW until further study of the actual system conditions can be made. The additional reduction based on shunt reactor / capacitor bank status does not apply with a PSS out of service. The PSS out of service limits were calculated very conservatively, and no further reduction factors are needed.

FNP ILT 37 ADMIN Page 1 of 6 Developer S. Jackson 05/09/14 NRC Approval SEE NUREG 1021 FORM ES-301-3 A.1.a.S, Conduct of Operations - SRO ONLY A.1.a.S TITLE: Calculate Diesel Generator Fuel Levels.

PROGRAM APPLICABLE: SOT SOCT OLT X LOCT ACCEPTABLE EVALUATION METHOD: X PERFORM SIMULATE DISCUSS EVALUATION LOCATION: SIMULATOR CONTROL ROOM X 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 of the task by reviewing the completed form.

2. Provide the examinee with the required materials to perform this JPM.

TASK STANDARD:

Calculate the final fuel level for two running Diesel Generators.

Determine the required Technical Specification actions if any. If none are required then determine how long until Technical Specification limits will be met.

Examinee:

Overall JPM Performance:

Satisfactory Unsatisfactory Evaluator Comments (attach additional sheets if necessary)

EXAMINER:

FNP ILT-37 ADMIN A.1.a.S Page 2 of 6 CONDITIONS When I tell you to begin, you are to: Calculate Diesel Generator Fuel Levels. The conditions under which this task is to be performed are:

a. Unit 2 has had a Loss of Offsite Power and is in MODE 3.

b. Power has been restored and the DGs are shut down.

c. The following conditions exist:

i.

1C DG.

The initial fuel oil level was 104 by local dipstick measurement.

The DG had been running for 40 hours4.62963e-4 days 0.0111 hours 6.613757e-5 weeks 1.522e-5 months at FULL load.

ii.

2B DG

The initial fuel oil level was 130 by local dipstick measurement.

The DG had been running for 28 hours3.240741e-4 days 0.00778 hours 4.62963e-5 weeks 1.0654e-5 months at FULL load.

d. No additions have been made to the respective FOSTs.

e. Assume all fuel consumption comes from the FOSTs and day tank levels remain constant.

f. The EPB fuel oil level indication is INOPERABLE and reads 0%.

1. You are required to determine the final fuel oil level in the FOST for the 1C and 2B DGs after the stated run times.

AND

2. List any Technical Specification REQUIRED ACTION(S).

INITIATING CUE: You may begin.

EVALUATION CHECKLIST RESULTS:

ELEMENTS:

STANDARDS:

(CIRCLE)

START TIME NOTE: Calculations may be performed in any order. This guide assumes the 1C DG is performed first.

1. Determines fuel used by 1C DG using Plant Curves and Fuel Consumption rate.

1) Calculates:

(40hrs x 213gph) = 8520gal S / U

FNP ILT-37 ADMIN A.1.a.S Page 3 of 6 EVALUATION CHECKLIST RESULTS:

ELEMENTS:

STANDARDS:

(CIRCLE)

NOTE: If using the curve, may calculate INITIAL level as low as 27,500gal useable which results in 18980gal final.

If using ACTUAL level, they must recognize they are below 21,000 useable. If they used most conservative level on the table they would use 22984gal Actual for the FINAL level which is 19100gal useable and is less than Tech Spec minimum.

2. Determines final DG fuel level

2) Calculates:

27788 gal - 8520gal =

19268gal (Useable) 31672gal - 8520gal =

23152gal (Actual)

S / U NOTE: Critical Task annotated by a

on substeps.

3. Determines that Tech Spec conditions exists:

3) Determine from Tech Specs:

a) *3.8.3 Cond F b) *3.8.1 Cond B S / U S / U

4. Determines fuel used by 2B DG using Plant Curves and Fuel Consumption rate.

4) Calculates:

(28hrs x 297gph) = 8316gal S / U NOTE: If using curve may calculate 35,000gal to 34,800 gal useable which results in 26684gal -

26484gal) final.

If using ACTUAL level, they may use most conservative level on the table they would use 30359gal actual which is 26475gal useable and is greater than Tech Spec minimum.

5. Determines final DG fuel level

5) Calculates:

34883gal - 8316 gal =

26567gal (Useable) 38767gal - 8316gal =

30451gal (Actual)

S / U

FNP ILT-37 ADMIN A.1.a.S Page 4 of 6 EVALUATION CHECKLIST RESULTS:

ELEMENTS:

STANDARDS:

(CIRCLE)

6. Determines if any Tech Spec conditions exists:

6) No Tech Spec Conditions Exist.

S / U TERMINATE After calculations and Tech Spec evaluations are completed.

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

GENERAL

REFERENCES:

1. FNP-0-SOP-38, v123

2. Technical Specifications, v193

3. Plant Curves: PCB-2-VOL2-CRV018A/B, v4

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

1. FNP-0-SOP-38, v123

2. Technical Specifications, v193 or access to Training Reference Disk.

3. Plant Curves: PCB-2-VOL2-CRV018A/B, v4

4. Pen/Pencil/Calculator Critical ELEMENT justification:

STEP Evaluation

1.

2.

3.

4.

5.

6.

Critical - Task Objective. Required for determining final fuel level.

Critical - Task Objective. Additionally, improper calculation could result in not entering Tech Spec Required Action Statement.

Critical (2 Components) - Proper evaluation of Technical Specifications is required to operate within the facilitys license.

Critical - Task Objective.

NOT Critical. No Tech Spec entry condition exists.

COMMENTS:

FNP ILT-37 ADMIN A.1.a.S HANDOUT Pg 1 of 2 CONDITIONS When I tell you to begin, you are to: Calculate Diesel Generator Fuel Levels. The conditions under which this task is to be performed are:

g. Unit 2 has had a Loss of Offsite Power and is in MODE 3.

h. Power has been restored and the DGs are shut down.

i. The following conditions exist:

i.

1C DG.

The initial fuel oil level was 104 by local dipstick measurement.

The DG had been running for 40 hours4.62963e-4 days 0.0111 hours 6.613757e-5 weeks 1.522e-5 months at FULL load.

ii.

2B DG

The initial fuel oil level was 130 by local dipstick measurement.

The DG had been running for 28 hours3.240741e-4 days 0.00778 hours 4.62963e-5 weeks 1.0654e-5 months at FULL load.

j. No additions have been made to the respective FOSTs.

k. Assume all fuel consumption comes from the FOSTs and day tank levels remain constant.

l. The EPB fuel oil level indication is INOPERABLE and reads 0%.

1. You are required to determine the final fuel oil level in the FOST for the 1C and 2B DGs after the stated run times.

AND

2. List any Technical Specification(s) that are required to be entered (if any).

1C DG FOST Final Level gal 2B DG FOST Final Level gal Technical Specification(s) (if any):

FNP ILT-37 ADMIN A.1.a.S HANDOUT Pg 2 of 2

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 1 of 37 S

A F

E T

Y DIESEL GENERATORS R

E L

A T

E D

PROCEDURE LEVEL OF USE CLASSIFICATION PER NMP-AP-003 CATEGORY SECTIONS Continuous:

ALL

Reference:

NONE Information:

NONE Approved By: David L Reed for)

Effective Date: 10/10/2013 Operations Manager

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 2 of 37 Version Number Version Description 112.0 New Procedure format per NMP-OS-008 and split out of the diesels into separate procedures.

113.0 Added requirement to have ACC place or verify the Capacitor Bank in manual prior to synchronizing a diesel to the grid.

114.0 Revised appendix 1 & 2 to add additional monitoring for DG 2B and 2C due to fuel rack stop adjustment from 112% to 120%.

115.0 Revised appendix 2 to add additional monitoring for DG 1-2A due to fuel rack stop adjustment from 112% to 120%.

116.0 Revised appendix 1 to add additional monitoring for DG 1C due to fuel rack stop adjustment from 112% to 120%.

117.0 Minor Editorial change to correct referenced step in Step 2.2.3 and added note in Attachment B at step 6.0 to filter new oil from 55 gal drums. CR#2010101367 Revised to change DG JW capacity listed for the 1C and 2C DG.

118.0 Implemented CR 2011103710 change, repaired cover sheet, headers, titles of appendices and attachments.

119.0 CR 344065 Correct numerical reference errors in Appendix 1 Step 2.1.3 &

corrected procedure reference Attachment B Step 7.0. CR 329293: FNP-0-SOP-0.0 has reference section that no longer exists, Step 2.2.11.

119.1 Added Appendix 4, CR 395712 119.2 P&L 2.1.15, corrected to better state 1-2A D/G response. CR 433674.

119.3 Added P&L 2.1.12. CR 491547 120.0 Appendix 1 & 2, consolidated redundant information. Appendix 3, restructured and added Data Sheet 1 for recording additional data as mandated by TE 504888.

120.1 Step 2.2.10, corrected typo. CR 556933 Step 2.2.11, corrected contained information regarding operability. CR 565327 121.0 Updated procedure to reflect changes due to implementation of DCP C050889101.

122.0 Added steps to address operation of the Webb Capacitor Bank.

123.0 Added step 2.1.23 to address the EPA requirement per 40CFR63.6640(f).

Appendix 3, page 2 of 9, Added new steps 4.0 and 7.0 and note proceeding.

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 3 of 37 TABLE OF CONTENTS 1.0 PURPOSE............................................................................................................................................ 4 2.0 PRECAUTION AND LIMITATIONS..................................................................................................... 4 3.0 INITIAL CONDITIONS....................................................................................................................... 10 4.0 INSTRUCTIONS................................................................................................................................ 11 4.1 1-2A Diesel Generator and auxiliaries............................................................................................ 11 4.2 1B Diesel Generator and auxiliaries............................................................................................... 11 4.3 1C Diesel Generator and auxiliaries............................................................................................... 11 4.4 2B Diesel Generator and auxiliaries............................................................................................... 11 4.5 2C Diesel Generator and auxiliaries............................................................................................... 11 5.0 RECORDS......................................................................................................................................... 11

6.0 REFERENCES

................................................................................................................................... 11 TABLE 1 Large D/G Jacket Water System Drain Points........................................................................ 13 TABLE 2 D/G load limits with elevated SW supply temperature............................................................ 14 FIGURE 1 Large Diesel Capability Curve............................................................................................. 16 FIGURE 2 Small Diesel Capability Curve............................................................................................. 17 ATTACHMENT A Guideline for returning a Diesel to service following a Maintenance Outage............. 18 ATTACHMENT B D/G Lube Oil Removal & Replacement Guidance.................................................... 19 ATTACHMENT C D/G Fuel Oil Consumption........................................................................................ 21 ATTACHMENT D Reading D/G Crankcase Vacuum Manometer.......................................................... 22 APPENDIX 1 Loading/Unloading Guidance for small D/Gs.................................................................. 25 APPENDIX 2 Loading/Unloading Guidance for large D/Gs................................................................... 26 APPENDIX 3 DG START/RUN DATA.................................................................................................... 27 APPENDIX 4 Surveillance Tests Containing Governor Settings............................................................ 37

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 4 of 37 1.0 PURPOSE This procedure provides Initial Conditions, Precautions, Limitations and Instructions for the operation of the Diesel Generators and auxiliaries.

2.0 PRECAUTION AND LIMITATIONS 2.1 PRECAUTIONS 2.1.1 Diesel generator automatic start capability is defeated in Modes 3 and 4.

2.1.2 If a diesel generator is removed from automatic standby operation, Limiting Conditions for Operation of Technical Specifications Section 3.8.1 and 3.8.2 apply.

2.1.3 Diesel generator parallel operation with offsite sources should be limited to surveillance testing and maintenance activities only. {CMT 0000603}

2.1.4 Parallel operation of diesel generators with offsite sources will be limited to one train at a time per unit and one diesel per unit. 2C Diesel is considered a B Train diesel for the purpose of this requirement.

{CMT 0000603}

2.1.5 Diesel generators should NOT be started and loaded in anticipation of a potential loss of offsite power. {CMT 0007846}

2.1.6 Do NOT manually load diesel generators above continuous load limit or above load limits of Figures 1 and 2. {CMT 0003632}

2.1.7 When operating a diesel continuously at less than synchronous speed, the exciter should be manually tripped to prevent possible generator damage.

2.1.8 UNIT SELECTOR SWITCHES may be placed in the UNIT 1 or UNIT 2 position only if the effect of this action has been analyzed and it has been determined that it will NOT reduce overall safety of the units.

2.1.9 One diesel at a time should be unloaded and returned to standby.

2.1.10 1-2A, 1B and 2B Diesels have a potential vibration harmonic at ~350 RPM and shall NOT be allowed to remain at this speed.

2.1.11 At low speed, all diesel automatic trips are disabled, with the exception of the Engine Start Failure trip.

2.1.12 IF the diesel is started following an event from which the diesel was secured, that was NOT in accordance with the normal shutdown process, i.e., unloaded, 60 HZ, 4160V, THEN, the as left configuration of the electronic governor may NOT allow the governor to respond as expected when energized as part of the slow start section. CR 491547

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FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 5 of 37 2.1.13 Diesel generators 1-2A, 1C and 2C are each connectable to both Units 1 and 2. In all design basis events, diesel generators 1-2A and 1C are assigned to only one unit, depending on the type of event. MCC 1S is dedicated to the diesel generator 1-2A auxiliaries. This MCC can be connected to either Unit 1 dedicated 600 V LC 1D through 600 V LC breaker ED13-1 or Unit 2 dedicated 600 V LC 2D through 600 V LC breaker ED13-2. The 600 V LC breakers ED13-1 and ED13-2 are electrically interlocked so that only one can be closed at any one time.

This prevents paralleling of the two plant units through 600 V MCC 1S.

The logic for the automatic scheme relies on the position of the Unit 1 and Unit 2 diesel generator 1-2A breakers (DF08-1 and DF08-2). If DF08-1 closes, ED13-2 opens (if it is closed at the time of the event) and ED13-1 closes (if it is open at the time of the event), and vice versa if DF08-2 closes. If load center 1D or 2D are being powered by the alternate source off the 1F or 2F load centers this transfer will not occur. If 1-2A diesel is started and aligned to Unit 1 and 2D load center is on the alternate source, the transfer of 1S MCC will not occur if subsequently 1-2A diesel is place on Unit 2. If 1-2A diesel is started and aligned to Unit 2 and 1D load center is on the alternate source the transfer of 1S MCC will not occur if subsequently 1-2A diesel is place on Unit 1. (CR2007112287) 2.1.14 MCC 1N is dedicated to the diesel generator 1C auxiliaries. This MCC is connected to shared LC 1R through the normally closed breaker ER03.

Load center 1R can be connected to either Unit 1 4.16 kV bus 1H through 600 V LC breaker ER02, station service transformer 1R and the Unit 1 4.16 kV breaker DH08-1 or Unit 2 4.16 kV bus 2H through 600 V LC breaker ER05, station service transformer 2R and the Unit 2 4.16 kV breaker DH08-2. The 4.16 kV breakers DH08-1 and DH08-2 are normally closed. The 600 V LC breakers ER02 and ER05 are electrically interlocked so that only one can be closed at any one time. This prevents paralleling of the two plant units through 600 V LC 1R.

2.1.15 MCC 1P is dedicated to the diesel generator 2C auxiliaries. This MCC is connected to shared LC 1S through the normally closed breaker ES03.

Load center 1S can be connected to either Unit 1 4.16 kV bus 1J through 600 V LC breaker ES02, station service transformer 1S and the Unit 1 4.16 kV breaker DJ07-1 or Unit 2 4.16 kV bus 2J through 600 V LC breaker ES05, station service transformer 2S and the Unit 2 4.16 kV breaker DJ07-2. The 600 V LC breakers ES02 and ES05 are electrically interlocked so that only one breaker can be closed at any one time. This prevents paralleling of the two plant units through the 600 V LC 1S.

2.1.16 1-2A Diesel will transfer to isochronous control if an auto start signal is present (an SI in either unit or UV condition on 1F or 2F bus). In most cases, 1-2A Diesel would NOT remain paralleled to the bus. If the transfer to isochronous control is due to an SI without LOSP or LOSP on Unit 1(2) while paralleled to Unit 2(1), 1 2A Diesel will remain paralleled to the bus, requiring prompt operator action to minimize potential for DG damage.

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FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 6 of 37 2.1.17 1C Diesel will transfer to isochronous control if an auto start signal is present (an SI in either unit or UV condition on 1H or 2H bus). In most cases, 1C Diesel would NOT remain paralleled to the bus. If the transfer to isochronous control is due to 1H (2H) bus undervoltage while paralleled to 2H(1H) bus, 1C Diesel will remain paralleled to the bus, requiring prompt operator action to minimize potential for DG damage.

2.1.18 Minimum lube oil temperature for diesel generator operability is 90 °F.

2.1.19 The minimum jacket water temperature for diesel generator operability is 80 °F.

2.1.20 At no time shall the nitrite solution in the diesel generator coolant system be discharged into floor drains or any other receptacles without prior authorization from Chemistry Supervision.

2.1.21 The pH of the Jacket Water is slightly caustic and contact with the skin should be avoided. If contact with the skin does occur flush with plain water immediately.

2.1.22 ACC has placed, or verified, the following capacitor banks in MANUAL prior to synchronizing a diesel generator to the grid.

Webb Sub Station Capacitor Bank Farley 230 KV Switchyard Capacitor Bank 2.1.23 The Environmental Protection Agency (40CFR63.6640(f)) has established annual runtime limits on emergency diesels. Annual runtimes shall be tracked by SNC Environmental Services. Prior to starting an emergency diesel for any purpose other than those specifically listed below, the Site Environmental Specialist shall be contacted during normal working hours or the SNC Environmental Services (on-call) shall be contacted (205-288-2064) to ensure compliance with EPA Guidelines.

Surveillance testing.

Functional testing.

Maintenance runs.

An actual emergency / auto start to perform its intended function.

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FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 7 of 37 2.2 LIMITATIONS 2.2.1 FNP-0-SOP-38.0 ATTACHMENT A, GUIDELINES FOR RETURNING A DIESEL TO SERVICE FOLLOWING A MAINTENANCE OUTAGE, should be referenced for guidance on returning a diesel to service following maintenance.

2.2.2 FNP-0-SOP-38.0 APPENDIX 3, DG START/RUN DATA, shall be filled out for any diesel run, i.e., STP, maintenance run, auto start, etc.

2.2.3 Information for each start or attempted start should be provided to the DG system engineer for inclusion in the DG Run Log.

2.2.4 In order to maintain availability of the D/G with the speed setter set at something less than the max setting, an operator must be responsible to raise the speed setter back to the max setting in the event the diesel receives an auto start signal. The designated person must remain in the D/G building the entire time the speed setter is less than the max setting.

2.2.5 It is important to expeditiously raise load to 50 kW after breaker closure to prevent a reverse power trip. If the switch for the output breaker and the governor motor switch are physically far apart, consideration should be given to utilizing two operators for performing those applicable procedure steps. {OR 1-2000-282}

2.2.6 Prior to diesel generator shutdown, the voltage regulator must be set at 4160V and frequency set at 60 Hz to ensure proper voltage and frequency is established when the diesel is aligned for automatic standby operation. {CMT 0003878}

2.2.7 During load changes on a diesel, the GOVERNOR MOTOR switch should NOT be bumped more frequently than every 3 seconds, and preferably NOT more than once every 5 seconds. {OR 1-97-375}

2.2.8 To minimize possibility of exhaust manifold fires, diesel generators should be loaded to rated load for at least one hour each time they are started, when practicable. This guidance is general in nature and does NOT hold for operation of a diesel generator under any surveillance test procedure (where special test conditions may exist).

2.2.9 When diesels are operated under low load conditions, there is a potential for the accumulation of combustion and lubrication products in the exhaust system. Any time it becomes necessary to operate a diesel at less than 30% of full load for more than twelve hours, action should be taken to run the diesel at greater than 50% of full load for at least one hour in each twelve hour period.

2.2.10 Table 2 of FNP-0-SOP-38.0 provides diesel loading restrictions when service water temperature is > 92°F.

2.2.11 When manipulating Service Water vents and drains, be cognizant of the following: Pipe internals can be potentially degraded. Proceed with caution. Do not subject vent/drain piping to any undue stress during removal of pipe cap/plug. {AI 2009202698}

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FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 8 of 37 2.2.12 The diesel room ventilation fans are credited for long term operation of the diesels during design basis accident conditions, and are considered attendant equipment for Tech Spec and NRC performance indicator purposes. IF the diesel room ventilation fans are placed in OFF, THEN the LCO RAS MUST be entered for that diesel. However, manual operator action can be credited for maintaining a diesel available if appropriate administrative controls are established. Refer to FNP-0-SOP-43.0, DIESEL GENERATOR BUILDING HVAC for guidance on operation of DG Room Ventilation.

2.2.13 The generator exciter can only be reset at the DLCP.

2.2.14 2C Diesel output breaker will open when 2C Diesel is placed in MODE 2 if DG01 and DG15 for either unit are both open.

2.2.15 The tolerance for calibrating DG watt meters on the control room EPB is +/- 120 Kw.

2.2.16 1C and 2C DGs normally should be barred over after each operation.

The requirement for barring can be waived with the concurrence of the applicable manager if any of the following are true:

The diesel will be restarted within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (SM).

Refueling outages on either unit are in progress (SM).

Taking the D/G out of service will cause an increased plant risk (OPS Manager).

2.2.17 If 1C or 2C Diesel were started with lube oil temperature 85°F, engine speed should be reduced as necessary to keep lube oil pressure, as indicated by the gauge on the gauge panel, < 55 psig until lube oil is warmed up.

2.2.18 If starting diesel engine 1C or 2C AND oil temperature decreases to less than 100°F AND the keep warm lube oil system is in service (i.e., the circulating oil pump is running), cylinders shall be blown down and the engine barred over prior to starting.

2.2.19 1C and 2C Diesel circulating oil pump circuitry has a time delay such that the pump will NOT start until 10 minutes after the diesel is shutdown.

2.2.20 Chemistry should be notified to obtain a jacket water sample for analysis anytime a makeup, feed and bleed or in-leakage will dilute the nitrite concentrations in the jacket water system.

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FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 9 of 37 2.2.21 The following apply to diesel generator lube oil strainers:

Lube oil strainers should be shifted when P across the on-service lube oil strainer exceeds 12 psid for 1-2A, 1B and 2B Diesels OR 15 psid for 1C and 2C Diesels.{CMT 0003869}

Lube oil strainer P limits apply when the lube oil temperature is at normal operating steady state conditions. {AI 2007200776}

The Lube Oil Strainer P will go up more rapidly if the crankcase oil has been replaced. This is due to the reaction of the detergents in the new oil and the sludge formations in the engine from carbon deposits.

Notify the Emergency Diesel Generator Maintenance Engineer or the System Engineer whenever there is a sudden increase in differential pressure during an engine run and whenever strainers are shifted

{AI 2007200776}

2.2.22 Various DG capacities are provided in the table below. The associated number of drums referenced serves as an estimate only, and should NOT be relied on exclusively during filling or draining operations. Close monitoring is required to prevent overfill and subsequent spilling.

{AI 2003201168, AI 2003202529}

VARIOUS DG CAPACITIES SYSTEM GALLON S

DRUMS DGs 1-2A, 1B, & 2B Total Lube Oil 1320 24 Engine & Oil Pan Lube Oil 845 15.4 Jacket Water 430 NA DGs 1C & 2C Total Lube Oil 440 8

Engine & Oil Pan Lube Oil 250 4.5 Jacket Water 400 NA DGs 1-2A, 1B, 2B, 1C, & 2C Jacket Water Surge Tank (full) 100 NA 2.2.23 Hoses used to transfer lube oil should have their connections bagged to minimize the potential for a spill in the event the hose connections were to leak.

2.2.24 Anytime the auxiliary jacket water pump on a diesel is run while it is shutdown, the diesel is inoperable and an LCO shall be initiated. Also, the engine shutdown reset pushbutton on the diesel local control panel (DLCP) shall be reset after the auxiliary jacket water pump is secured to clear the emergency shutdown relay.

{CMT 0006909}

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FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 10 of 37 3.0 INITIAL CONDITIONS 3.1 The electrical distribution system is energized and aligned for normal operation per FNP-1-SOP-36.0, PLANT ELECTRICAL DISTRIBUTION LINE-UP, and FNP-2-SOP-36.0, PLANT ELECTRICAL DISTRIBUTION LINE-UP, with exceptions noted.

3.2 The diesel generator system valves and electrical distribution systems are aligned per System Check List FNP-0-SOP-38.0A (B, C, D and E) with exceptions noted.

3.3 The service water system is in service and aligned for normal operation per FNP-1-SOP-24.0, SERVICE WATER SYSTEM, and FNP-2-SOP-24.0, SERVICE WATER SYSTEM, with exceptions noted.

3.4 Diesel building HVAC is in service per FNP-0-SOP-43.0, DIESEL GENERATOR BUILDING HVAC, with exceptions noted.

3.5 The diesel building fire protection system is aligned per FNP-0-SOP-61.3, FIRE PROTECTION - LOW PRESSURE CO2 SYSTEMS, with exceptions noted.

3.6 Diesel generator fuel oil storage and transfer system is in operation per FNP-0-SOP-42.0, DIESEL GENERATOR FUEL OIL STORAGE AND TRANSFER SYSTEM, with exceptions noted.

3.7 IF a diesel generator start is being performed, THEN SS has determined the type of start required. For the final maintenance start performed at the conclusion of major maintenance on 1-2A, 1B, 2B and 1C DGs a fast speed start would typically be used to fully exercise the diesel functions. Guidance for surveillance starts is contained in the appropriate surveillance test procedure. Other routine operational starts would typically be slow speed starts to minimize diesel wear.

3.8 IF a diesel generator is to be loaded, THEN ACC has placed the following capacitor banks in manual prior to the generator being synchronized to the grid.

Webb Sub Station Capacitor Bank Farley 230 KV Switchyard Capacitor Bank

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FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 11 of 37 4.0 INSTRUCTIONS 4.1 IF the task involves operation of the 1-2A Diesel Generator and auxiliaries, THEN Go To FNP-0-SOP-38.0-1-2A.

4.2 IF the task involves operation of the 1B Diesel Generator and auxiliaries, THEN Go To FNP-0-SOP-0-38.0-1B.

4.3 IF the task involves operation of the 1C Diesel Generator and auxiliaries, THEN Go To FNP-0-SOP-0-38.0-1C.

4.4 IF the task involves operation of the 2B Generator Diesel and auxiliaries, THEN Go To FNP-0-SOP-0-38.0-2B.

4.5 IF the task involves operation of the 2C Generator Diesel and auxiliaries, THEN Go To FNP-0-SOP-0-38.0-2C 5.0 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-0-SOP-38.0 Life of Plant HH6.051

6.0 REFERENCES

6.1 PROCEDURES 6.1.1 U-184852 - Service Manual Colt Industries 4075 kW DGs.

6.1.2 U-184804 - Service Manual Colt Industries 2850 kW DGs.

6.1.3 FSAR - Chapter 8 Section 8.3.1.1.7 6.1.4 NDS-90-2003, Diesel Fuel Oil Storage Tank Capacity 6.1.5 A-181001, Service Water System Functional System Description 6.1.6 FNP-0-SOP-0.7, General Instructions for Filling Out DG Test Data Logs and the DG Reliability Program 6.1.7 A-181005, Diesel Generator System Functional System Description 6.1.8 DCP C050889101, 2C Emergency Diesel Generator (EDG) Governor Upgrade.

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FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 12 of 37 6.2 DRAWINGS 6.2.1 D-172774 - Elementary Diagram Diesel Generator 1-2A Start, Stop

& Shutdown.

6.2.2 D-172772 - Elementary Diagram, Diesel Generator 1C Start, Stop &

Shutdown.

6.2.3 D-177033 - Logic Diagram Diesel 1-2A Auto Start & Loading.

6.2.4 D-177036 - Logic Diagram Diesel 1C Auto Start & Loading.

6.2.5 D-172860 - Motor Control Center 1N 6.2.6 D-172861 - Motor Control Center 1P 6.2.7 D-172862 - Motor Control Center 1S 6.2.8 D-172863 - Motor Control Center 1T 6.2.9 D-202539, 40, 41, 42 - MCC 2T 6.2.10 D-177032 - Logic Diagram Diesel 1B Auto Start & Loading.

6.2.11 D-177037 - Logic Diagram Diesel 2C Auto Start & Loading.

6.2.12 D-170119, D-200013, Sheet 3 or 6 - River Water, Service Water and Circulating Water Systems 6.2.13 D-170800 through D-170809, (200209-200213) - Diesel Air Start, Lube Oil, and Cooling Water Systems 6.2.14 D-170849 - P&ID Diesel Coolant Storage System.

6.2.15 D-207032 - Logic Diagram Diesel 2B Auto Start & Loading.

END OF PROCEDURE TEXT

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FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 13 of 37 TABLE 1 1-2A, 1B, 2B Jacket Water System Drain Points Valve Name 1-2A 1B 2B J. W. HX SHELL SIDE DRN QSR43V670 Q1R43V547 Q2R43V547 INTER-COOLER HX SHELL SIDE DRN QSR43V713 Q1R43V560 Q2R43V560 AUX J. W. HDR DISCH DRN ISO N/A Q1R43V886 Q2R43V617 J. W. DISCH HDR DRN QSR43V766 N/A N/A AUX J. W. PUMP SUCT DRN ISO Q1P21V535 Q1P21V537 Q2P21V537 AUX J. W. PUMP DISCH DRN ISO Q1P21V536 Q1P21V538 Q2P21V538 AUX J. W. PUMP SUCT VENT ISO Q1P21V541 Q1P21V539 Q2P21V539 AUX J. W. PUMP DISCH VENT Q1P21V542 Q1P21V540 Q2P21V540 1C, 2C Jacket Water System Drain Points Valve Name 1C 2C J. W. HX SHELL SIDE DRN QSR43V570 QSR43V554 AIR COOLANT HX SHELL SIDE DRN (Note 1)

QSR43V698 (Note 2)

QSR43V697 J. W. SUPP HDR DRN QSR43V735 QSR43V734 AUX J. W. PUMP SUCT HDR DRN Q1P21V531 Q1P21V533 AUX J. W. PUMP DISCH HDR DRN Q1P21V532 Q1P21V534 AUX J. W. PUMP SUCT VENT ISO Q1P21V543 Q1P21V545 AUX J. W. PUMP DISCH VENT ISO Q1P21V544 Q1P21V546 J. W. HX BYP LINE DRN QSR43V569 QSR43V553 P512 PUMP SUCT HDR DRN VLV 1C DG (Note 1)

QSR43V889 N/A P511 PUMP SUCT HDR DRN N/A (Note 2)

QSR43V891 ENGINE DRIVEN AIR COOLANT PUMP SUCT DRN (Note 1)

QSR43V704 (Note 2)

QSR43V703 Note 1 Valve is in series with 1C D/G Coolant Drn Hdr Iso, QSR43V890, which must also be open to allow draining.

Note 2 Valve is in series with 2C D/G Coolant Drn Hdr Iso, QSR43V892, which must also be open to allow draining.

Page 1 of 1

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FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 14 of 37 TABLE 2 NOTE When operating a diesel with service water supply temperature > 92°F, the following loading limits should be observed.

"Continuous Rating" Service Water Temperature Intercooler Water Temperature Deration Factor Allowable KW without exceeding DG Rating 1B, 2B Diesel Deration @ 4075 KW 97.3 °F 120.0 °F 0.0 %

4075 KW 106.2 °F 128.7 °F 1.18 %

4027 KW 1-2A Diesel Deration @ 4075 KW 97.3 °F 121.5 °F 0.20 %

4067 KW 106.2 °F 130.2 °F 1.38 %

4018 KW 1C, 2C Diesel Deration @ 2850 KW 97.3 °F 120.0 °F 0.0 %

2850 KW 106.2 °F 128.5 °F 1.15 %

2817 KW Page 1 of 2

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FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 15 of 37 TABLE 2 "2000 Hour Rating" Service Water Temperature Intercooler Water Temperature Deration Factor Allowable KW without exceeding DG Rating 1B, 2B Diesel Deration @ 4353 KW 97.3 °F 123.9 °F 0.53 %

4330 KW 106.2 °F 132.5 °F 1.69%

4279 KW 1-2A Diesel Deration @ 4353 KW 97.3 °F 125.7 °F 0.77 %

4320 KW 106.2 °F 134.3 °F 1.93%

4269 KW 1C, 2C Diesel Deration @ 3100 KW 97.3 °F 125.0 °F 0.68 %

3079 KW 106.2 °F 129.0 °F 1.81%

3044 KW Page 2 of 2

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FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 16 of 37 FIGURE 1 Page 1 of 1

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FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 17 of 37 FIGURE 2 Page 1 of 1

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FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 18 of 37 ATTACHMENT A GUIDELINES FOR RETURNING A DIESEL TO SERVICE FOLLOWING A MAINTENANCE OUTAGE 1.0 Frequently, maintenance activities on Diesels require the performance of diesel generator starting and loading. This operation of the diesels may be necessary to allow running adjustments as part of the maintenance procedure. As such, a maintenance start should be performed following maintenance which requires such checks. Acknowledgment of diesel maintenance starts must be made and properly documented prior to the associated diesel start. Maintenance activities which would invoke maintenance starts include quarterly and 18 month preventive maintenance and any maintenance which works on any control function of the diesel (such as work on governor, fuel rack systems or air start systems). These maintenance starts should normally include the closure of the output breaker and loading of the diesel to allow adjustment of the control systems during loaded operations. The return to service surveillance should be performed upon successful completion of all maintenance activities including required maintenance starts and loading. The on-call Emergency Director should be called if there is any question as to whether a maintenance start or return to service surveillance should be performed.

2.0 All maintenance starts should be performed using SOP-38.0 for guidance. Timing the start should be done for the purpose of gathering information. Normally, the maintenance start is expected to be performed as a dual header start.

3.0 Any time the diesel generator has been tagged out and the generator output breakers have been racked out, the output breakers should be closed to demonstrate diesel operability for the applicable unit. This can be accomplished during the maintenance run provided it is appropriately documented in the operators log book.

4.0 Any time a diesel generator has been tagged out of service for major maintenance a full load maintenance run should be performed. This allows a comprehensive review of diesel generator performance at expected operating conditions to make final adjustments to engine parameters (e.g., governor settings) prior to attempting a surveillance run.

5.0 Any time maintenance has been performed on an air start system during a diesel generator outage, a single header start is required on the applicable header. When no maintenance has been performed on the air systems, the Shift Supervisor should determine if it is necessary to perform single header starts on both air headers. After a satisfactory maintenance run on a diesel generator, justification for not performing two single header starts during the return to service STP must be documented in the applicable STP review sheet.

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FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 19 of 37 ATTACHMENT B DIESEL LUBE OIL REMOVAL AND REPLACEMENT GUIDANCE

{IR # 1-96-143}

WARNING Transferring lube oil from a diesel is an evolution that requires close monitoring to prevent overfilling of drums and subsequent spilling.

NOTES

New oil is the normal source of make up to the diesel lube oil sump.

All new oil in 55 gallon drums must be filtered prior to use. (Ref FNP-0-GMP-30.1 APP F)

A predetermined amount of oil removed from the diesel during maintenance or lube schedule may be reused in the diesel it came from.

Satisfactory sample analysis and filtering is required prior to reusing diesel lube oil.

Reusable or new oil may be added to a shutdown diesel. New oil shall be added to a running diesel.

1-2A, 1B and 2B lube oil heat exchangers do NOT drain to the diesel lube oil sump.

They must be drained independently.

Any hoses used to transfer lube oil should have their connections bagged to minimize the potential for a spill in the event the hose connections were to leak.

Consideration should be given to replacing the oil transfer pump filter prior to draining lube oil.

Facilities should be contacted ASAP to move full oil drums out of the DB (greater than 30 feet from the building) and to ensure drums are covered to prevent potential contamination from rain water.

6.0 If a complete drain of lube oil is desired, the filter vents and strainer vent will have to be opened.

7.0 Potentially reusable oil should be placed in lined open topped drums, or new drums, and labeled per NMP-SH-012, HAZARD COMMUNICATION PROGRAM.

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FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 20 of 37 ATTACHMENT B DIESEL LUBE OIL REMOVAL AND REPLACEMENT GUIDANCE

{IR # 1-96-143}

Page 2 of 2 8.0 Potentially reusable oil drums shall be caution tagged closed. The caution tags shall have wording to the effect of Oil on hold, awaiting sampling.

9.0 Potentially reusable oil shall be sampled and analyzed for acceptability prior to reuse.

10.0 If sample results indicate oil is unacceptable for reuse, non-reusable oil drums should be labeled as used oil -unacceptable for reuse.

11.0 FAC should be contacted to remove and properly dispose of oil unacceptable for reuse as soon as possible, preferably the same shift.

12.0 Oil drums that are unacceptable for reuse should be kept separated from oil drums that are acceptable for reuse.

13.0 If sample results indicate oil is acceptable for reuse, reusable oil drums should be caution tagged with wording to the effect of Acceptable for reuse in [insert the diesel that the oil came from here].

14.0 Oil deemed acceptable for reuse must be filtered prior to adding to the diesel lube oil sump.

15.0 Propping open fire doors and temporarily storing combustibles outside a diesel room should be reported to the Fire Protection Administrator.

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FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 21 of 37 ATTACHMENT C DIESEL GENERATOR FUEL OIL CONSUMPTION NOTE The information in the table below provides the run time that can be expected under three different diesel operating configurations assuming maximum loading and minimum initial storage tank level.

This can be used to assess replenishment requirements.

Diesels Running Storage Tanks Available Load Run Time

Consumption Rate 2 Large, 1 Small 4 (init. level 68%)

Max 5 1/4 days 807 gal/hr 3 Large, 1 Small 4 (init. level 68%)

Max 3 3/4 days 1104 gal/hr 3 Large, 2 Small 5 (init. level 68%)

Max 4 days 1317 gal/hr Consumption rates compute to an average per diesel of 297 gal/hr for 1-2A, 1B, and 2B Diesels (Large Diesels) and 213 gal/hr for 1C and 2C Diesels (Small Diesels) under maximum load. {CR 2000-044 and REA 98-1637}

Page 1 of 1

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 22 of 37 ATTACHMENT D READING DIESEL GENERATOR CRANKCASE VACUUM MANOMETER The following discussion and examples is intended to remove confusion which may exist concerning how to read the crankcase manometer installed on each of the emergency diesel generators.

In the example illustrated above, to calculate the pressure measured by this application, the readings above and below zero are added; with the result being 4. It is important to note the At rest reading of the manometer, in this example, 0.

Page 1 of 3 At rest, atmospheric pressure equals crankcase pressure Atmospheric Pressure Crankcase Pressure

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 23 of 37 ATTACHMENT D READING DIESEL GENERATOR CRANKCASE VACUUM MANOMETER A recent field trip to the Diesel Building (all EDGs secured) to ascertain the At rest manometer readings obtained the following information:

The manometer readings were:

1-2A D/G

-0.3

1C D/G

-1.7

-1.8

2B D/G

-2.4

1B D/G

-0.4

2C D/G 0.0

-0.2 The conclusion to be made from these readings is the manometers are low on operating fluid.

The important fact to realize is the At rest manometer reading, because both legs will use this as the point of reference for determining a value for crankcase vacuum when the diesel is in operation. To correctly calculate crankcase vacuum, determine the ALGEBRAIC DIFFERENCE between the two readings. The left leg (atmosphere) minus the right leg (crankcase). The resultant ALGEBRAIC DIFFERENCE is the crankcase pressure reading that should be recorded in the logs. Hopefully, this is a negative number, indicating a vacuum.

During routine D/G operations, a trend of the crankcase pressure would be helpful in determining the condition of the cylinders. To obtain a manometer reading, perform the following action: Left leg minus right leg.

Examples of hypothetical readings:

LEFT minus RIGHT

=

Reading What it means.

1

-1.7

-1.4

=

-0.3 Indicates crankcase vacuum.

2

-1.7 1.7

=

-3.4 Indicates crankcase vacuum.

3 1.7

-1.7

=

3.4 Indicates potential cylinder blow-by.

4

-3.6

-1.3

=

-2.3 Indicates crankcase vacuum.

5 1.5 0.5

=

1.0 Indicates potential cylinder blow-by.

Page 2 of 3

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 24 of 37 ATTACHMENT D READING DIESEL GENERATOR CRANKCASE VACUUM MANOMETER NOTE IF this page is revised, THEN ensure operator aid is updated.

READING DIESEL GENERATOR CRANKCASE VACUUM MANOMETER Crankcase vacuum is read by viewing levels in both legs of the manometer and calculating the algebraic difference in fluid level to obtain the value for crankcase vacuum.

The right-hand side of the manometer is the crankcase side of the gauge. A higher column of fluid on this side indicates a vacuum in the crankcase.

The left-hand side of the manometer is the atmospheric side. A higher column of fluid on this side indicates the crankcase is pressurized.

Subtract the right hand side from the left hand side to obtain log reading.

Ref. SOP-38.0 This Operator Aid is found on the following diesel gauge boards:

1-2A Diesel 1C Diesel 2B Diesel 1B Diesel 2C Diesel Page 3 of 3

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 25 of 37 APPENDIX 1 LOADING/UNLOADING GUIDANCE FOR 1C AND 2C DIESEL GENERATORS Page 1 of 1 NOTES

The values in parenthesis following the MW load hold points correspond to approximate EPB ammeter readings for that load. Major deviations from these values should be investigated.

{OR 2-97-314 and CMT 0003868}

When changing loads on a diesel, MVARs must be kept within the limits of Figure 2.

Fuel rack stop settings for Diesel Generators 1C and 2C have been increased from 112% to 120% in order to restore sufficient margin for EDG response during worst case dynamic loading. Exercise caution when loading and unloading DG 1C or 2C to ensure load on the DG remains within procedural guidance.

During D/G load changes, at each specified point, the D/G load shall be monitored to check for any drift in monitored parameters.

1.0 Loading

1.1 Slowly increase load to desired load up to 2850 kW (400-450 amps) with the following requirements:

Maintain load at 1000 kW (160-185 amps) for 15 minutes.

Maintain load at 1500 kW (220-275 amps) for 15 minutes.

Maintain load at 2000 kW (300-330 amps) for 15 minutes.

Maintain load at 2500 kW (360-390 amps) for 15 minutes.

2.0 Unloading

2.1 Slowly decrease load with the following requirements:

2.1.1 IF load is > 1500 kW, THEN Slowly decrease load to 1500 kW and maintain load for 15 minutes.

2.1.2 Slowly decrease load below 1500 kW.

2.1.3 Perform the following:

2.1.3.1 Go To Step 4.5.11 in FNP-0-SOP-38.0-1C if unloading 1C DG.

2.1.3.2 Go To Step 4.5.12 in FNP-0-SOP-38.0-2C if unloading 2C DG.

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 26 of 37 APPENDIX 2 LOADING/UNLOADING GUIDANCE FOR 1-2A, 1B AND 2B DIESEL GENERATORS Page 1 of 1 NOTES

The values in parenthesis following the MW load hold points correspond to approximate EPB ammeter readings for that load. Major deviations from these values should be investigated.

{OR 2-97-314 and CMT 0003868}

When changing loads on a diesel, MVARs must be kept within the limits of Figure 1.

Fuel rack stop settings for Diesel Generator 1-2A and 2B have been increased from 112% to 120%

in order to restore sufficient margin for EDG response during worst case dynamic loading. Exercise caution when loading and unloading DG 1-2A and 2B to ensure load on the DG remains within procedural guidance.

During D/G load changes, at each specified point, the D/G load shall be monitored to check for any drift in monitored parameters.

1.0 Loading

1.1 IF loading 1-2A, 1B or 2B Diesel Generator, PERFORM the following:

Slowly increase load to desired load up to 4075 kW (570-630 amps) with the following requirements:

Maintain load at 1000 kW (150-200 amps) for 15 minutes.

Maintain load at 2000 kW (300-350 amps) for 15 minutes.

Maintain load at 3000 kW (425-475 amps) for 15 minutes.

Maintain load at 3500 kW (480-530 amps) for 15 minutes.

2.0 Unloading

2.1 IF unloading 1-2A, 1B or 2B Diesel Generator, PERFORM the following:

2.1.1 IF load is > 2000 kW, THEN Slowly decrease load to 2000 kW and maintain load for 15 minutes.

2.1.2 Slowly decrease load below 2000 kW.

2.1.3 Perform the following:

2.1.3.1 Go To Step 4.5.12 of FNP-0-SOP-38.0-1-2A if unloading 1-2A DG.

2.1.3.2 Go To Step 4.5.12 of FNP-0-SOP-38.0-1B if unloading 1B DG.

2.1.3.3 Go To Step 4.5.12 of FNP-0-SOP-38.0-2B if unloading 2B DG.

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 27 of 37 APPENDIX 3 DG START/RUN DATA DG STARTED __________.

DATE/TIME STARTED ____________

Performed by:___________________________________

Shift Supervisor Review (EPB Logs Reviewed):

(SS)

Shift Support Supervisor Review (Diesel Bldg Diesel Run Logs Reviewed):

(SSS)

Copy of this Attachment sent to Diesel System Engineer or the System Engineer Supervisor for DGs:

(SSS)

Data Recorded in appropriate Units Control Room log using the Diesel Start Data (SOP-38) stamp:

(SSS)

This appendix consists of 9 pages.

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 28 of 37 APPENDIX 3 DG START / RUN DATA Page 1 of 9 1.0 Verify the version of this procedure is the current version. {OR 1-98-498}

2.0 Identify the reason for starting the Diesel Generator. (Check the appropriate box)

Scheduled surveillance FNP-___-STP-Cover Page Date/Time stamp:

STP performed after maintenance to verify operability.

FNP-___-STP-Cover Page Date/Time stamp:

STP performed to verify operability when other train is inoperable.

FNP-___-STP-Cover Page Date/Time stamp:

Maintenance start.

Record document used for guidance.__________________

(Document reason in comments section.)

Diesel started due to actual undervoltage not associated with testing.

Record bus that experienced undervoltage. ____________

Diesel started due to actual Safety Injection signal not associated with testing.

INDICATE AFFECTED UNIT INDICATE AFFECTED TRAIN UNIT 1 UNIT 2 A TRAIN B TRAIN BOTH TRAINS An FNP-0-SOP-38 Start.

(Document Reason in Comments section.)

2C DG is started due to an actual station blackout condition.

INDICATE AFFECTED UNIT UNIT 1 UNIT 2

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 29 of 37 APPENDIX 3 DG START / RUN DATA Page 2 of 9 3.0 Have the Diesel Building SO begin Attachment 1 of this appendix.

NOTE Ensure the correct information obtained by using the same IPC as the unit the DG will be tied to.

4.0 Check the selected DG Output breaker (pre-start) IPC status OPEN.

5.0 Obtain DG START/RUN DATA as follows:

DG started:(circle one) 1-2A 1C 2B 1B 2C Unit DG aligned to: (circle one)

Unit 1 Unit 2 None Diesel start attempt: (circle one)

Successful / Unsuccessful Date / time started:

/

Type of Start (circle one)

SLOW FAST Seconds to start: (if timed) (N/A for slow start)

Freq Speed Volts SST Air Header started on: (circle one)

1

2 Both DG Loaded: (circle one)

Yes No Time Loaded above 50% Load:

HH/mm 6.0 Record Service Water supply temperature:_____ °F NOTE The intent of the following step is to differentiate between an IPC problem and a failure of the DG output breaker MOC switch.

7.0 IF loaded, THEN check the selected DG Output breaker IPC status CLOSED.

7.1 IF the selected DG Output breaker IPC status did not change state (refer to step 4.0),

THEN dispatch personnel to check the position of the MOC switch.

7.1.1 Submit a CR for evaluation of the problem, including all indications that may be beneficial.

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 30 of 37 APPENDIX 3 DG START / RUN DATA Page 3 of 9 8.0 Record date and time diesel loaded to at least 50% of continuous load rating (2100 Kw on 1-2A, 1B and 2B Diesels and 1500 Kw on 1C and 2C Diesels)

Date and Time

/

9.0 Record date and time diesel load reduced to less than 50% of continuous load rating.

Date and Time

/

NOTE Step 10.0 is NOT applicable to maintenance starts.

10.0 Circle either Y or N:

Y N

Start resulted from automatic real signal-actual bus undervoltage (not caused by preplanned test or maintenance sequence) or actual safety injection (caused by plant parameters reaching setpoints, manually initiated safety injection, inadvertent - not preplanned - safety injection).

Y N

Start resulted from manual real signal - purposefully started due to need for emergency power to a bus.

Y N

Start resulted from preplanned test (STP) or maintenance sequence.

Y N

Diesel loaded to at least 50% of continuous load rating for at least one hour.

Y N

Diesel run terminated due to preplanned test or maintenance sequence (STP was completed as written).

Y N

Diesel run terminated due to operator error that does not or would not prevent the diesel from being restarted and brought to load in a few minutes without corrective action.

Y N

Diesel run terminated due to inadvertent or spurious trip signal that is not operative in the emergency mode. Spurious trips refer to false or illegitimate signals such as a shorted contact or other faulty equipment that results in automatic trip. Valid trip signals due to actual condition (such as actual high crankcase pressure) are not considered inadvertent or spurious.

Y N

Diesel run terminated due to malfunction of equipment not operative in the emergency mode (examples: synchronizing circuits, SST, pre-lube pump, non-shutdown alarm devices, non-essential generator protection devices).

Y N

Diesel run terminated due to minor water leaks and oil leaks (fuel or lube) that would not preclude operation of the DG in an emergency.

COMMENTS:

(Explanation of all abnormal occurrences, indications and alarms observed during this DG start/run or any other pertinent information.)

11.0 Attach the completed Attachment 1 to Appendix 3.

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 31 of 37 APPENDIX 3 DG START / RUN DATA Page 4 of 9 ATTACHMENT 1 INCREASED DG MONITORING DURING MAINTENANCE AND SURVEILLANCE RUNS.

1.0 Purpose This attachment has been developed to provide the minimum requirements for diesel generator monitoring during maintenance and surveillance runs. (S-2012-20) 2.0 Instructions 2.1 When performing DG monitoring, the following field observations shall be performed, at a minimum.

Monitor gage board parameters to include crankcase vacuum.

Inspect for unusual operating characteristics, such as fluid leaks (fuel, JW, or oil), exhaust leaks, excessive vibrations, abnormal sounds, etc.

Monitor temperature indications for proper response to current engine conditions.

Monitor filter and strainer performance.

Monitor pump performance. (discharge pressure, abnormal noise, seal leaks, etc.)

Monitor oil levels. (engine sump, governor, turbochargers and generator)

Monitor room ventilation. (fans, intake screens and louvers)

Breakers and alarm panels and should be inspected for abnormal or unusual conditions.

JW expansion tank level.

2.2 Any abnormal indications shall be brought to the attention of the Shift Supervisor for investigation and resolution.

2.3 IF the DG is started following maintenance, THEN maintenance personnel shall directly observe the DG start.

2.4 Operations personnel shall directly observe the DG start.

2.5 Diesel operation shall be monitored locally AND at the EPB for approximately fifteen (15) minutes following DG start.

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 32 of 37 APPENDIX 3 DG START / RUN DATA Page 5 of 9 2.6 Diesel operation shall be monitored locally AND at the EPB for approximately fifteen (15) minutes following each load increase (during load ascension, normally at fifteen minute intervals). This observation should be of sufficient duration to allow parameters monitored to stabilize.

2.7 IF delays occur in loading the DG, THEN the DG shall be monitored locally and at the EPB at approximately thirty (30) minute intervals.

2.8 At least one set of DG run logs shall be taken with the DG at full load. DG run logs shall be taken hourly for periods of extended operation.

2.9 In addition to the logs normally taken, Attachment 1, Data Sheet 1 will be completed for each start/run of any DG.

2.10 Mark any Data Sheet N/A for D/G not covered by this Appendix 3.

2.11 For extended periods of operation, additional Data Sheets should be printed and attached as necessary.

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 33 of 37 APPENDIX 3 DG START / RUN DATA Page 6 of 9 DATA SHEET 1, page 1 NOTES Using a thermal gun, take the following temperatures at the designated/marked locations each time load is added to the DG.

If any of the water temperatures exceeds 110oF, contact Engineering for guidance.

If any of the water temperatures reaches 120oF, the DG should be immediately shutdown.

The taking of these logs may be secured by the Shift Supervisor with engineering concurrence once the DG has reached full load and at least three sets of stable1 temperature readings have been taken.

1-2A Diesel Generator West Side MIN MAX TIME TIME TIME TIME TIME TIME TIME Description West Air Intercooler Water Temperature In N/A 120°F West Air Intercooler Water Temperature Out N/A 120°F Intercooler West Bank Air Inlet Temperature N/A N/A Intercooler West Bank Air Outlet Temperature N/A N/A 1-2A Diesel Generator East Side MIN MAX TIME TIME TIME TIME TIME TIME TIME Description East Air Intercooler Water Temperature In N/A 120°F East Air Intercooler Water Temperature Out N/A 120°F Intercooler East Bank Air Inlet Temperature N/A N/A Intercooler East Bank Air Outlet Temperature N/A N/A Note 1: Stable is defined as no change greater than 3°F in temperature after two minutes of operation.

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 34 of 37 APPENDIX 3 DG START / RUN DATA Page 7 of 9 DATA SHEET 1, page 2 NOTES Using a thermal gun, take the following temperatures at the designated/marked locations each time load is added to the DG.

If any of the water temperatures exceeds 110oF, contact Engineering for guidance.

If any of the water temperatures reaches 120oF, the DG should be immediately shutdown.

The taking of these logs may be secured by the Shift Supervisor with engineering concurrence once the DG has reached full load and at least three sets of stable1 temperature readings have been taken.

1B Diesel Generator West Side MIN MAX TIME TIME TIME TIME TIME TIME TIME Description West Air Intercooler Water Temperature In N/A 120°F West Air Intercooler Water Temperature Out N/A 120°F Intercooler West Bank Air Inlet Temperature N/A N/A Intercooler West Bank Air Outlet Temperature N/A N/A 1B Diesel Generator East Side MIN MAX TIME TIME TIME TIME TIME TIME TIME Description East Air Intercooler Water Temperature In N/A 120°F East Air Intercooler Water Temperature Out N/A 120°F Intercooler East Bank Air Inlet Temperature N/A N/A Intercooler East Bank Air Outlet Temperature N/A N/A Note 1: Stable is defined as no change greater than 3°F in temperature after two minutes of operation.

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 35 of 37 APPENDIX 3 DG START / RUN DATA Page 8 of 9 DATA SHEET 1, page 3 NOTES Using a thermal gun, take the following temperatures at the designated/marked locations each time load is added to the DG.

If any of the water temperatures exceeds 110oF, contact Engineering for guidance.

If any of the water temperatures reaches 120oF, the DG should be immediately shutdown.

The taking of these logs may be secured by the Shift Supervisor with engineering concurrence once the DG has reached full load and at least three sets of stable1 temperature readings have been taken.

2B Diesel Generator West Side MIN MAX TIME TIME TIME TIME TIME TIME TIME Description West Air Intercooler Water Temperature In N/A 120°F West Air Intercooler Water Temperature Out N/A 120°F Intercooler West Bank Air Inlet Temperature N/A N/A Intercooler West Bank Air Outlet Temperature N/A N/A 2B Diesel Generator East Side MIN MAX TIME TIME TIME TIME TIME TIME TIME Description East Air Intercooler Water Temperature In N/A 120°F East Air Intercooler Water Temperature Out N/A 120°F Intercooler East Bank Air Inlet Temperature N/A N/A Intercooler East Bank Air Outlet Temperature N/A N/A Note 1: Stable is defined as no change greater than 3°F in temperature after two minutes of operation.

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 36 of 37 APPENDIX 3 DG START / RUN DATA Page 9 of 9 DATA SHEET 1, page 4 NOTES Using a thermal gun, take the following temperatures at the designated/marked locations each time load is added to the DG.

If any of the water temperatures exceeds 110oF, contact Engineering for guidance.

If any of the water temperatures reaches 120oF, the DG should be immediately shutdown.

The taking of these logs may be secured by the Shift Supervisor with engineering concurrence once the DG has reached full load and at least three sets of stable1 temperature readings have been taken.

1C Diesel Generator MIN MAX TIME TIME TIME TIME TIME TIME TIME Description Intercooler Water Into Air Cooler N/A N/A Scavenging Air Into Cylinders N/A N/A Note 1: Stable is defined as no change greater than 3°F in temperature after two minutes of operation.

NOTES Using a thermal gun, take the following temperatures at the designated/marked locations each time load is added to the DG.

If any of the water temperatures exceeds 110oF, contact Engineering for guidance.

If any of the water temperatures reaches 120oF, the DG should be immediately shutdown.

The taking of these logs may be secured by the Shift Supervisor with engineering concurrence once the DG has reached full load and at least three sets of stable1 temperature readings have been taken.

2C Diesel Generator MIN MAX TIME TIME TIME TIME TIME TIME TIME Description Intercooler Water Into Air Cooler N/A N/A Scavenging Air Into Cylinders N/A N/A Note 1: Stable is defined as no change greater than 3°F in temperature after two minutes of operation.

SHARED Farley Nuclear Plant Procedure Number Ver.

FNP-0-SOP-38.0 123.0 10/28/2013 18:05:32 DIESEL GENERATORS Page Number 37 of 37 APPENDIX 4 SURVEILLANCE TESTS CONTAINING GOVERNOR SETTINGS Diesel Generator Affected Surveillance Test Shared Unit 1 Unit 2 1-2A D/G FNP-0-STP-80.1 FNP-1-STP-80.14 FNP-2-STP-80.14 FNP-0-STP-80.5 FNP-1-STP-80.20 FNP-2-STP-80.20 FNP-0-STP-80.6 FNP-1-STP-80.21 FNP-2-STP-80.21 FNP-0-STP-80.11 FNP-1-STP-80.25 FNP-2-STP-80.25 1C D/G FNP-0-STP-80.2 FNP-1-STP-80.14 FNP-2-STP-80.14 FNP-0-STP-80.5 FNP-1-STP-80.18 FNP-2-STP-80.18 FNP-0-STP-80.7 FNP-1-STP-80.23 FNP-2-STP-80.23 FNP-0-STP-80.11 FNP-1-STP-80.25 FNP-2-STP-80.25 FNP-0-STP-80.12 2C D/G 1B D/G FNP-1-STP-80.1 FNP-1-STP-80.5 FNP-1-STP-80.6 FNP-1-STP-80.8 FNP-1-STP-80.11 FNP-1-STP-80.22 FNP-1-STP-80.25 2B D/G FNP-2-STP-80.1 FNP-2-STP-80.5 FNP-2-STP-80.6 FNP-2-STP-80.8 FNP-2-STP-80.11 FNP-2-STP-80.22 FNP-2-STP-80.25

FNP ILT 37 ADMIN Page 1 of 7 Developer S. Jackson 05/07/14 NRC Approval SEE NUREG 1021 FORM ES-301-3 A.1.b, Conduct of Operations - RO & SRO A.1.b TITLE: Perform A Shutdown Margin Calculation in modes 1 & 2.

PROGRAM APPLICABLE: SOT SOCT OLT X LOCT ACCEPTABLE EVALUATION METHOD: X PERFORM SIMULATE DISCUSS EVALUATION LOCATION: SIMULATOR CONTROL ROOM X 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 of the task by reviewing the completed form.

2. Provide the examinee with the required materials to perform this JPM.

TASK STANDARD:

Perform a Shutdown Margin calculation while in Mode 1, using STP-29.5 accurately to within the acceptable ranges identified within each critical elements standard.

Identify the need to emergency borate.

Examinee:

Overall JPM Performance:

Satisfactory Unsatisfactory Evaluator Comments (attach additional sheets if necessary)

EXAMINER:

FNP ILT-37 ADMIN A.1.b Page 2 of 7 CONDITIONS When I tell you to begin, you are to Determine the excess Shutdown Margin using STP-29.5, SHUTDOWN MARGIN CALCULATION IN MODES 1 AND 2 (TAVG 547°F), for Unit 1. The conditions under which this task is to be performed are:

a. Unit 1 is stable at 90% with the ramp on hold

b. Bank D indicates 192 by Group Demand.

c. Seven of the Bank D rods (H2, B8, H14, F6, F10, K10, K6) are at 192 steps by DRPI.

d. Rod P8, in the D bank, has been determined to be stuck.

e. Rod P8 is at 174 steps by DRPI.

f. All other rods are at 228 steps.

g. Core burnup is 9,800 MWD/MTU burnup.

h. FNP-1-STP-29.5, SHUTDOWN MARGIN CALCULATION IN MODES 1 AND 2 (TAVG 547°F), initial conditions are satisfied.

i. The Shift Supervisor has directed you to complete FNP-1-STP-29.5 starting at step 5.1 and identify whether or not emergency boration is required.

INITIATING CUE:

You may begin.

EVALUATION CHECKLIST RESULTS:

ELEMENTS:

STANDARDS:

(CIRCLE)

START TIME NOTE: Elements 1 through 13 are evaluated by comparing the completed Calculation page to the values and ranges of each element. The acceptable responses are ALSO listed on the calculation KEY.

1. Step A.1: Document Core Burnup

1) Value entered: 9,800 MWD S / U

2. Step A.2: Document Power Level

2) Value entered: 90% entered S / U

FNP ILT-37 ADMIN A.1.b Page 3 of 7 EVALUATION CHECKLIST RESULTS:

ELEMENTS:

STANDARDS:

(CIRCLE)

3. Step A.3: Determine penalty steps for Banks below RIL.

a) Using COLR figure 1 determines RIL for 90% power level.

b) Gathers data from Conditions page c) Determines penalty steps per bank.

3) Value entered: ZERO (0)

(range: NONE) a) Determines RIL from COLR CB D/ RIL = 167 (range: 165-170) from COLR.

CBC / RIL = FULL OUT (or 228).

b) Documents given Demand positions CB D/ Demand 192 All others: FULL OUT (or 228) c) Calculates difference All values: ZERO (0)

(range: NONE)

S / U

4. Step A.4: Determine number of penalty steps for RODS below RIL.

4) Value entered: ZERO (0)

S / U

5. Step B.1: Determine Rod Worth for all control and shutdown bands at Zero steps using given power and burnup:

a) Uses Curve 77 pg 1 for 90% power and > 9000 - < 10000MWD

5) Value entered: 6043.

(range: NONE)

S / U

6. Step B.2: Calculate penalty value of rod banks.

6) Value entered of ZERO (0)

S / U

7. Step B.3: Calculate penalty value of individual rods.

7) Value entered of ZERO (0)

S / U

8. Step B.4.a; Determine most reactive Rod worth.

8) Value entered of 1389 (range: NONE) a)

From Curve 77 pg 2 for

> 9000 - < 10000MWD S / U

FNP ILT-37 ADMIN A.1.b Page 4 of 7 EVALUATION CHECKLIST RESULTS:

ELEMENTS:

STANDARDS:

(CIRCLE)

9. Step B.4.b; Calculate rod worth of stuck/untrippable rod

9) Value entered of 3472.5 (range: 3471-3473 for various rounding technique effects) a)

of stuck: 1 rod b)

B.4.a: 1389 Calculate using equation.

S / U

10. Step B.5; Calculate penalized rod worth

10) Value entered of (-) 2313.5 NOTE: NEG (-) SIGN IS IMPORTANT FOR THIS CALCULATION/Evaluation

( range: (-)2313 to (-) 2315 )

Transfer data from other steps:

a)

B.1: 6043 b)

B.2: 0 c)

B.3: 0 d)

B.4.b: 3472.5 (+.5, -1.5)

Calculate using equation.

S / U

11. Step B.6; Determine power defect for given conditions

11) Value entered of 1701 (range:

NONE) a)

From Curve 78 for

> 9000 - < 10000MWD S / U

FNP ILT-37 ADMIN A.1.b Page 5 of 7 EVALUATION CHECKLIST RESULTS:

ELEMENTS:

STANDARDS:

(CIRCLE)

12. Step B.8; Calculate available Shutdown Reactivity

12) Value entered of (-) 562.5 pcm (range: -562 to -564)

NOTE: NEG (-) SIGN IS IMPORTANT FOR THIS CALCULATION/Evaluation a)

Transfer data:

i. B.5: (-) 2313.5 (range: (-)2313 to (-)2315) ii. B.6: 1701 Calculate using equation.

S / U

13. Step B.9; Calculate Excess Shutdown Margin

13) Value entered of (+) 1207.5 (range: +1206 to +1208)

NOTE: POS (+) SIGN IS IMPORTANT FOR THIS CALCULATION/Evaluation a)

Transpose data:

i. B.8: (-) 562.5 (-562 to -564) ii. Calculate S / U NOTE: Element 15 is not required to be completed but is likely to be completed/initialed if initiated as a group/classroom setting.

14. Step B.10: Identifies Need to Emergency Borate

14) Notifies Shift Supervisor of need to Emergency Borate.

S / U

15. completes task:

a) Signs and dates Calculation Sheet b) Initials step 5.1 c) Asks for verification of calculation

15) Completes sign off.

a) Signs and dates form b) Initials step 5.1 of procedure.

S / U TERMINATE After calculation of Excess Shutdown Margin AND element 14 completed.

STOP TIME

FNP ILT-37 ADMIN A.1.b Page 6 of 7 CRITICAL ELEMENTS: Critical Elements are denoted with an asterisk () before the element number.

GENERAL

REFERENCES:

1. FNP-1-STP-29.5, VER 5.0

2. KA: G2.1.20 - 4.6 / 4.6 G2.1.23 - 4.3 / 4.4 GENERAL TOOLS AND EQUIPMENT:

1. FNP-1-STP-29.5, ver 5.0

2. PCB-VOL1-CRV77, Cycle 26 rev 11

3. PCB-VOL1-CRV78, Cycle 26 rev 11

4. Unit 1, COLR for FNP Unit1 Cycle 26, Rev 1, Figure 1.

5. Pen/Pencil

6. calculator Critical ELEMENT justification:

STEP Evaluation 1-4, 6, 15 Not critical - These steps have no impact on the SDM calculation.

5, 7-13 Critical - Calculation completion; each step is critical in accurately determining available SDM and Excess SDM.

14 Critical - Task Objective; Identification that Acceptance Criteria NOT met and Emergency boration IS required to ensure corrective action is initiated and compliance with T.S. is restored.

COMMENTS:

FNP ILT-37 ADMIN A.1.b HANDOUT Pg 1 of 1 CONDITIONS When I tell you to begin, you are to Determine if Shutdown Margin is adequate using STP-29.5, SHUTDOWN MARGIN CALCULATION IN MODES 1 AND 2 (TAVG 547°F), for Unit 1. The conditions under which this task is to be performed are:

a. Unit 1 is stable at 90% with the ramp on hold

b. Bank D indicates 192 by Group Demand.

c. Seven of the Bank D rods (H2, B8, H14, F6, F10, K10, K6) are at 192 steps by DRPI.

d. Rod P8, in the D bank, has been determined to be Stuck.

e. Rod P8 is at 174 steps by DRPI.

f. All other rods are at 228 steps.

g. Core burnup is 9,800 MWD/MTU burnup.

h. FNP-1-STP-29.5, SHUTDOWN MARGIN CALCULATION IN MODES 1 AND 2 (TAVG 547°F), initial conditions are satisfied.

i. The Shift Supervisor has directed you to complete FNP-1-STP-29.5 starting at step 5.1 and identify whether or not emergency boration is required.

UNIT 1 06/01/11 15:34:35 FNP-1-STP-29.5 Page 1 of 3 Version 5.0 SHUTDOWN MARGIN IN MODES 1 AND 2 A.

PRESENT CONDITIONS A.1 Core Burnup ________ MWD/MTU A.2 Power Level. %

A.3 Determine number of penalty steps for ROD BANKS below RIL.

(Use COLR or convert the RIL computer reading from % to steps)

A.3.a Record data in table ROD BANKS BANK RIL HEIGHT BANK DEMAND STEPS BELOW RIL CBA FULL OUT CBB FULL OUT CBC CBD SDA FULL OUT SDB FULL OUT TOTAL STEPS BELOW RIL KEY 9800 90 Full Out (228)

Full Out (228)

Full Out (228) 192 Full Out (228)

Full Out (228) 0 0

0 0

0 Full Out(228) 167 (165-170)

RANGE for CBD RIL:

LO: Readability of COLR RIL curve may allow as low as 165 steps; although this is < than the curve limit of 166.9, if calculated. The assumptions within the curve development provides for this readability error.

HI: conservatism allowed by P&L 4.1 may be instituted and a value of up to 170 steps may be selected since the specific value between the Y-axis increments may not be calculated.

UNIT 1 06/01/11 15:34:35 FNP-1-STP-29.5 Page 2 of 3 Version 5.0 A.4 Determine number of penalty steps for RODS below RIL which were not counted in A.3 (Rods below RIL on DRPI when the BANK demand is above RIL)

(Use COLR or convert the RIL computer reading from % to steps)

A.4.a Record data in table ROD NUMBER RIL POSITION DRPI POSITION DIFFERENCE TOTAL STEPS BELOW RIL B.

SHUTDOWN MARGIN NOTE: Write the values from Curves 77 & 78 directly into the surveillance test.

The correct sign convention has been entered in the STP.

B.1 Rod worth for all control and shutdown banks at zero steps at Present Burnup (A.1) and Power Level (A.2).

()

pcm (Curve 77 Page 1)

B.2 Penalty value of rod banks below insertion limit:

steps 75 pcm/step =

(A.3.a)

B.3 Penalty value of individual rods below RIL which were not counted in A.3 (Rods below RIL on DRPI when the BANK demand is above RIL) steps 10 pcm/step =

(A.4.a)

(+)

pcm

(+)

pcm KEY N/A 6043 0

0 0

UNIT 1 06/01/11 15:34:35 FNP-1-STP-29.5 Page 3 of 3 Version 5.0 B.4 Stuck / Untrippable Rod penalty:

(B.4.a is N/A and B.4.b is zero if there are no stuck/untrippable rods)

B.4.a Worth of most reactive rod worth at present burnup (A.1) ()

pcm from Curve 77 pg. 2 B.4.b Calculate worth of Stuck/untrippable rods

[

()

1.75 ] + [()

0.75] = ()

pcm

(# Stuck/

(B.4.a)

(B.4.a) untrippable rods) (Most reactive (Most reactive rod worth) rod worth)

B.5 Penalized rod worth considering stuck/untrippable rods, misaligned rods, rods below the insertion limit, and uncertainty:

[()

+ ______ + ______ ()______] 0.9 =

( )

pcm (B.1)

(B.2)

(B.3)

(B.4.b)

B.6 Power Defect at Power Level (A.2) and Burnup (A.1)

(Curve 78).

()

pcm B.7 Void Collapse Defect.

(+) 50 pcm B.8 Available Shutdown Reactivity:

( ) () +

50 pcm (B.5)

(B.6)

(B.7)

B.9 Shutdown Margin in excess of required Shutdown Margin (B.8 Required SDM from the COLR):

( )__________ pcm () 1770 pcm =

( ) pcm (B.8) Required SDM (SDMExcess) from the COLR B.10 If B.9 is positive, THEN emergency borate per FNP-1-AOP-27.0, EMERGENCY BORATION, to establish the required shutdown margin otherwise Shutdown Margin is adequate for the Present plant condition.

Date:

Performed by:

Date:

Verified by:

1389 1389 1389 1

3472.5 range: 3471 to 3473 KEY Range considers rounding up or rounding down 6043 0

3472.5

(+.5,

-1.5)

[-6043+3472.5]*0.9 = -2313.45 (rounded to -2313.5)

[-6043+3471]*0.9 = -2314.8 (rounded to -2315)

[-6043+3473] *0.9 = -2313

(-) 2313.5 range: (-)2313 to (-)2315 1701 1701

(+) 1207.5 range:

(+)1206 to

(+)1208 Emergency Boration IS required May also state that a Rx trip may be warranted (P&L 4.3).

DATE-- Element 15-if assumes/states emergency boration completed Signed-- element 15-if assumes/states Emerg Boration completed

(-) 562.5 range:

(-) 562 to (-) 564 0

(-) 2313.5 range: (-)2313 to

(-)2315

(-) 562.5 range:

(-) 562 to (-) 564

UNIT 1 06/01/11 15:34:35 FNP-1-STP-29.5 May 3, 2011 Version 5.0 FARLEY NUCLEAR PLANT SURVEILLANCE TEST PROCEDURE FNP-1-STP-29.5 S

A F

E T

Y SHUTDOWN MARGIN CALCULATION IN MODES 1 AND 2 (TAVG 547F)

R E

L A

T E

D PROCEDURE USAGE REQUIREMENTS SECTIONS Continuous Use:

Procedure must be open and readily available at the work location. Follow procedure step by step unless otherwise directed by the procedure.

ALL Reference Use:

Procedure or applicable section(s) available at the work location for ready reference by person performing steps.

NONE Information Use:

Available on plant site for reference needed.

NONE Approved:

David L Reed (for)

Date Issued: May 5, 2011 Operations Manager

UNIT 1 06/01/11 15:34:35 FNP-1-STP-29.5 Version 5.0 FARLEY NUCLEAR PLANT SURVEILLANCE TEST REVIEW SHEET SURVEILLANCE TEST NO.

FNP-1-STP-29.5 TECHNICAL SPECIFICATION REFERENCE TR 13.1.1; LCO 3.1.4; LCO 3.1.5; LCO 3.1.6 TITLE SHUTDOWN MARGIN CALCULATION IN MODES 1 AND 2 (TAVG 547F)

MODE(S) REQUIRING TEST:

1*,2*

See special test exceptions of above specifications TEST RESULTS (TO BE COMPLETED BY TEST PERFORMER)

PERFORMED BY DATE/TIME 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

[ ] 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 TECHNICAL GROUP-REACTOR ENG REVIEW REVIEWED BY DATE

[ ] Satisfactory and Approved

[ ] Comments:

UNIT 1 06/01/11 15:34:35 FNP-1-STP-29.5 Page 1 of 1 Version 5.0 TABLE OF CONTENTS Procedure Contains Number of Pages STRS.........................................................1 Body..........................................................2 Shutdown Margin......................................3

UNIT 1 06/01/11 15:34:35 FNP-1-STP-29.5 Version 5.0 FARLEY NUCLEAR PLANT UNIT 1 SURVEILLANCE TEST PROCEDURE STP-29.5 SHUTDOWN MARGIN CALCULATION IN MODES 1 AND 2 (TAVG 547F) 1.0 Purpose 1.1 The purpose of this procedure is to verify that the SHUTDOWN MARGIN is greater than the limits of the Technical Requirements Manual TR 13.1.1 as directed by Technical Specifications in Modes 1 or 2:

1.1.1 One or more rod(s) untrippable (LCO 3.1.4),

1.1.2 One or more rod(s) not aligned within 12 steps of their group step counter demand position (LCO 3.1.4),

1.1.3 One or more shutdown banks not within insertion limits specified in the COLR (LCO 3.1.5),

1.1.4 Control bank insertion, sequence, or overlap not within limits specified in the COLR (LCO 3.1.6). (This condition does not affect shutdown margin unless control banks are below insertion limits) 2.0 Acceptance Criteria 2.1 The Shutdown Margin shall be greater than or equal to the value specified in the COLR.

3.0 Initial Conditions 3.1 The revision of this procedure has been verified to be the current revision and correct unit for the task. (OR 1-98-498) 3.2 TAVG 547°F.

3.3 TAVG +/- 1°F of programmed value. (Needed for Power Defect to be accurate) 3.4 The plant is in Mode 1 or 2 with Keff 1.

3.5 Technical Specifications required action entered to verify SDM to be within the limits provided in the COLR OR Shift Supervisor desires to perform.

SJJ SJJ SJJ SJJ SJJ

UNIT 1 06/01/11 15:34:35 FNP-1-STP-29.5 Version 5.0 4.0 Precautions and Limitations 4.1 Read all curves as accurately as possible OR most conservatively.

4.2 Observe proper algebraic sign notation throughout the calculation.

4.3 IF necessary to emergency borate due to inadequate shutdown margin, THEN consideration should be given to tripping the reactor and entering FNP-1-EEP-0, REACTOR TRIP OR SAFETY INJECTION concurrent with the emergency boration.

5.0 Instructions NOTE: For calculating shutdown margin at power, the amount of reactivity by which the reactor would be subcritical from its present condition must be determined.

If the reactor were to shutdown instantaneously, the changes in reactivity would be from control rod position and power defect. In the instant that the reactor shut down, reactivity changes from xenon, samarium and boron concentration would be zero.

5.1 Enter the information required on the attached calculation sheets and calculate the shutdown margin.

NOTE: Verification of shutdown margin calculation by a licensed individual other than the test performer, should take place as soon as practical, and any differences resolved immediately.

A Shift Foreman that serves as verifier of the calculation may also serve as reviewer on the Surveillance Test Review Sheet.

5.2 Verify shutdown margin calculated in step 5.1.

6.0 References 6.1 Technical Specifications: LCOs 3.1.4, 3.1.5, & 3.1.6.

6.2 Technical Requirement Manual TR 13.1.1 6.3 Core Operating Limits Report (COLR).

UNIT 1 06/01/11 15:34:35 FNP-1-STP-29.5 Page 1 of 3 Version 5.0 SHUTDOWN MARGIN IN MODES 1 AND 2 A.

PRESENT CONDITIONS A.1 Core Burnup ________ MWD/MTU A.2 Power Level. %

A.3 Determine number of penalty steps for ROD BANKS below RIL.

(Use COLR or convert the RIL computer reading from % to steps)

A.3.a Record data in table ROD BANKS BANK RIL HEIGHT BANK DEMAND STEPS BELOW RIL CBA FULL OUT CBB FULL OUT CBC CBD SDA FULL OUT SDB FULL OUT TOTAL STEPS BELOW RIL

UNIT 1 06/01/11 15:34:35 FNP-1-STP-29.5 Page 2 of 3 Version 5.0 A.4 Determine number of penalty steps for RODS below RIL which were not counted in A.3 (Rods below RIL on DRPI when the BANK demand is above RIL)

(Use COLR or convert the RIL computer reading from % to steps)

A.4.a Record data in table ROD NUMBER RIL POSITION DRPI POSITION DIFFERENCE TOTAL STEPS BELOW RIL B.

SHUTDOWN MARGIN NOTE: Write the values from Curves 77 & 78 directly into the surveillance test.

The correct sign convention has been entered in the STP.

B.1 Rod worth for all control and shutdown banks at zero steps at Present Burnup (A.1) and Power Level (A.2).

()

pcm (Curve 77 Page 1)

B.2 Penalty value of rod banks below insertion limit:

steps 75 pcm/step =

(A.3.a)

B.3 Penalty value of individual rods below RIL which were not counted in A.3 (Rods below RIL on DRPI when the BANK demand is above RIL) steps 10 pcm/step =

(A.4.a)

(+)

pcm

(+)

pcm

UNIT 1 06/01/11 15:34:35 FNP-1-STP-29.5 Page 3 of 3 Version 5.0 B.4 Stuck / Untrippable Rod penalty:

(B.4.a is N/A and B.4.b is zero if there are no stuck/untrippable rods)

B.4.a Worth of most reactive rod worth at present burnup (A.1) ()

pcm from Curve 77 pg. 2 B.4.b Calculate worth of Stuck/untrippable rods

[

()

1.75 ] + [()

0.75] = ()

pcm

(# Stuck/

(B.4.a)

(B.4.a) untrippable rods) (Most reactive (Most reactive rod worth) rod worth)

B.5 Penalized rod worth considering stuck/untrippable rods, misaligned rods, rods below the insertion limit, and uncertainty:

[()

+ ______ + ______ ()______] 0.9 =

( )

pcm (B.1)

(B.2)

(B.3)

(B.4.b)

B.6 Power Defect at Power Level (A.2) and Burnup (A.1)

(Curve 78).

()

pcm B.7 Void Collapse Defect.

(+) 50 pcm B.8 Available Shutdown Reactivity:

( ) () +

50 pcm (B.5)

(B.6)

(B.7)

B.9 Shutdown Margin in excess of required Shutdown Margin (B.8 Required SDM from the COLR):

( )__________ pcm () 1770 pcm =

( ) pcm (B.8) Required SDM (SDMExcess) from the COLR B.10 If B.9 is positive, THEN emergency borate per FNP-1-AOP-27.0, EMERGENCY BORATION, to establish the required shutdown margin otherwise Shutdown Margin is adequate for the Present plant condition.

Date:

Performed by:

Date:

Verified by:

FNP ILT 37 ADMIN 1 OF 5 A.2, Equipment Control - RO A.2 - RO (mod)

TITLE: Complete selected sections of STP-1.0, OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS.

PROGRAM APPLICABLE: SOT SOCT OLT X LOCT ACCEPTABLE EVALUATION METHOD: X PERFORM SIMULATE DISCUSS 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 of the task by reviewing the completed form.

2. Provide the examinee with the required materials to perform this JPM.

TASK STANDARD:

Complete selected sections of STP-1.0, OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS, Appendix 1.

Identify conditions that do not meet acceptance criteria.

Examinee:

Overall JPM Performance:

Satisfactory Unsatisfactory Evaluator Comments (attach additional sheets if necessary)

EXAMINER:

Developer S. Jackson 05/07/14 NRC Approval SEE NUREG 1021 FORM ES-301-3

FNP ILT 37 ADMIN 2 OF 5 CONDITIONS When I tell you to begin, you are to complete pages 12-14 & 27 of FNP-1-STP-1.0, OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS, Appendix 1. The conditions under which this task is to be performed are:

a. Unit 1 is at 60% power and stable following a load rejection.

b. The UO has completed taking the data for STP-1.0, Appendix 1, for night shift with the exception of pages 12-14 & 27.

c. You are the extra plant operator and have been directed by the Shift Supervisor to:

1. Complete pages 12-14 & 27 of FNP-1-STP-1.0, Appendix 1 for night shift using the pictures provided.

2. Identify any condition that does not meet acceptance criteria.

EVALUATION CHECKLIST RESULTS:

ELEMENTS:

STANDARDS:

(CIRCLE)

START TIME NOTE: This is a classroom setting ADMIN JPM task.

Meters must be read accurately enough to ensure the proper identification of out of tolerance instruments and properly identify in tolerance instruments.

1.

Records all data not previously recorded.

1) Records all data on pages 12-14

& 27 not previously recorded.

S / U

2.

Determines #4, LI-496 for C SG, does not meet acceptance criteria.

(NOT CRITICAL: May record in the comments section of the STRS).

2) Determines #4, LI-496 for C SG, does not meet acceptance criteria.

(May record in the comments section of the STRS).

S / U

3.

Informs SS that LI-496 for C SG does not meet acceptance criteria.

3) Informs SS that LI-496 for C SG does not meet acceptance criteria, writes CR, & records CR number in the comments section. (CUE: SS acknowledges & CR 123456 has been written).

S / U

4.

Determines #23, Axial Flux Difference (AFD), does not meet acceptance criteria.

(NOT CRITICAL: May record in the comments section of the STRS).

4) Determines #23, Axial Flux Difference, does not meet acceptance criteria.

(May record in the comments section of the STRS).

S / U

FNP ILT 37 ADMIN 3 OF 5 EVALUATION CHECKLIST RESULTS:

ELEMENTS:

STANDARDS:

(CIRCLE)

5.

Informs SS that AFD does not meet acceptance criteria, writes CR, & records CR number in the comments section.

5) Informs SS that AFD does not meet acceptance criteria, writes CR, & records CR number in the comments section. (CUE:

SS acknowledges & CR 234567 has been written).

S / U

6.

Determines #25, CH A RVLIS, has less than 4 sensors operable per channel & does not meet acceptance criteria.

(NOT CRITICAL: May record in the comments section of the STRS).

6) Determines #25, CH A RVLIS, has less than 4 sensors operable per channel does not meet acceptance criteria.

(May record in the comments section of the STRS).

S / U

7.

Informs SS that CH A RVLIS does not meet acceptance criteria, writes CR, & records CR number in the comments section.

7) Informs SS that CH A RVLIS does not meet acceptance criteria, writes CR, & records CR number in the comments section. (CUE: SS acknowledges & CR 345678 has been written).

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.

GENERAL

REFERENCES:

1.

FNP-1-STP-1.0 Ver 112

2.

COLR, Cycle 26 Ver 1

3.

K/A: G2.2.12 - 3.7 / 4.1 G2.2.42 - 3.9 / 4.6 GENERAL TOOLS AND EQUIPMENT:

Provide:

1. Partially filled out copy of FNP-1-STP-1.0, Attachment 1.

2. Pictures of parts of MCB.

FNP ILT 37 ADMIN 4 OF 5 Critical ELEMENT justification:

STEP Evaluation

1.

NOT Critical - As long as the proper indications are identified, then Tech Spec requirements can be met.

2.

Critical - Task Objective. Recognizing that out of tolerance indications exists ensures the plant is operated per its License.

3.

NOT Critical - Administrative function.

4.

Critical - Task Objective. Recognizing that out of tolerance indications ensures the plant is operated per its License.

5.

NOT Critical - Administrative function.

6.

Critical - Task Objective. Recognizing that out of tolerance indications exists ensures the plant is operated per its License.

7.

NOT Critical - Administrative function.

COMMENTS:

FNP ILT 37 ADMIN Page 1 of 1 CONDITIONS When I tell you to begin, you are to complete pages 12-14 & 27 of FNP-1-STP-1.0, OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS, Appendix 1. The conditions under which this task is to be performed are:

a. Unit 1 is at 60% power and stable following a load rejection.

b. The UO has completed taking the data for STP-1.0, Appendix 1, for night shift with the exception of pages 12-14 & 27.

c. You are the extra plant operator and have been directed by the Shift Supervisor to:

1. Complete pages 12-14 & 27 of FNP-1-STP-1.0, Appendix 1 for night shift using the pictures provided.

2. Identify any condition that does not meet acceptance criteria.

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-STP-1.0 112.0 7/21/2014 08:30:56 OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS Page Number 1 of 99 OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS PROCEDURE LEVEL OF USE CLASSIFICATION PER NMP-AP-003 CATEGORY SECTIONS Continuous:

ALL

Reference:

NONE Information:

NONE Approved By: David L. Reed____________

Effective Date: 07/12/14 Operations Manager

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-STP-1.0 112.0 7/21/2014 08:30:56 OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS Page Number 2 of 99 Version Number Version Description 105.0 Revised step 58 of Appendix 1 by deleting PDI-3317 reference. Changed acceptance criteria for Appendix 1, item 1 from 150K to 160K gallons.

(CR355457). Added guidance to acceptance criteria for item 14 of appendix 1 per ES request.

105.1 Appendix 1, Changed ARO rod height for Fuel Cycle 25.

105.2 Added note below containment temperature page referencing FNP-0-SOP-0.16.

105.3 Added place keeping blocks to item 38 to signify which CTMT cooler fan is selected at the time STP-1.0 is performed..

105.4 Revised note in Item 1 to read 13.0 ft for CST level. CR 465834 105.5 Deleted Item 58 and combined requirements with Item 34. Renumbered.

105.6 Appendix 1, item 11, changed EOL Coastdown variance information. CR 482797 106.0 App 1 Item 52, App 2 Item 16, App 3 Item 17; Incorporated new Met Tower instruments per DCP C072201201 106.1 App 1 Item 52, App 2 Item 16, App 3 Item 17; Added units for data and changed IPC group reference 107.0 Implemented changes to LTOP items per LDCR 2012011.

107.1 Corrected missing border in item 53 of Appendix 1.

108.0 Deleted requirement to check PAHAs every Sunday night. CR 778297 108.1 Corrected typo in TS reference for Appendix 1, item 90. CR 787702 109.0 Added item 70.0. CR 804136 110.0 Added expected variation for N35&36 111.0 Revised Item 37 to include guidance to Contact ES to evaluate UHS operability if recorded SW Pond temperature reaches or exceeds 90 deg. F.

112.0 Major revision to the instructions and acceptance criteria. CR 818977, CR 788318, deleted fig. 1

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-STP-1.0 112.0 7/21/2014 08:30:56 OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS Page Number 3 of 99 TABLE OF CONTENTS 1.0 PURPOSE............................................................................................................................................ 4 2.0 PRECAUTION AND LIMITATIONS..................................................................................................... 4 3.0 INITIAL CONDITIONS......................................................................................................................... 4 4.0 ACCEPTANCE CRITERIA................................................................................................................... 4 5.0 INSTRUCTIONS.................................................................................................................................. 4 6.0 RECORDS........................................................................................................................................... 7

7.0 REFERENCES

..................................................................................................................................... 7 APPENDIX 1, OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS, MODES 1, 2, 3, 4. 8 APPENDIX 2, OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS MODE 5............... 54 APPENDIX 3, OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS MODE 6............... 80

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-STP-1.0 112.0 7/21/2014 08:30:56 OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS Page Number 4 of 99 1.0 PURPOSE This procedure provides a means for recording data required on a shift and daily basis.

2.0 PRECAUTION AND LIMITATIONS Each Appendix contains applicable Precaution and Limitation statements.

3.0 INITIAL CONDITIONS None 4.0 ACCEPTANCE CRITERIA Each Appendix contains applicable Acceptance Criteria statement.

5.0 INSTRUCTIONS NOTE The Shift or Daily Logs shall be considered complete when all items have been completed, with the following exceptions: (1) items that have been designated as being performed anytime during the shift, and (2) 1600 SFP readings. These items shall be completed prior to the final review.

5.1 A Daily and Shift Surveillance for applicable modes shall be completed every day.

5.2 Utilize one of the methods given below to verify each parameter, condition, component or system as specified by the LCO.

5.2.1 Verification of a Measured Parameter.

Confirm the measured parameter is within the limits specified in the Acceptance Criteria column.

5.2.2 Verification of a Specified Condition.

Confirm the component, instrument, or system listed satisfies that specified in the Acceptance Criteria column.

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-STP-1.0 112.0 7/21/2014 08:30:56 OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS Page Number 5 of 99 5.2.3 Channel Check Observe the instrument response. The operability of instrument channels, which have indication available, shall be verified by one or more of the following:

Comparing readings on channels which monitor the same variable recognizing any differences in the actual process variable between sensor locations (for example, compare Power Channel N41 with redundant Power Channels N42 and N43),

Comparing readings between channels that monitor the same variable and bear a known relationship to one another (for example, comparing intermediate range and source range neutron monitoring during startup or shutdown when both channels indicate on scale),

Comparing readings between channels which monitor different variables and bear a known relationship to one another (for example, at a given power level the primary coolant outlet temperature is a certain value).

5.3 Complete the appropriate Appendix for the applicable mode(s) per the following:

5.3.1 The operator completing the surveillance shall enter the mode, time, and his/her name in the appropriate space on the review sheet.

5.3.2 Except where specified in the Appendix, the data for each item should be taken AND logged in the column provided between the times given below to ensure that 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months surveillance requirements are met:

1100 and 1230 on Day Shift 2300 and 0030 on Night shift 5.3.3 List shift data under the appropriate shift column.

5.3.4 Data need not be recorded in sequence.

5.3.5 Recording a numerical value for an item when not in a Mode that requires an entry is permissible.

5.3.6 IF data can NOT be logged for any of the following conditions, enter N/A (OR IN TEST as applicable) in the appropriate space.

The equipment or instrument is NONFUNCTIONAL (broken, or in maintenance) AND the applicable LCO action statement has been entered.

The plant is in a mode or condition such that the surveillance does not apply. {AI2008200006}

The channel is in test.

Condition makes logging impractical.

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-STP-1.0 112.0 7/21/2014 08:30:56 OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS Page Number 6 of 99 5.3.7 Where no value is required to be logged for an item, the operator will initial the appropriate space.

5.3.8 WHEN a channel check is performed on an instrument that has a numerical readout, the actual value will be recorded, unless otherwise noted. Initials must be used to document performance of other channel checks and verifications.

5.3.9 IF a daily OR shift surveillance item can NOT be taken from the listed indicator, BUT is available by some other indication, THEN that value will be listed in the appropriate space and the indicator actually used for the surveillance noted.

5.3.10 Some data has been assigned an eight hour commitment and will be logged in the appropriate time slot.

5.3.11 The operator completing the miscellaneous section shall enter the title, time, value, acceptance criteria comments, and technical specification requirement in the appropriate columns.

5.3.12 Surveillance required due to special or abnormal plant conditions which are not normally taken on a shift or daily basis shall be entered in the miscellaneous section of the appropriate Appendix.

5.3.13 The Shift or Daily Logs shall be submitted to the Shift Supervisor for his/her review by the following times:

1300 for Day Shift 0100 for Night Shift 5.3.14 The Shift Supervisor or Shift Support Supervisor shall enter any discrepancies and/or comments in the review section of the appropriate Appendix.

5.4 The body of this procedure shall be printed out and attached to the appropriate Appendix. {AI2008200007}

5.5 The modes for which surveillance on an item is required are listed in the Acceptance Criteria column.

5.6 The acceptance criteria for the logged data is also listed in the Acceptance Criteria column.

5.7 The technical specification reference is listed for each item in the Tech. Spec.

column.

5.8 The operator shall inform the Shift Supervisor promptly of any new discrepancies in the Shift or Daily Logs.

5.9 Upon notification of a new discrepancy, and during review of existing discrepancies, the Shift Supervisor is responsible for evaluating the discrepancy and ensuring that all appropriate actions are initiated including any that are required to meet any applicable Technical Specification action statements.

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-STP-1.0 112.0 7/21/2014 08:30:56 OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS Page Number 7 of 99 5.10 Comments regarding all discrepancies shall be included in the comments section of the Surveillance Test Review Sheet.

5.11 Compare data taken to the expected variations between instrumentation channels.

This information, where applicable, along with the maximum allowable deviation is provided in the appropriate Appendix at the step where data is being taken and in Table 1 of Appendix 1.

5.11.1 IF the variance is greater than expected, submit a Condition Report to the Shift Supervisor to correct the out of tolerance instrument.

5.12 Marking the STRS as Acceptable means that all data points are within their applicable tolerances, meeting the acceptance criteria, or identified and justified by a reason in the comments section (or Appendix).

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-1.0 Life of Plant H06.045

7.0 REFERENCES

7.1 Technical Specifications.

7.2 FNP-0-M-011, Offsite Dose Calculation Manual.

7.3 FSAR Chapter 16 7.4 Technical Requirements Manual END OF PROCEDURE TEXT

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-STP-1.0 112.0 7/21/2014 08:30:56 OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS Page Number 8 of 99 APPENDIX 1, OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS, MODES 1, 2, 3, 4 This appendix consists of 47 pages.

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-STP-1.0 112.0 7/21/2014 08:30:56 OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS Page Number 9 of 99 APPENDIX 1 - MODES 1, 2, 3, 4 Page 2 of 47 SURVEILLANCE TEST REVIEW SHEET SURVEILLANCE TEST NO.

FNP-1-STP-1.0 TECHNICAL SPECIFICATION REFERENCE Various TITLE:

Operations Daily and Shift Surveillance Requirements MODE(S) REQUIRING TEST:

1, 2, 3, 4 NIGHT SHIFT OPERATOR

________________/_________________

(PRINT) (SIGNATURE)

DATE/TIME

______/______

MODE ACCEPTABLE YES NO NIGHT SHIFT SUPERVISOR REVIEW

/

(PRINT) (SIGNATURE)

DAY SHIFT OPERATOR

________________/__________________

(PRINT) (SIGNATURE)

DATE/TIME

_______/______

MODE ACCEPTABLE YES NO DAY SHIFT SUPERVISOR REVIEW

/

(PRINT) (SIGNATURE)

COMMENTS:

FINAL SHIFT SUPERVISOR/SHIFT SUPPORT SUPERVISOR REVIEW PROCEDURE PROPERLY COMPLETED SATISFACTORY PER FNP-0-AP-5 0800 AND 1600 SFP READINGS HAVE BEEN REVIEWED COMMENTS:

REVIEWED BY:

/

(PRINT) (SIGNATURE) (DATE)

ENGINEERING SUPPORT GROUP SCREENING (IF APPLICABLE)

SCREENED BY:

/

(PRINT) (SIGNATURE) (DATE)

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-STP-1.0 112.0 7/21/2014 08:30:56 OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS Page Number 10 of 99 APPENDIX 1 - MODES 1, 2, 3, 4 Page 3 of 47 1.0 PURPOSE This procedure provides a means for recording data required on a shift and daily basis.

2.0 PRECAUTION AND LIMITATIONS 2.1 Each parameter should be logged as accurately as possible.

2.2 It is permissible to use N/A for any parameter under the following conditions:

{AI2008200006}

The equipment or instrument is INOPERABLE (broken, or in maintenance) and the applicable LCO action statement has been entered.

The plant is in a mode or condition such that the surveillance does not apply.

2.3 The SS/SM will be notified immediately if the As Found condition is out of tolerance when the As Found condition is evaluated against the acceptance / functional criteria.

3.0 INITIAL CONDITIONS 3.1 Verify the version of this procedure has been verified to be the current version.

{OR 1-98-498}

3.2 Verify this procedure to be for the correct unit for the task. {OR 1-98-498}

3.3 Verify the Body of FNP-1-STP-1.0 is attached to this Appendix.

{AI2008200007}

4.0 ACCEPTANCE CRITERIA Logged data shall be within the acceptance criteria listed in the appropriate Appendix.

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-STP-1.0 112.0 7/21/2014 08:30:56 OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS Page Number 12 of 99 Appendix 1 Modes 1, 2, 3, 4 Page 5 of 47 TITLE NIGHT DAY ACCEPTANCE CRITERIA TECH SPEC

4.

SG Level (%)

SG 1A LI 474 Channel Check LI 475 Mode 1, 2; Mode 1, 2; 3.3.1-1(14):SR 3.3.1.1 3.3.2-1(5.b):SR 3.3.2.1 LI 476 Mode 1, 2, 3; Mode 1, 2, 3; 3.3.2-1(6.b):SR 3.3.2.1 3.3.3-1(4):SR 3.3.3.1 LR 477 (WR)

PEN 1 SG 1B LI 484 Mode 3; LI 485 NR Level 30% for at least 2 SGs SR 3.4.5.2 LI 486 Mode 4; LR 477 (WR)

PEN 2 WR Level 75% for SG in operating Reactor Coolant Loop SR 3.4.6.2 SG 1C LI 494 Expected variation: +/- 4%

LI 495 Maximum deviation between channels:

8%

LI 496 LR 477 (WR)

PEN 3

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-STP-1.0 112.0 7/21/2014 08:30:56 OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS Page Number 13 of 99 Appendix 1 Modes 1, 2, 3, 4 Page 6 of 47 TITLE NIGHT DAY ACCEPTANCE CRITERIA TECH SPEC

5.

SG Feed Flow (lbm/hr)

Mode 1, 2; SG 1A FI 477 x 106 x 106 Channel Check N/A FI 476 x 106 x 106 SG 1B FI 487 x 106 x 106 FI 486 x 106 x 106 SG 1C FI 497 x 106 x 106 FI 496 x 106 x 106 NOTE IF any channel III or IV pressure transmitter is out of service for surveillance testing or otherwise inoperable, THEN the corresponding steam flows may be channel checked using the appropriate points off the plant computer (in units of KBH) or by I&C direct readout. Since the MCB FIs are compensated for steam pressure but the computer points are not, compare only FI data to FI data, or computer point to computer point. Note on the Surveillance Test Review Sheet comments section whenever the alternate method of channel check is used.

6.

SG Steam Flow (lbm/hr)

Mode 1, 2d, 3d; SG 1A FI 474 (FE0474B) x 106 x 106 d) Except when one MSIV is closed in each steam line.

3.3.2-1(4.e):

SR 3.3.2.1 FI 475 (FE0475B) x 106 x 106 Channel Check SG 1B FI 484 (FE0484B) x 106 x 106 FI 485 (FE0485B) x 106 x 106 SG 1C FI 494 (FE0494B) x 106 x 106 FI 495 (FE0495B) x 106 x 106

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-STP-1.0 112.0 7/21/2014 08:30:56 OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS Page Number 14 of 99 Appendix 1 Modes 1, 2, 3, 4 Page 7 of 47 TITLE NIGHT DAY ACCEPTANCE CRITERIA TECH SPEC

7.

SG Pressure (psig)

SG 1A PI 474 Channel Check PI 475 Mode 1, 2, 3; Mode 1, 2d, 3b,d; 3.2-1(1.e.2):SR 3.3.2.1 3.3.2-1(4.d):SR 3.3.2.1 PI 476 Mode 1, 2, 3b; Mode 1, 2, 3; 3.3.2-1(1.e.1):SR 3.3.2.1 3.3.3-1(8):SR 3.3.3.1 SG 1B PI 484 (b) Above the P-12 interlock.

(d) Except when one MSIV closed in each steam line.

PI 485 PI 486 Expected variation: +/- 40 psi Maximum deviation between channels:

50 psi SG 1C PI 494 PI 495 PI 496

8.

RCS Temperature (°F)

THOT (TR 413)

Loop 1 Mode 1, 2, 3; 3.3.3-1(1):SR 3.3.3.1 Loop 2 Channel Check 3.3.3-1(2):SR 3.3.3.1 Loop 3 TCOLD (TR 410)

Loop 1 Loop 2 Expected variation: +/- 17°F Loop 3 Maximum deviation between channels:

23°F

UNIT 1 Farley Nuclear Plant Procedure Number Ver FNP-1-STP-1.0 112.0 7/21/2014 08:30:56 OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS Page Number 27 of 99 Appendix 1 Modes 1, 2, 3, 4 Page 20 of 47 TITLE NIGHT DAY ACCEPTANCE CRITERIA TECH SPEC

23.

Axial Flux Difference (%)

N-41 Mode 1, Power 50% RTP; Within limits of COLR SR 3.2.3.1 N-42 N-43 N-44 AFD Target Point for Present Power Level (Curve 64)

24.

Sub Cooled Margin Monitor (°F)

RTD CETC Mode 1, 2, 3; 3.3.3-1(10):

SR 3.3.3.1 Q1B14TI2354-A Channel Check Record subcooling margin and TMAX Q1B14TI2355-B TMAX Q1B14TI2301-A Q1B14TI2302-B

25.

Reactor Vessel Level Indicating System (MCB Mimic)

Mode 1, 2, 3; Perform Channel Check. Verify at least 4 sensors operable per channel by comparing each valid sensor with its corresponding sensor in the opposite train to verify they display the same state. IF one train is inoperable, THEN verify that at least 4 sensors indicate properly in the opposite train.

3.3.3-1(16):

SR 3.3.3.1 Initial Channel A Channel B 84.4 84.1 70.6 66.8 583 587

110UNIT 1

Farley Nuclear Plant Procedure Number Ver FNP-1-STP-1.0 112.0 7/21/2014 08:30:56 OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS Page Number 53 of 99 Appendix 1 Modes 1, 2, 3, 4 Page 46 of 47 TABLE 1 Expected Variations Between Instrumentation Channels During Normal Operation NOTE If recorded data is greater than the expected variation, a CR should be submitted to correct the out of tolerance instrument and so note in the deficiency section of the Surveillance Test Review Sheet.

Parameter Expected Variation Maximum Deviation Between Channels Reactor coolant average temperature indicators

+/- 3°F 6°F Delta-T indicators

+/- 3.7%

7.4%

Reactor coolant flow indicators

+/- 5%

9%

Pressurizer pressure indicators

+/- 30 psi 48 psi Pressurizer level indicators

+/- 4%

8%

Steam generator level indicators (narrow range)

+/- 4%

8%

Steam line pressure indicators

+/- 40 psi 50 psi Turbine impulse chamber pressure indicators

+/- 20 psi 40 psi The overpower T reactor trip setpoints

+/- 3.5%

6%

The overtemperature T reactor trip setpoints

+ 7.5%

18.8%

Top nuclear flux indicators

+/- 2%

3.6%

Bottom nuclear flux indicators

+/- 2%

3.6%

RCS temperature recorders

+/- 17°F 23°F

FNP ILT 37 ADMIN Page 1 of 5 A.2, Equipment Control - SRO A.2.S TITLE: Review selected sections of STP-1.0, OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS & identify any required actions.

PROGRAM APPLICABLE: SOT SOCT OLT X LOCT ACCEPTABLE EVALUATION METHOD: X PERFORM SIMULATE DISCUSS 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 of the task by reviewing the completed form.

2. Provide the examinee with the required materials to perform this JPM.

TASK STANDARD:

Review selected sections of STP-1.0, OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS & identify any Tech Spec actions required due to inoperable components which do not meet acceptance criteria Examinee:

Overall JPM Performance:

Satisfactory Unsatisfactory Evaluator Comments (attach additional sheets if necessary)

EXAMINER:

Developer S. Jackson 05/07/14 NRC Approval SEE NUREG 1021 FORM ES-301-3

FNP ILT 37 ADMIN Page 2 of 5 CONDITIONS When I tell you to begin, you are to review pages 10-13 & 26 of FNP-1-STP-1.0, OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS. The conditions under which this task is to be performed are:

a. Unit 1 is at 39% power.

b. You are the Shift Supervisor and must:

1. Review pages 11-14 & 27 of FNP-1-STP-1.0.

2. IF any component is inoperable, THEN identify ALL required actions for ALL inoperable components.

EVALUATION CHECKLIST RESULTS:

ELEMENTS:

STANDARDS:

(CIRCLE)

START TIME

1.

Reviews all readings on pages 11-14 & 27 and determines that they are in spec with the exception of the elements below:

1) Reviews all readings and determines that they are in spec with the exception of the following:

S / U

2.

Determines #4, LI-496 for C SG, is out of tolerance low & inoperable.

2) Determines #4, LI-496 for C SG, is out of tolerance low &

inop.

S / U Note: Applicant may also say an ADMIN LCO is required for 3.3.3 (4) Cond A. This is NOT required.

3 Determines the required actions from Tech Specs with LI-496 for C SG inoperable.

3) Determines from Tech Specs:

a) *3.3.1-1(14): Cond E b) *3.3.2-1(5.b): Cond. I c) *3.3.2-1(6.b): Cond. D S / U S / U S / U

4.

Determines #8, TR-410 Tcold for Loop 1 &

2, are greater than Maximum deviation between channels & inop, and Loop 3 Tcold is out of commission.

4) Determines #8, TR-410 Tcold for Loop 1 & 2, are greater than Maximum deviation between channels & at least one of the two are inop, and Loop 3 Tcold is out of commission.

S / U

5.

Determines the required actions from Tech Specs with less than 2 Tcolds operable.

5) Determines from Tech Specs:

a) *3.3.3-1(2):Condition A S / U

FNP ILT 37 ADMIN Page 3 of 5 EVALUATION CHECKLIST RESULTS:

ELEMENTS:

STANDARDS:

(CIRCLE)

6.

Determines #25, CH A RVLIS, has only 3

(<4) sensors operable & Channel A is inop.

6) Determines #25, CH A RVLIS, has less than 4 sensors operable

& is inop.

S / U

7.

Determines the required actions from Tech Specs with CH A RVLIS inoperable.

7) Determines from Tech Specs:

a) *3.3.3-1(16): Condition A.

S / U STOP TIME Terminate when all actions have been identified.

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

GENERAL

REFERENCES:

1. FNP-1-STP-1.0 Ver 108.0

2. Technical Specifications, Ver 193

3. Technical Specification Bases, Ver 63

4. TRM, Ver 29

5. TRM Bases, Ver 13

6. K/A: G2.2.40 - 3.4 / 3.7 G2.2.42 - 3.9 / 4.6 GENERAL TOOLS AND EQUIPMENT:

1. Partially marked up version of STP-1.0

2. Technical Specifications, TRM, & Basis (Computer version is available in classroom, book is available in sequester room).

FNP ILT 37 ADMIN Page 4 of 5 Critical ELEMENT justification:

STEP Evaluation

1.

NOT Critical - Not required as long as applicant recognizes correct Tech Spec issues.

2.

NOT Critical - Evaluation of this element is encompassed by Element 3.

3.

Critical. Task Objective. (3 elements) Proper evaluation of Tech Specs is required to be able to operate within the facility license.

4.

NOT Critical - Evaluation of this element is encompassed by Element 5

5.

Critical. Task Objective. Proper evaluation of Tech Specs is required to be able to operate within the facility license.

6.

Not Critical - Evaluation of this element is encompassed by Element 7.

7.

Critical. Task Objective. Proper evaluation of Tech Specs is required to be able to operate within the facility license.

COMMENTS:

FNP ILT-37 HANDOUT Page 1 of 1 CONDITIONS When I tell you to begin, you are to review pages 10-13 & 26 of FNP-1-STP-1.0, OPERATIONS DAILY AND SHIFT SURVEILLANCE REQUIREMENTS. The conditions under which this task is to be performed are:

a. Unit 1 is at 39% power.

b. You are the Shift Supervisor and must:

1. Review pages 11-14 & 27 of FNP-1-STP-1.0.

2. IF any component is inoperable, THEN identify ALL required actions for ALL inoperable components.

RTS Instrumentation 3.3.1 Farley Units 1 and 2 3.3.1-17 Amendment No. 183 (Unit 1)

Amendment No. 176 (Unit 2)

Table 3.3.1-1 (page 4 of 8)

Reactor Trip System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS CONDITIONS SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE TRIP SETPOINT

11.

Not used

12.

Undervoltage RCPs 1(f) 3 M

SR 3.3.1.6 SR 3.3.1.10 2640 V 2680 V

13.

Underfrequency RCPs 1(f) 3 M

SR 3.3.1.6 SR 3.3.1.10 56.9 Hz 57 Hz

14.

Steam 1,2 3 per SG E

SR 3.3.1.1 27.6%

28%

Generator (SG)

SR 3.3.1.7 Water Level SR 3.3.1.10 Low Low SR 3.3.1.14 (f)

Above the P-7 (Low Power Reactor Trips Block) interlock.

ESFAS Instrumentation 3.3.2 Farley Units 1 and 2 3.3.2-12 Amendment No. 185 (Unit 1)

Amendment No. 180 (Unit 2)

Table 3.3.2-1 (page 4 of 4)

Engineered Safety Feature Actuation System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS CONDITIONS SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE TRIP SETPOINT

5.

Turbine Trip and Feedwater Isolation

a.

Automatic Actuation Logic and Actuation Relays 1,2 2 trains H

SR 3.3.2.2 SR 3.3.2.3 SR 3.3.2.8 NA NA

b.

SG Water Level -

1,2 3 per SG I

SR 3.3.2.1 82.4%

82%

High High (P-14)

SR 3.3.2.4 SR 3.3.2.7 SR 3.3.2.9

c.

Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

6.

Auxiliary Feedwater

a.

Automatic Actuation Logic and Actuation Relays 1,2,3 2 trains G

SR 3.3.2.2 SR 3.3.2.3 SR 3.3.2.8 NA NA

b.

SG Water Level -

1,2,3 3 per SG D

SR 3.3.2.1 27.6%

28%

Low Low SR 3.3.2.4 SR 3.3.2.7 SR 3.3.2.9 (g)

c.

Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

d.

Undervoltage Reactor Coolant Pump 1,2 3

I SR 3.3.2.5 SR 3.3.2.7 SR 3.3.2.9 2640 volts 2680 volts

e.

Trip of all Main Feedwater Pumps 1

2 per pump J

SR 3.3.2.10 NA NA

7.

ESFAS Interlocks

a.

Automatic Actuation Logic and Actuation Relays 1,2,3 2 trains L

SR 3.3.2.2 SR 3.3.2.3 SR 3.3.2.8 NA NA

b.

Reactor Trip, P-4 1,2,3 1 per train, 2 trains C

SR 3.3.2.6 NA NA

c.

Pressurizer Pressure, P-11 1,2,3 3

K SR 3.3.2.4 SR 3.3.2.7 2003 psig 2000 psig

d.

Tavg - Low Low, P-12 (Decreasing)

(Increasing) 1,2,3 1 per loop K

SR 3.3.2.4 SR 3.3.2.7 542.6°F 545.4°F 543°F 545°F (g)

Applicable to MDAFW pumps only.

PAM Instrumentation 3.3.3 Farley Units 1 and 2 3.3.3-1 Amendment No. 170 (Unit 1)

Amendment No. 163 (Unit 2) 3.3 INSTRUMENTATION 3.3.3 Post Accident Monitoring (PAM) Instrumentation LCO 3.3.3 The PAM instrumentation for each Function in Table 3.3.3-1 shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS

NOTE--------------------------------------------------------

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more Functions with one required channel inoperable.

A.1 Restore required channel to OPERABLE status.

30 days B.

Required Action and associated Completion Time of Condition A not met.

B.1 Initiate action in accordance with Specification 5.6.8.

Immediately C.

One or more Functions with two required channels inoperable.

C.1 Restore one channel to OPERABLE status.

7 days

PAM Instrumentation 3.3.3 Farley Units 1 and 2 3.3.3-3 Amendment No. 167 (Unit 1)

Amendment No. 159 (Unit 2)

Table 3.3.3-1 (page 1 of 1)

Post Accident Monitoring Instrumentation FUNCTION REQUIRED CHANNELS CONDITION REFERENCED FROM REQUIRED ACTION D.1

1. RCS Hot Leg Temperature (Wide Range) 2 E

2. RCS Cold Leg Temperature (Wide Range) 2 E

3. RCS Pressure (Wide Range) 2 E

4. Steam Generator (SG) Water Level (Wide or Narrow Range) 2/SG E

5. Refueling Water Storage Tank Level 2

E

6. Containment Pressure (Narrow Range) 2 E

7. Pressurizer Water Level 2

E

8. Steam Line Pressure 2/SG E

9. Auxiliary Feedwater Flow Rate 2

E

10. RCS Subcooling Margin Monitor 2

E

11. Containment Water Level (Wide Range) 2 E

12. Core Exit Temperature - Quadrant 1 2(a)

E

13. Core Exit Temperature - Quadrant 2 2(a)

E

14. Core Exit Temperature - Quadrant 3 2(a)

E

15. Core Exit Temperature - Quadrant 4 2(a)

E

16. Reactor Vessel Level Indicating System 2

F

17. Condensate Storage Tank Level 2

E

18. Deleted

19. Containment Area Radiation (High Range) 2 F

(a) A channel consists of two core exit thermocouples.