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Sequoya Retake Initial Exam 2011-301 Draft Sim/In-Plant JPMs
	ML112160582
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Site:	Sequoyah
Issue date:	06/03/2011
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SRO JPM A.1.a Page 1 of 10 Rev. 0 SEQUOYAH NUCLEAR PLANT SRO ADMIN A.1.a Calculate Subcooling Margin

SRO JPM A.1.a Page 2 of 10 Rev. 0 SRO JOB PERFORMANCE MEASURE Task: Calculate Subcooling with no Subcooling Monitors and NO Plant computers available.

Task#: 3440100302 Task Standard: Exam inee calculates RCS subcooling of 49 degrees based on initial conditions and determines SI Termination is permissible.

Time Critical Task: YES: NO: X KIA Reference!Ratings: 2.1.45 (4.3)

Method of Testing:

Simulated Performance: Actual Performance: X Evaluation Method:

Simulator In-Plant Classroom X Main Control Room Mock-up Performer:

Trainee Name Evaluator: /

Name I Signature DATE Performance Rating: SAT: UNSAT:

Validation Time: 14 mm Total Time:

Performance Time: Start Time: Finish Time:

COMMENTS

SRO JPM A.1.a Page 3 of 10 Rev. 0 SPECIAL INSTRUCTIONS TO EVALUATOR:

1. Critical steps are identified in step SAT/UNSAT column by bold print Critical Step.

2. Any UNSAT requires comments.

ToolslEquipmentlProcedures Needed:

1. Calculator

2. 2-68-PIP-004 Saturation Table

3. AOP-C.04 SHUTDOWN FROM AUXILIARY CONTROL ROOM

References:

Reference Title Rev No.

1 AOP-C04 SHUTDOWN FROM AUXILIARY CONTROL 25 ROOM Read to the examinee:

DIRECTIONS TO TRAINEE:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM. I will provide initiating cues and reports on other actions when directed by you.

When you complete the task successfully, the objective for this job performance measure will be satisfied. Ensure you indicate to me when you understand your assigned task. To indicate that you have completed your assigned task return the handout sheet I provided you.

HAND JPM BRIEFING SHEET TO EXAMINEE AT THIS TIME!

INITIAL CONDITIONS:

1. Unit2isinMODE3

2. RCS Loop 1 Th is 540 Loop 2 Th is 545, Loop 3 Th is 560 and Loop 4 Th is 565.

3. RCS Pressure is 1700 psig

4. An event has occurred requiring Control Room Abandonment.

5. A valid SI signal has occurred.

6. AOP-C.04 SHUTDOWN FROM AUXILIARY CONTROL ROOM is in progress at step 26 RNO.

SROJPMA.1.a Page 4 of 10 Rev. 0

[NITIATIF4G CUES:

1. You are to calculate RCS subcooling using AOP-C.04 SHUTDOWN FROM AUXILIARY CONTROL ROOM Appendix F and the provided saturation table.

2. When you have calculated RCS subcooling, then determine if SI flow is required based on subcooling.

3. Inform the evaluator when you are complete.

SRO JPM A.1.a Page 5 of 10 Rev. 0 Start Time Obtain a copy of 2-68-PIP-004 Saturation Table and AOP-C.04 STEP 1 : SHUTDOWN FROM AUXILIARY CONTROL ROOM SAT UNSAT Exam inee obtains a copy of 2-68-P IP-004 Saturation Table and AOP Standard C.04 SHUTDOWN FROM AUXILIARY CONTROL ROOM Appendix F.

Provide a copy of 2-68-PIP-004 Saturation Table and AOP-C.04 Cue SHUTDOWN FROM AUXILIARY CONTROL ROOM Appendix F to the examinee.

Comment Procedure NOTE I Conditions (such as an unisotable LOCA) which require maintaining Note ECCS flow are outside the scope of this procedure.

Procedure NOTE 2 Arc flash protection requirements are waived m this procedure..

Note 1 IDENTIFY applicable unit:

STEP 2 : SAT

. Unit I U N SAT

Unit2____

Examinee records Unit 2 as the applicable unit based on information Standard provided in the initiating cue.

Comment

SRO JPM A.1.a Page 6 of 10 Rev. 0

2. IF terminating spurious S during Appendix R fire event STEP 3 . THEN SAT GO TO Note prior to Step 5.

U N SAT Examinee determines step is N/A based on information provided in the Standard initiating cue.

Comment

3. DETERMINE RCS subcooling:

STEP 4 : SAT

a. RECORD RCS pressure. [L-10] S9 UNSAT Examinee records RCS pressure of 1700 based on information provided Critical Step Standard:

in the initiating cue.

Comment Examiner This step is critical because the correct answer will be calculated only Note if the information placed into the calculation is correct.

SRO JPM A.1.a Page 7 of 10 Rev. 0

3. DETERMINE RCS subcooling:

STEP 5 : SAT

b. DETERMINE saturaton temperature for current RCS pressure UNSAT U SING posted saturation table. [L-I 0]

F Examinee determines the saturation temperature of 614 based on Critical Step Standard information provided in 2-68-PIPOO4 Saturation Table.

Comment Examiner This step is critical because the correct answer will be calculated only Note if the information placed into the calculation is correct.

3. DETERMINE RCS subcooling:

STEP 6 : SAT

c RECORD highest RCS 7-hot. [L-1D]

UNSAT Examinee records RCS the highest RCS Thot of 565 based on Critical Step Standard information provided in the initiating cue, Comment Examiner This step is critical because the correct answer will be calculated only Note if the information placed into the calculation is correct.

SRO JPM A.1.a Page 8 of 10 Rev. 0

3. DETERMINE RCS sirhcoohng:

STEP 7 : SAT

d. CALCULATE subcooling:

UNSAT

= Critical Step sat temp T-hot subcooling Standard: The exarninee calculates a subcooling value of 49 Comment Examiner This step is critical because SI flow cannot be terminated until RCS Note subcooling is calculated at a value of greater than 40 deg.

STEP 8 : 4. MONITOR SI flow NOT required:

SAT

. RCS subcooling (step 3) greater than 40°F.

UNSAT Critical Step Standard Exarninee determines SI flow is NOT required based on RCS subcooling calculated is greater than 40°F.

Comment Examiner This step is critical because SI flow cannot be terminated until RCS Note subcooling is calculated at a value of greater than 40 deg.

When the examinee determines that RCS subcooling is greater Terminating than the SI flow termination requirement, provide the following Cue: cue, Another Operator will complete the remaining steps of this STOP procedure.

Stop Time

SRO JPM A.1.a S

Page9oflo Rev. 0 JPM BRIEFING SHEET The examiner will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this job performance measure will be satisfied.

INITIAL CONDITIONS:

1. Unit2isinMODE3

2. RCS Loop 1 Th is 540 Loop 2 Th is 545, Loop 3 Th is 560 and Loop 4 Th is 565.

3. RCS Pressure is 1700 psig

4. An event has occurred requiring Control Room Abandonment.

5. A valid SI signal has occurred.

6. AOP-C.04 SHUTDOWN FROM AUXILIARY CONTROL ROOM is in progress at step 26 RNO.

INITIATING CUES:

1. You are to calculate RCS subcooling using AOP-C.04 SHUTDOWN FROM AUXILIARY CONTROL ROOM Appendix F and the provided saturation table.

2. When you have calculated RCS subcooling, then determine if SI flow is required based on subcooling.

3. Inform the evaluator when you are complete.

Acknowledge to the examiner when you are ready to begin.

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

SRO JPM A.1.a Page 10 of 10 Rev. 0

/

{Tempcratufl Rowjded to Nearest 19 300 4i ..: USC 5 534 ucla S3J. 533 400 .L; f)9J 43iQ 53 54)

SQN SHUTDOWN FROM AUXILIARY CONTROL ROOM AOP.C.04 Rev. 25 Page 1 of 2 APPENDIX F STOPPING ECCS PUMPS FOLLOWING SI ACTUATION NOTE I Conditions (such as an unisolable LOCA) which require maintaining ECOS flow are outside the scope of this procedure.

NOTE 2 Arc flash protection requirements are waived in this procedure.

1. IDENTIFY applicable unit:

Uniti

Unit2

2. IF terminating spurious SI during Appendix R fire event, THEN GO TO Note prior to Step 5.

3. DETERMINE RCS subcooling:

a. RECORD RCS pressure. [L-1O] psig El

b. DETERMINE saturation temperature for current RCS pressure USING posted saturation table. [L-1O]

c. RECORD highest RCS T-hot. [L-1O) El

°F

d. CALCULATE subcooling:

sat temp T-hot subcooling Page 132 of 193

SQN SHUTDOWN FROM AUXILIARY CONTROL ROOM Rev. 25 Page 2 of 2 APPENDIX F

4. MONITOR SI flow NOT required:

RCS subcooHng (step 3) greater than 40°F. El

RCS pressure stable or rising. [L-10j El

Narrow range level in at least one SIG greater than 10%

OR total AFW flow greater than 440 gpm.

pressurizer level greater than 10%. [L-10J NOTE Checklist 5 (Unit 1) and 6 (Unit 2) require closing CCPIT valves within 13 minutes to ensure adequate RCP seal injection flow and to prevent pzr overfill.

5. IF both COPs RUNNING (A-A and B-B),

THEN STOP one COP. [6.9 KV Shutdown Bd A-A or B-B Compt 18] El

6. STOP SI pumps. [6.9 KV Shutdown Bd A-A and B-B Compt 15]

7. STOP RHR pumps NOT running for shutdown cooling.

[6.9 KV Shutdown Bd A-A and B-B Compt 14]

8. WHEN appendix completed on affected unit, THEN NOTIFY ACR ( x6359 or x6170).

END OF TEXT Page 133 of 193

JPM Admin A-i .b Page 1 of 14 Rev. 0 SEQUOYAH NUCLEAR PLANT SRO ADMIN A.ib Review and Evaluate Shift Daily Surveillance Log Mode One

JPM Admin A-i .b Page 2 of 14 Rev. 0 SRO JOB PERFORMANCE MEASURE Task: Review and Evaluate Shift Daily Surveillance Log Mode One Task #: SRO 1190070301 Analyze operating loop for trends and out of specification conditions Task Standard: Correctly review data on Appendix A to determine whether or not the surveillance meets acceptable criteria.

Time Critical Task: YES: NO: X KIA ReferencelRatings: 2.1.18 (3.6/3.8)

Method of Testing:

Simulated Performance: Actual Performance: X Evaluation Method:

Simulator In-Plant Classroom X Main Control Room Mock-up Performer:

Trainee Name Evaluator: /

Name I Signature DATE Performance Rating: SAT: UNSAT:

Validation Time: 19 minutes Total Time:

Performance Time: Start Time: Finish Time:

COMMENTS

JPM Admin A-i .b Page 3 of 14 Rev. 0 SPECIAL INTRUCTIONS TO EVALUATOR:

1. Critical steps are identified in step SATIUNSAT column by bold print Critical Step.

2. Any UNSAT requires comments.

ToolslEquipmentIProcedures Needed:

1. i-Sl-OPS-000-002.0, Shift Log, Appendix A

2. Technical Specifications, Unit 1

3. Chronological Test Log

References:

Reference Title Rev No.

1. 1-Sl-OPS-000-002.O Shift Log, Appendix A 96

2. Unit 1 Technical Specifications Read to the examinee:

DIRECTIONS TO TRAINEE:

I will explain the initial conditions, and state the administrative task to be performed. I will provide initiating cues and reports on other actions when directed by you. When you complete the task successfully, the objective for this job performance measure will be satisfied. Ensure you indicate to me when you understand your assigned task. To indicate that you have completed your assigned task return the handout sheet I provided you.

HAND JPM BRIEFING SHEET TO EXAMINEE AT THIS TIME!

INITIAL CONDITIONS:

1. Unit 1 has been operating at 100% rated thermal power and has been stable for the last 30 days. No LCO entries at this time.

2. Portions of the field data have been entered by ROs and AUOs.

3. Data takers are present.

4. You are the Unit Supervisor and the Shift Manager has assigned you to review only the data that is currently logged on 1 -SI-OPS-000-002.0, Shift Log, Appendix A for the 0630-1830 shift for discrepancies and take appropriate action(s) if any, once the review is complete.

INITIATING CUES:

1. The Shift Manager directs you to review the data logged on the sections of Appendix A. (Another SRO will review the rest of the SI-2 data)

2. When you have finished reviewing the assigned pages of Appendix A, Identify and address any deviations on the Chronological Test Log.

3. Notify the Shift Manager when you have completed your task.

JPM Admin A-i .b Page 4 of 14 Rev. 0 Start Time Obtain a copy of i-SI-OPS-000-002.0, Shift Log, Appendix A and a STEP 1 : Chronological Test Log SAT UNSAT Standard: Copy of 1-SI-OPS-000-002.0, Shift Log, Appendix A and a Chronological Test Log have been obtained.

Provide a copy of a marked up Appendix A and a Chronological Test Log Cue

JPM Admin A-i .b Page 5 of 14 Rev. 0 Reviews data for CST A and CST B Level STEP 2 SAT U N SAT Applicant reviews readings for CST Level 0-Ll-2-230A and 0-LI 233A recorded on the data sheet, determines that the values meets T.S. limit of 240,000 gallons.

Standard:

>240,000 gals 0-Ll-2-230A gals 300,000 Operable 0-Ll-2-233A Gals 320,000 Corn rn ent

JPM Admin A-I .b Page 6 of 14 Rev. 0 Reviews data in SG Level data table, check Operable, Channel Check, STEP 3 : and MCD < 6.0%. SAT UNSAT Applicant reviews current readings for SG level on the data sheet and determines Critical Step that SG 2 Level channel 2-Ll-3-52 is not within MCD of <6.0%. The candidate will identify the associated Tech Spec LCO Action and write them on the (Shaded Chronological Test Log. portions Tech Specs: critical) 3.3.1.1,Action9 3.3.2.1ActionI7 3.3.2.1, Action 36 3.3.3.7, Action I Operable #1 LI-3-42 % 44 Operable #1 LT-3-39 % 42 Standard: Operable #1 LI-3-38 % 45 Operable #2 Ll-3-55 % 46 SG Water Level Operable #2 Ll-3-52 % 38

, Operable #2 LI-3-51 % 42 Operable #3 Ll-3-97 % 44 Operable #3 LI-3-94 % 44 Operable #3 LI-3-93 % 45 Operable #4 LI-3-1 10 % 46 Operable #4 Ll-3-107 % 44 Operable #4 Ll-3-106 % 42 Examiner If asked: Respond as the RO who took the data that the MCB still Note: indicates as transcribed onto the data sheet.

If asked to review previous shifts Sl-2 data, inform the candidate Examiner that all previous data on this instrumentation was within MCD prior oe.

totoday.

Examiner If asked the color of the placard for 2-Ll-3-52 (to deduce if it is a Note: PAMS instrument), respond that it is a black placard.

Comment

JPM Admin A-i .b Page 7 of 14 Rev. 0 Reviews data in SG Pressure data table, check Operable, Channel STEP 4 : Check, and MCD <60 psig. SAT UNSAT Applicant reviews readings for SG Pressure on the data sheet, determines that the channels are operable, channel checked and MCD is within < 60 psig.

Operable #1 Pl-1-2A psig 865 Operable #1 Pl-1-2B psig 860 Operable #1 P1-1-5 psig 860 Operable #2 Pl-1-9A psig 860 Steam Line Operable #2 Pl-1-9B psig 860 Standard:

Pressure Operable #2 P1-i -12 psig 870 Operable #3 P1-i -20A psig 870 Operable #3 Pl-l-20B psig 860 Operable #3 P1-i -23 psig 870 Operable #4 PI-i-27A psig 870 Operable #4 PI-l-27B psig 850 Operable #4 P1-1-30 psig 860 Comment

JPM Admin A-i .b Page 8 of 14 Rev. 0 STEP Reviews data in Shutdown Banks data table, check Operable and Rod 5 SAT Position Indication agree within < 12 steps U N SAT Applicant reviews readings for Shutdown Banks on the data sheet, determines that the RPIs are operable and RPIs are within < 12 steps.

COLR Gr 1 Step steps 228 A **

Gr 1 RPIs steps 230 COLR Gr 2 Step steps 228 i

Gr 2 RPIs steps 225 Shutdown COLR Gr 1 Step steps 228 Standard: Banks B **

Gr 1 RPIs steps 224 COLR Gr2 Step steps 228 Gr 2 RPls steps 224 COLR Gr Step steps 228 C **

GrRPIs steps 224 COLR Gr Step steps 228 D **

GrRPIs steps 226 Comment

JPM Admin A-i .b Page 9 of 14 Rev. 0 Reviews data in Control Banks A & B data table (page 6),check STEP 6 SAT Operable, and Rod Position Indication agree within < 12 steps UNSAT Applicant reviews readings for Control Banks A & B on the data sheet, determines that the RPls are operable and RPIs are within < 12 steps.

COLR Gr 1 Step steps 228 figure 1 A Gr 1 RPIs steps 225 COLR Gr 2 Step steps 228 Standard: Control Rod figure 1 Banks **

Gr2 RPIs steps 225 COLR Gr 1 Step steps 228 figure 1 B Gr I RPls steps 226 COLR Gr 2 Step steps 228 figure 1 Gr2 RPfs steps 225 Comment

JPM Admin A-i .b Page 10 of 14 Rev. 0 STEP Reviews data in Control Banks C & D data table (page 7),check 7 SAT

Operable, and Rod Position Indication agree within < 12 steps UNSAT Applicant reviews readings for Control Banks C & D on the data sheet, determines that the RPIs are operable and RPIs are within 12 steps.

COLR Gr 1 Step steps 228 figure 1 c

Gri RPls steps 225 COLR Gr 2 Step steps 228 Standard: Control Rod figure 1 Banks **

Gr 2 RPls steps 225 COLR Gr 1 Step steps 220 figure 1 ID Gr 1 RPls steps 222 COLR Gr 2 Step steps 220 figure 1 Gr2 RPls steps 225 Comment

JPM Admin A-i .b Page ii of 14 Rev. 0 STEP Reviews data in ECCS Subsystem (page 13), checks TS limit Valve 8 : SAT Open.

UNSAT Applicant reviews data for ECCS subsystem on the data sheet, determines that the indicating lights for 1-HS-63-1A and i-HS-63-22A indicate that the valves are OPEN (check mark in box), Red lights On/Green lights Off.

Standard:

rECCS Valve Open 1-HS-63-IA 1 Subsystem Valve Open 1-HS-63-22A J Evaluators If asked by applicant for the current indications for 1-HS-63-IA Note andlor I -HS-63-22A on I -M-6, respond that the Red lights are lit.

Comment

JPM Admin A-i .b Page 12 of 14 Rev. 0 STEP Reviews data in RWST Level and CNTMT Level for Auto Swapover Cold 9 SAT

Leg during SI (page 13) data block, checks Operable, Channel Check,:

and MCD <5% for RWST level and MCD <6% for CNTMT sump level.

UNSAT Applicant reviews data for RWST Level and CNTMT Level on the data sheet, determines that the MCD of < 5% for RWST level has been exceeded due to 1- Critical Step Ll-63-52 at9i The..candidate will identify the associated Tech Spec LCO Action (Shaded and write them on the Chronological Test Log. Applicant also determines that portions indicated level on 1-Ll-63-178 does not exceed MCD and is acceptable even if no critical) level is present (Note 40).

Tech Spec:

3.3.2.1 Action 18 R Operable 1-Ll-63-50 % 99 Standard:

W 1-Ll-63-51 % 98 RWST Level S 0 and CNTMT iLI352 /0 91 Level for Auto T 1 -Ll-63-53 0/

97 Swapover Cold Leg during SI C Operable 1-Ll-63-176 % 0 T

N 1-Ll-63-177 % 0 1-Ll-63-178 % 2 1-LI-63-179 % 0 Evaluators If asked by applicant for the current indications for RWST level, Note respond that the indications are as listed in the table.

Evaluators If asked by applicant for the current indications for Containment Note Sump level, respond that the indications are as listed in the table.

EXAMINER If asked the color of the placard for 1-Ll-63-52 (to deduce if it is a NOTE: PAMS instrument), respond that it is a white placard.

Comment

JPM Admin A-i .b Page 13 of 14 Rev. 0 Terminating When the examinee determines acceptance criteria is NOT met, Cue: provide the following cue, Another Operator will complete the remaining steps of this procedure.

I STOP Stop Time

JPM Admin A-i .b Page 14 of 14 Rev. 0 JPM BRIEFING SHEET DIRECTIONS TO TRAINEE:

The examiner will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this job performance measure will be satisfied.

INITIAL CONDITIONS:

1. Unit 1 has been operating at 100% rated thermal power and has been stable for the last 30 days. No LCO entries at this time.

2. Portions of the field data have been entered by ROs and AUOs.

3. Data takers are present.

4. You are the Unit Supervisor and the Shift Manager has assigned you to review only the data that is currently logged on 1-SI-OPS-000-002.0, Shift Log, Appendix A for the 0630-1830 shift for discrepancies and take appropriate action(s) if any, once the review is complete.

INITIATING CUES:

1. The Shift Manager directs you to review the data logged on the sections of Appendix A. (Another SRO will review the rest of the Sl-2 data)

2. When you have finished reviewing the assigned pages of Appendix A, Identify and address any deviations on the Chronological Test Log.

3. Notify the Shift Manager when you have completed your task.

Acknowledge to the examiner when you are ready to begin.

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

SQN 1-SI-OPS-000-OOZO

. SHIFT LOG Rev. 96 I Pagel2of68 APPENDIX A Page 2 of 27 Surveillance Ref. Mode Notes TS Limits Instrument No. Units 0630-1830 1830-0630 REMARKS SFP Area and Fuel Pool All 1116 Operable 0-RM-90-102 mR/hr Rad Monitors 4.3.3.1 .A. l.a 0-RM-90-1 03 mR/h Condensate > 240000 Gal StorageTank 4.7.1.3.1 123,4 3,15 Operable 0-Ll-2-230A gals Level 0-Ll-2-233A gals oC)

UO/RO Review Initials NOTES:

3. Applicable at all times during modes 1, 2, & 3. Applicable during mode 4, only when steam generator is relied upon for heat removal.

11. General Notes: In the event a radiation monitor listed in this Instruction becomes inoperable, the monitor is to be listed on Attachment 1. NOTIFY the SRO to consult Tech Specs for appropriate actions for inoperable monitors. Any questionable monitor may be source checked in accordance with 1-SO-90-2 for Unit 1 monitors and 0-SO-90-2 for Unit 0 monitors to aid in determining operability.

15. LOG the water level indicated on Ll-2-230A for CST A and LI-2-233A for CST B. Operability is determined by having equal to or greater than 240,000 gallons, in the CST aligned to the unit. Either A or B CST may be aligned to the operable unit. IF inoperable THEN REFER to 0-SI-OPS-067-1 17.0.

16. VERIFY the Fuel Pool Radiation Monitors are operable by observing power is on, instrument malfunction alarms clear, and readings of at least background on ratemeter. COMPARE radiation levels to opposite train monitor and to levels from the previous shift using either the lOS computer or ratemeter readings. Radiation Protection Area surveys are required when RM-90-102 and RM-90-103 are inoperable with fuel in the storage pool, and the survey results are recorded on Attachment 1.

SON I -S[-OPS-000-002.O SHIFT LOG Rev. 96 I Pagel3of68 APPENDIX A Page 3 of 27 Surveillance Ref. Mode Notes TS Limits Instrument No. Units 0630-1830 1830-0630 REMARKS OPERABLE #1 LI-3-42 OPERABLE #1 LI-3-39 %

OPERABLE #1 Ll-3-38 °° SO Water 4.3.1.1.1.A.14.A OPERABLE #2 Ll-3-55

°° Level 4.3.1.1.1.A.14.B OPERABLE #2 Ll-352 3.

Channel 4.3.2.1.1 .A.5.a 12,3 17 OPERABLE #2 Ll-3-51 U Deviation 4,3.2.1.1 .A.6.c.1 OPERABLE #3 L[-397 °° 43.2.1 .1 .A.6.c.2 OPERABLE #3 LI-3-94 ° OPERABLE #3 Ll-3-93 £_______

OPERABLE #4 LI3-11O ° OPERABLE #4 Ll-3-107 OPERABLE #4 Ll-3-106 °° UO/RO Review Initials NOTES:

17. COMPARE the three Steam Generator Level indicators for each SIG located on panel 1-M-4 to each other. Operability is verified by an acceptable deviation between channels of equal to or less than 6%.

SQN 1-SI-OPS-OOO.-OO2O SHIFT LOG Rev. 96 I Pagel4of68 APPENDIX A Page 4 of 27 Surveillance Ref. Mode Notes TS Limits Instrument No. Units 0630-1830 1830-0630 REMARKS OPERABLE 1 P-1-2A PSIG OPERABLE #1 PI-1-2B PSIG O OPERABLE #1 P1-1-5 PSIG 4.3.2.1.1.A.1.f OPERABLE #2 Pl-1-9A PSIG Steam Line 4.3.2.1.1 .A.4.d OPERABLE #2 Pl-1-9B PSIG Pressure 4.3.2.1.1 .A.4.e 12,3 18 OPERABLE #2 P1-1-12 PSIG 4.3.2.1.1 ,A.6.d OPERABLE #3 Pl-1-20A PSIG OPERABLE #3 Pl-1-20B PSIG iC OPERABLE #3 P1-1-23 PSIG ,o OPERABLE #4 Pl-1-27A PSIG OPERABLE #4 P1-1-278 PSIG OPERABLE #4 P1-1-30 PSIG UO/RO Review nitiaIs NOTES:

18. COMPARE the three steam line pressure indicators for each steam line, located on panel 1-M-4 to each other. Operability is verified by an acceptable deviation between channels of equal to or less than 60 psig.

SON I -SI-OPS-000-002.O SHIFT LOG Rev. 96 I Pagel5of68 APPENDIX A Page 5 of 27 Surveillance Ref. Bank Mode Notes TS Limits Instrument No. Units 0630-1830 1830-0630 REMARKS 1,2 192122 COLR Gr 1 Step Steps A 1,2 20 **

Gr 1 RPIs Steps 3 C) 1,2 19,21,22 COLR Gr2 Step Steps 1,2 20 **

Gr2 RPls Steos Shutdown 4.1.3.1.1 1,2 19,2122 COLR Gr 1 Step Steps -

Banks 4.13.2 B 1,2 20 **

Or 1 RPIs Steps aQ 4.1 3.5.b 1,2 19,21,22 COLR Gr2 Step Steps 1,2 20 **

Gr 2 RPls Steps 2 2. H 1,2 19,2122 COLR Or Step Steps ,2:).

1,2 20 **

Or RPIs Steps 2 0 1,2 19,21,22 COLR Gr Step Steps 1,2 20 **

Or RPIs Steps

- Wthin +/- 12 steps of step counter.

UO/RO Review Initials NOTES:

19. COMPARE each full length rod position indicator (RPI) to its associated group demand position indicator AND VERIFY correct rod position by each RPI within +/- 12 steps of the indicated group demand.

COMPARE each group of RPls to the associated group demand position indicator AND VERIFY the rod position indication system and the rod position demand indication system are operating and agree within +/- 12 steps. RECORD steps in the applicable column of the data sheet.

20. With Keff equal to or greater than 0.99.

21. REFER to COLR Figure 1 for fully withdrawn position range of rod banks. Tl-28, Attachment 6, provides the desired position within this range.

22. WHEN the rod position deviation monitor is inoperable OR WHEN the rod insertion limit monitor is inoperable VERIFY rod position once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and LOG on the data sheet. (Reference LCD 3.1.3.2> WHEN a maximum of one demand position indicator per bank is inoperable, THEN VERIFY that all RPIs for the affected bank are operable and that the most withdrawn rod and the least withdrawn rod of the bank are within a maximum of 12 steps of each other, once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . (Reference LCD 3i.3.2.c.1)

SQN 1-Sl-OPS-000-002.O SHIFT LOG I Rev. 96 i j jPae16of68 APPENDiX A Page 6 of 27 SurveiHance Ref. Bank Mode Notes TS Limits Instrument No. Units 0630-1 830 1830-0630 REMARKS 19,2122 1,2 Fure1 Gr 1 Step Steps 20 **

Gri RPIS Steps 1,2

.2 Control 41.3.1.1 A 192122 COLR 1,2 Gr2 Step Steps Rod 4.1.3.2 Figure 1 Banks 4.1.3.6 1,2 20 ** Gr2 RPIs Steps 4.1.1.1.1.b 19,21,22 COLR 1,2 Gr 1 Step Steps Figure 1 1,2 20

- Grl RPls Steps B 19.21,22. COLR 1,2 Gr 2 Step Steps Figure 1 1,2 20 ** Gr 2 RPIs Steps

- Within 12 steps of step counter. UG/RO Review Initials NOTES:

19. COMPARE each full length rod position indicator (RPI) to its associated group demand position indicator AND VERIFY correct rod position by each RPI within +/- 12 steps of the indicated group demand. COMPARE each group of RPIs to the associated group demand position indicator AND VERIFY the rod position indication system and the rod position demand indication system are operating and agree within

+/- 12 steps, THEN RECORD steps in the applicable column of the data sheet.

20. With Keff equal to or greater than 0.99.

21. REFER to COLR Figure 1 for fully withdrawn position range of rod banks. Tl-28, Attachment 6, provides the desired position within this range.

22, WHEN the rod position deviation monitor is inoperable OR WHEN the rod insertion limit monitor is inoperable VERIFY rod position once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and LOG on the data sheet. (Reference LCO 3.1.3.2) WHEN a maximum of one demand position indicator per bank is inoperable, THEN VERIFY that all RPIs for the affected bank are operable and that the most withdrawn rod and the least withdrawn rod of the bank are within a maximum of 12 steps of each other, once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . (Reference LCO 3.1.3.2.c.1)

SQN I -Sl-OPS-000-002.O SHIFT LOG Rev. 96 I

[

APPENDIX A Page 7 of 27 Surveillance Ref. Bank Mode Notes TS Limits Instrument No. Units 0630-1830 1830-0630 REMARKS F 1 ,2 19,21,22,23, 66 COLR Figure 1 Gr 1 Step Steps C

1,2 20

- Gr 1 RPIs Steps Control 4.1.3.1.1 19,2122,23, COLR 12 Gr 2 Step Steps Rod 4.1.3.2 66 Figure 1 Banks 4.1.3.6 1,2 20 ** Gr2 RPIS Steps 4.1.1,1.1 .b 19,21,22,23, COLR 1,2 Gr 1 Step Steps 66 Figure 1 D 1,2 20 ** Gr 1 RPIs Steps 19,21,22,23, COLR 1,2 Gr2Step Steps 66 Figure 1 1,2 20 ** Gr2RPIs Steps .2.2

- Wthin +/- 12 steps of step counter. UO/RO Review Initials NOTES:

19. COMPARE each full length rod position indicator (RPI) to its associated group demand position indicator AND VERIFY correct rod position by each RPI within +/- 12 steps of the indicated group demand. COMPARE each group of RPls to the associated group demand position indicator AND VERIFY the rod position indication system and the rod position demand indication system are operating and agree within

+/- 12 steps, THEN RECORD steps in the applicable column of the data sheet.

20. With Keff equal to or greater than 0.99.

21. REFER to COLR Figure 1 for fully withdrawn position range of rod banks. Tl-28, Att. 6, provides the desired position within this range.

22. WHEN the rod position deviation monitor is inoperable OR WHEN the rod insertion limit monitor is inoperable VERIFY rod position once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and LOG on the data sheet. (Reference LCO 3.1.3.2>

WHEN a maximum of one demand position indicator per bank is inoperable, THEN VERIFY that all RPIs for the affected bank are operable and that the most withdrawn rod and the least withdrawn rod of the bank are within a maximum of 12 steps of each other, once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

(Reference LCO 3.1.3.2.c.1)

23. IF manual rod motion occurs during SI performance, THEN allowing one-half hour for thermal soak may provide a more accurate RPI reading.

66. MMNTAIN rods above insertion limits as shown by COLR Figure 1. IF LEFM calorimetric power indication (U2118) is inoperable, then rod insertion limit lines in COLR must be raised by 3 steps withdrawn until LEFM is restored.

SQN I ..Sl-OPS-000-002.O SHIFT LOG Rev. 96 I Page23of68 APPENDIX A Page 13 of 27 Surveillance Ref. Mode Notes TS Limits Instrument No. Units 0630-1830 1830-0630 REMARKS ECCS Subsystem 4.5.2.a 1,2,3 38 Valve Open 1-HS-63-1A () i.

R 68 1-HS-63-22A 1 (>

I -Ll-63-50 % 9 RWST Level W 1-Ll-63-51 9 and CNTMT S 1,2.3,4 39 Operable 1-Ll-63-52 q Level for Auto T 1-Ll-63-53 ..

Swapover 43.2.1.1.A.9.a C 1-Ll-63-176 Cold Leg T 1-Ll-63-177 during SI N 1,2,3,4 40 Operable 1-Ll-63-178 2 1-Ll-63-179 % o Cold Leg (1) 1-HS-63-118A Accumulator Valves Fully 1 -HS-63-98A Isolation 4.511.1.a.2 1,2,3 41 Open 1-HS-63-80A Valves 1-HS-63-67A ()

UO/RO Review Initials NOTES:

38. VERIFY by use of the indicating lights on panel 1 -M-6 that these valves are open. Verification of power disconnected will be accomplished later in this Instruction.

39. COMPARE the four RWST level indicators to each other. Acceptable deviation between channels is equal to or less than 5%. If control room indication is lost, refer to GOI-6 for alternative means of obtaining RWST level.

40. COMPARE the four containment sump level indicators to each other. Acceptable deviation between channels is equal to or less than 6%.

With no water in the sump, no indicator should read more than 4%.

41. WHEN pressurizer pressure is above 1000 psig, THEN VERIFY each of the four cold leg accumulator isolation valves on panel 1-M-6 are open by observation of the position indicating lights.

68. When entering Mode 3 from Mode 4, FCV-63-22 may be closed to support transition from LCO 3.4,12 for up to 4 hrs. or until the temperature of all RCS cold legs exceeds 375°F (whichever comes first).

CHRONOLOGICAL TEST LOG tCTL)

Data Package Page of Procedure No. Rev.

1

/

3 Date Time Narrative Initials Log entries have been reviewed and items are appropriately addressed.

Test Director 2 Date t

Use 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months clock for each entry.

Test Director signature only required on last sheet of CTL. The other review blanks can be marked N/A.

2 The Date column needs to be filled in for the first entry on the CTL and for the first entry after each date change.

WA 40681 [07-201 01 Page 1 of 1 NPG-SPP-06.9.1-2 [07-09-2010]

3/4.3 INSTRUMENTATION 3/4.3.1 REACTOR TRIP SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.1.1 As a minimum, the reactor trip system instrumentation channels and interlocks of Table 3.3-1 shall be OPERABLE.

APPLICABILITY: As shown in Table 3.3-1.

ACTION:

As shown in Table 3.3-1.

SURVEILLANCE REQUIREMENTS 4.3.1.1.1 Each reactor trip system instrumentation channel and interlock shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations for the MODES and at the frequencies shown in Table 4.3-1.

4.3.1.1.2 The logic for the interlocks shall be demonstrated OPERABLE prior to each reactor startup unless performed during the preceeding 92 days. The total interlock function shall be demonstrated OPERABLE at least once per 18 months during CHANNEL CALIBRATION testing of each channel affected by interlock operation.

4.3.1.1.3 The REACTOR TRIP SYSTEM RESPONSE TIME of each reactor trip function shall be verified to be within its limit at least once per 18 months. Neutron detectors are exempt from response time testing. Each verification shall include at least one train such that both trains are verified at least once per 36 months and one channel per function such that all channels are verified at least once every N times 18 months where N is the total number of redundant channels in a specific reactor trip function as shown in the Total No. of Channels column of Table 3.3.1.

February 29, 2000 SEQUOYAH - UNIT 1 3/4 3-1 Amendment Nos. 12, 190, 251

TABLE 3.3-1 REACTOR TRIP SYSTEM INSTRUMENTATION TOTAL NO. MINIMUM OF CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT CHANNELS TO TRIP OPERABLE MODES ACTION

1. Manual Reactor Trip 2 1 2 1,2,and* 1

2. Power Range, Neutron Flux 4 2 3 1,2 2

3. Power Range, Neutron Flux 4 2 3 1,2 2 High Positive Rate

4. Power Range, Neutron Flux, High Negative Rate 4 2 3 1,2 2 I

5. Intermediate Range, 2 1 2 1,2,and* 3 Neutron Flux

6. Source Range, Neutron Flux A. Startup 2 1 2 2,and* 4 B. Shutdown 2 0 1 3,4and5 5

7. Overtemperature AT Four Loop Operation 4 2 3 1,2 6 I

8. Overpower AT Four Loop 4 2 3 1,2 6 I Operation

9. Pressurizer Pressure-Low 4 2 3 1,2 6 I

10. Pressurizer PressureHigh 4 2 3 1,2 6 I

11. Pressurizer Water Level High 3 2 2 1,2 6 I April 11,2005 SEQUOYAH UNIT 1

- 3/4 3-2 Amendment Nos. 41, 141, 301

TABLE3. 3-1 (Continued)

REACTOR TRIP SYSTEM INSTRUMENTATION TOTAL NO. MINIMUM OF CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT CHANNELS TO TRIP OPERABLE MODES ACTION

12. Loss of Flow Single Loop

- 3/loop 2/loop in 2/loop in 1 6 (Above P-8) any each operating operating loop loop

13. Loss of Flow Two Loops

- 3/loop 2/loop in two 2/loop in 1 6 (Above P-7 and below P-8) operating each loops operating loop

14. Main Steam Generator Water Level--Low-Low A. Steam Generator Water 3/Stm. Gen. 2/Stm. Gen. 2/Stm. Gen. 1,2 9 Level--Low-Low in any in each (Adverse) operating Operating Stm.Gen Stm.Gen.

B. Steam Generator Water 3/Stm. Gen. 2/Stm. Gen. 2/Stm. Gen. 1,2 9 Level--Low-Low (EAM) in any in each operating operating Stm.Gen. Stm.Gen.

C. RCS Loop AT 4(1/loop) 2 3 1,2 10 D. Containment Pressure 4 2 3 1,2 11 (EAM)

15. Deleted

16. Undervoltage-Reactor Coolant 4-1/bus 2 3 1 6 Pumps

17. Underfrequency-Reactor 4-1/bus 2 3 1 6 Coolant Pumps

18. Turbine Trip A. LowFluidOil 3 2 2 6 Pressure B. Turbine Stop Valve 4 4 4 1 7 Closure September 2, 2005 SEQUOYAH - UNIT 1 3/4 3-3 Amendment No. 141, 301, 304

TABLE 3.3-1 (Continued)

REACTOR TRIP SYSTEM INSTRUMENTATION TOTAL NO. MINIMUM OF CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT CHANNELS TO TRIP OPERABLE MODES ACTION

19. Safetylnjectionlnputfrom 2 1 2 1,2 12 ESF

20. Reactor Trip Breakers A. Startupand Power 2 1 2 1,2 12,15 Operation B. Shutdown 2 1 2 3*,4* and 5* 16

21. Automatic Trip Logic A. Startup and Power 2 1 2 1, 2 12 Operation B. Shutdown 2 1 2 3*4* and 5* 16

22. Reactor Trip System Interlocks A. Intermediate Range Neutron Flux, P-S 2 1 2 2, and* 8a B. Power Range Neutron 4 2 3 1 8b Flux, P-7 C. Power Range Neutron 4 2 3 1 8c Flux, P-8 D. Power Range Neutron 4 2 3 1, 2 8d Flux, P-10 E. Turbine Impulse Chamber 2 1 2 1 8b Pressure, P-i 3 F. Power Range Neutron 4 2 3 1 8e Flux, P-9 G. Reactor Trip P-4 2 1 2 1,2, and

14 July20, 1987 SEQUOYAH - UNIT 1 3/4 3-4 Amendment No. 54, 56

TABLE 3.3-1 (Continued)

TABLE NOTATION With the reactor trip system breakers in the closed position, the control rod drive system capable of rod withdrawal, and fuel in the reactor vessel.

Above the P-9 (Power Range Neutron Flux) interlock.

Source Range outputs may be disabled above the P-6 (Block of Source Range Reactor Trip) setpoint.

ACTION STATEMENTS ACTION 1 - With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and/or open the reactor trip breakers.

ACTION 2 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and POWER OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b. The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1.

c. The QUADRANT POWER TILT RATIO is monitored in accordance with Technical Specification 3.2.4.

September 2, 2005 SEQUOYAH - UNIT 1 3/43-5 Amendment Nos. 47,135,136,141, 213, 301, 304

TABLE 3.3-1 (Continued)

ACTION 3 - With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement and with the THERMAL POWER level:

a. Below the P-6 (Block of Source Range Reactor Trip) setpoint, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above the P-6 Setpoint.

b. Above the P-6 (Block of Source Range Reactor Trip) setpoint, but below 5% of RATED THERMAL POWER, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above 5% of RATED THERMAL POWER.

c. Above 5% of RATED THERMAL POWER, POWER OPERATION may continue.

d. Above 10% of RATED THERMAL POWER, the provisions of Specification 3.0.3 are not applicable.

ACTION 4 - With the number of OPERABLE channels one less than required by the Minimum Channels OPERABLE requirement and with the THERMAL POWER level:

a. Below the P-6 (Block of Source Range Reactor Trip) setpoint, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above the P-6 Setpoint.

b. Above the P-6 (Block of Source Range Reactor Trip) setpoint, operation may continue.

ACTION 5 - With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement, verify compliance with the SHUTDOWN MARGIN requirements of Specification 3.1.1.1 or 3.1.1.2, as applicable, within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter.

ACTION 6 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b. The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1.

ACTION 7 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or THERMAL POWER is reduced to less than P-9 within 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months .

September 2, 2005 SEQUOYAH - UNIT 1 3/4 3-6 Amendment No. 47, 141, 304

- TABLE 3.3-1 (Continued)

ACTION 8 - With less than the Minimum Number of Channels OPERABLE, declare the interlock inoperable and verify that all affected channels of the functions listed below are OPERABLE or apply the appropriate ACTION statement(s) for those functions.

Functions to be evaluated are:

a. Source Range Reactor Trip

b. Reactor Trip Low Reactor Coolant Loop Flow (2 loops)

Undervoltage Underfrequency Pressurizer Low Pressure Pressurizer High Level

c. Reactor Trip Low Reactor Coolant Loop Flow (1 loop)

d. Reactor Trip Intermediate Range Low Power Range Source Range

e. Reactor Trip Turbine Trip ACTION 9 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b. For the affected protection set, the Trip Time Delay for one affected steam generator (Ts) is adjusted to match the Trip Time Delay for multiple affected steam generators (TM) within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

c. The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1.

ACTION 10 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided that within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , for the affected protection set, the Trip Time Delays (Ts and TM) threshold power level for zero seconds time delay is adjusted to 0% RTP.

May 16, 1990 SEQUOYAH - UNIT 1 3/4 3-7 Amendment No. 54, 141

TABLE 3.3-1 (Continued)

ACTION 11 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided that within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , for the affected protection set, the Steam Generator Water Level -

Low-Low (EAM) channels trip setpoint is adjusted to the same value as Steam Generator Water Level Low-Low (Adverse).

ACTION 12 - With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement, be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; however, one channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per Specification 4.3.1.1.1 provided the other channel is OPERABLE.

ACTION 13- Deleted ACTION 14 - With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement, be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

ACTION 15 - With one of the diverse trip features (undervoltage or shunt trip attachment) inoperable, restore it to operable status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or declare the breaker inoperable and apply ACTION 12. The breaker shall not be bypassed while one of the diverse trip features is inoperable except for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for performing maintenance to restore the breaker to OPERABLE status.

ACTION 16 - With the number of OPERABLE channels one less than the minimum channels operable requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or open the reactor trip breakers within the next hour.

October 4, 1995 SEQUOYAH - UNIT 1 3/4 3-8 Amendment No. 54, 141,213

I NSTRUMENTATION 3/4.3.2 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.2.1 The Engineered Safety Feature Actuation System (ESFAS) instrumentation channels and interlocks shown in Table 3.3-3 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Nominal Trip Setpoint column of Table 3.3-4.

APPLICABILITY: As shown in Table 3.3-3.

ACTION:

a. With an ESFAS instrumentation channel or interlock trip setpoint less conservative than the value shown in the Allowable Values column of Table 3.3-4, declare the channel inoperable and apply the applicable ACTION requirement of Table 3.3-3 until the channel is restored to OPERABLE status with the trip setpoint adjusted consistent with the Nominal Trip Setpoint value.

b. With an ESFAS instrumentation channel or interlock inoperable, take the ACTION shown in Table 3.3-3.

SURVEILLANCE REQUIREMENTS 4.3.2.1.1 Each ESFAS instrumentation channel shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations for the MODES and at the frequencies shown in Table 4.3-2.

4.3.2.1.2 The logic for the interlocks shall be demonstrated OPERABLE during the automatic actuation logic test. The total interlock function shall be demonstrated OPERABLE at least once per 18 months during CHANNEL CALIBRATION testing of each channel affected by interlock operation.

4.3.2.1.3 The ENGINEERED SAFETY FEATURES RESPONSE TIME of each ESFAS function shall be verified to be within the limit at least once per 18 months. Each verification shall include at least one train such that both trains are verified at least once per 36 months and one channel per function such that all channels are verified at least once per N times 18 months where N is the total number of redundant channels in a specific ESFAS function as shown in the Total No. of Channels Column of Table 3.3-3.

September 13, 2006 SEQUOYAH UNIT 1- 3/4 3-14 Amendment No. 190, 251, 310

TABLE 3.3-3 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TOTAL NO. MINIMUM OF CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT CHANNELS TO TRIP OPERABLE MODES ACTION

1. SAFETY INJECTION, TURBINE TRIP AND FEEDWATER ISOLATION

a. Manual Initiation 2 1 2 1, 2, 3, 4 20

b. Automatic Actuation 2 1 2 1, 2, 3, 4 15 Logic

c. Containment Pressure High 3 2 2 1,2,3 17

d. Pressurizer Pressure- 3 2 2 1, 2, 3# 17 Low

e. Deleted April 11,2005 SEQUOYAH - UNIT 1 3/4 3-15 Amendment No. 41, 141, 301

TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TOTAL NO. MINIMUM OF CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT CHANNELS TO TRIP OPERABLE MODES ACTION

f. Steam Line Pressure- 3/steam line 2/steam line 2/steam line 1, 2, 3# 17 Low in any steam line

2. CONTAINMENT SPRAY

a. Manual 2 1** 2 1,2, 3, 4 20

b. Automatic Actuation 2 1 2 1, 2, 3, 4 15 Logic

c. Containment Pressure- 4 2 3 1,2,3 18

-High-High

3. CONTAINMENT ISOLATION

a. Phase A Isolation

1) Manual 2 1 2 1, 2, 3, 4 20

2) From Safety 2 1 2 1, 2, 3,4 15 Injection Automatic Actuation Logic

- Two switches must be operated simultaneously for actuation.

April 11,2005 SEQUOYAH - UNIT 1 3/4 3-16 Amendment No.41, 63, 141, 168, 301

TABLE 3.3-3 (Continued ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

b. Phase B Isolation

1) Manual 2 1** 2 1,2,3,4 20

2) Automatic Actuation 2 1 2 1, 2, 3, 4 15 Logic

3) Containment 4 2 3 1,2,3 18 Pressure-High-High

c. Containment Ventilation 2 1 2 1,2, 3, 4 19 Isolation

1) Manual

2) Automatic Isolation 2 1 2 1,2, 3, 4 15 Logic

3) ContainmentPurgeAir 2 1 1 1,2,3,4 19 Exhaust Monitor Radioactivity-High

- Two switches must be operated simultaneously for actuation.

April 11,2005 SEQUOYAH - UNIT 1 3/4 3-17 Amendment No. 41, 63, 168, 301

TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

4. STEAM LINE ISOLATION

a. Manual 1/steam line 1/steam line 1/operating 1,2, 3 25 steam line

b. Automatic Actuation Logic 2 1 2 1, 2, 3 23

c. Containment Pressure-- 4 2 3 1,2,3 18 High-High

d. Steam Line Pressure- Low 3/steam line 2/steam line 2/steam line 1, 2, 3# 17 in any steam line

e. Negative Steam Line 3/steam line 2/steam line 2/steam line 3 17 Pressure Rate-High in any steam lines April 11,2005 SEQUOYAH - UNIT 1 3/4 3-18 Amendment No. 41, 141, 301

TABLE3.3-3 (COntinuecfl ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TOTAL NO. MINIMUM OF CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT CHANNELS TO TRIP OPERABLE MODES ACTION

5. TURBINE TRIP &

FEEDWATER ISOLATION

a. Steam Generator 3/loop 2iloop in any 2/loop in each 1, 2, 3 17 Water Level operating loop operating loop High-High

b. Automatic 2 1 2 1, 2, 3 23 Actuation Logic

6. AUXILIARY FEEDWATER

a. Manual Initiation 2 1 2 1,2,3 24

b. Automatic 2 1 2 1, 2, 3 23 Actuation Logic

c. Main Stm. Gen.

Water LevelLow-Low

i. Start Motor-Driven Pumps

a. Steam Generator 3/Stm. Gen. 2/Stm. Gen. 2/Stm. Gen. 1,2,3 36 Water Level--Low- in any in each Low (Adverse) operating operating Stm. Gen. Stm. Gen

b. Steam Gen 3/Stm. Gen 2/Stm. Gen. 2/Stm. Gen. 1,2, 3 36 Water Level-- in any in each Low-Low (EAM) operating operating Stm.Gen. Stm.Gen.

c. RCS Loopz\T 4(1/loop) 2 3 1,2, 3 37

d. Containment 4 2 3 1,2, 3 38 Pressure (EAM)

April 11,2005 SEQUOYAH - UNIT 1 3/4 3-19 Amendment No.41,63, 141, 301

TABLE 3.3-3 (COnfinud) -

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TOTAL NO. MINIMUM OF CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT CHANNELS TO TRIP OPERABLE MODES ACTION ii. Start Turbine Driven Pump

a. Steam Generator 3/Stm. Gen. 2/Stm. Gen. 2/Stm. Gen. 1,2, 3 36 Water Level-- in any 2 Stm. in each Low-Low Gen. operating (Adverse) Stm. Gen

b. Steam Generator 3/Stm. Gen. 2/Stm. Gen. 2/Stm. Gen. 1,2, 3 36 Water Level-- in any 2 Stm. In each Low-Low (EAM) Gen. operating Stm.

Gen

c. RCS Loop zT 4(1/loop) 2 3 1, 2, 3 37

d. Containment 4 2 3 1,2,3 38 Pressure (EAM)

d. SI.

Start Motor-Driven See 1 above (all S.!. initiating functions and requirements)

Pumps and Turbine Driven Pump April 11, 2005 SEQUOYAH - UNIT 1 3/4 3-19a Amendment No.41,63, 141, 301

TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TOTAL NO. MINIMUM OF CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT CHANNELS TO TRIP OPERABLE MODES ACTION

e. Loss of Power Start

1. Voltage Sensors 3/shutdown 2/shutdown 3/shutdown 1, 2, 3 35 board** board** board**

2. Load Shed Timer 2/shutdown 1/shutdown 1/shutdown 1, 2, 3 35 board** board** board**

f. Trip of Main Feedwater Pumps Start Motor-Driven Pumps and Turbine Driven Pump 1/pump 1/pump (b) 20 i/pump

g. Auxiliary Feedwater Suction Pressure-Low 3/pump 2/pump 3/pump 1, 2, 3 21

h. Auxiliary Feedwater Suction Transfer Time Delays

1. Motor-Driven Pump 1/pump 1/pump 1/pump 1, 2, 3 21

2. Turbine-Driven Pump 2/pump 1/pump 2/pump 1,2, 3 21

- Unit 1 shutdown boards only (a) One channel may be inoperable during Mode 1 for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months when placing the second main feedwater (MFW) pump in service or removing one of two MFW pumps from service.

(b) When one or more Main Feedwater Pump(s) are supplying feedwater to steam generators.

August 29, 2008 SEQUOYAH UNIT 1

- 3/4 3-20 Amendment No. 41, 129, 182, 188, 207, 301, 310, 319

TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

7. This Functional Unit has been deleted.

8. ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INTERLOCKS

a. Pressurizer Pressure- 3 2 2 1, 2, 3 22a P-i 1/Not P-il

b. Deleted

c. Steam Generator Level 3/loop 2/loop any 3/loop 1, 2 22c P-14 loop September 14, 2006 SEQUOYAH - UNIT 1 3/4 3-21 Amendment No. 41, 129, 141, 160, 182, 188, 207, 310, 311

TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TOTAL NO. MINIMUM OF CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT CHANNELS TO TRIP OPERABLE MODES ACTION

9. AUTOMATIC SWITCHOVER TO CONTAINMENT SUMP

a. RWST Level Low- 4 2 3 1,2, 3,4 18 COINCIDENT WITH Containment Sump Level High 4 2 3 1,2,3,4 18 AND Safety Injection (See I above for Safety Injection Requirements)

b. Automatic Actuation 2 1 2 1,2,3,4 15 Logic December 31, 1987 SEQUOYAH UNIT 1

- 3/4 3-21a Amendment No. 29, 63

TABLE 3.3-3 (Continuecfl TABLE NOTATION Trip function may be bypassed in this MODE below P-i 1 (Pressurizer Pressure Block of Safety Injection) setpoint.

Trip function automatically blocked above P-il and may be blocked below P11 when Safety Injection on Steam Line Pressure-Low is not blocked.

ACTION STATEMENTS ACTION 15 - With the number of OPERABLE Channels one less than the Total Number of Channels, be in at least HOT STANDBY within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ; however, one channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification 4.3.2.1.1 provided the other channel is OPERABLE.

ACTION 16 - Deleted.

ACTION 17 - With the number of OPERABLE Channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b. The Minimum Channels OPERABLE requirements is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.2.1 .1.

ACTION 18 - With the number of OPERABLE Channels one less than the Total Number of Channels, operation may proceed provided the inoperable channel is placed in the bypassed condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and the Minimum Channels OPERABLE requirement is met; one additional channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification 4.3.2.1.1.

ACTION 19 - With less than the Minimum Channels OPERABLE, operation may continue provided the containment purge supply and exhaust valves are maintained closed.

ACTION 20 - With the number of OPERABLE Channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

September 14, 2006 SEQUOYAH - UNIT 1 3/4 3-22 Amendment No. 63, 141, 168, 182, 188, 202, 207, 213, 301, 311

TABLE 3.3-3 (Continued)

ACTION 21 - With less than the Minimum Number of Channels OPERABLE, declare the associated auxiliary feedwater pump inoperable, and comply with the ACTION requirements of Specification 3.7.1.2.

ACTION 22 - With less than the Minimum Number of Channels OPERABLE, declare the interlock inoperable and verify that all affected channels of the functions listed below are OPERABLE or apply the appropriate ACTION statement(s) for those functions.

Functions to be evaluated are:

a. Safety Injection Pressurizer Pressure Steam Line Pressure Negative Steam Line Pressure Rate

b. Deleted

c. Turbine Trip Steam Generator Level High-High Feedwater Isolation Steam Generator Level High-High ACTION 23 - With the number of OPERABLE channels one less than the Total Number of Channels, be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in at least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; however, one channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per Specification 4.3.2.1.1.

ACTION 24 - With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in at least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

ACTION 25 - With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or declare the associated valve inoperable and take the ACTION required by Specification 3.7.1.5.

ACTION 34 - Deleted September 14, 2006 SEQUOYAH - UNIT 1 3/4 3-23 Amendment No. 12, 63, 129, 141, 160, 182, 188, 207, 310, 311

TABLE 3.3-3 (Continued)

ACTION 35 - a. With the number of OPERABLE channels one less than the Total Number of Channels for voltage sensors, restore the inoperable channel to OPERABLE I status within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or enter applicable Limiting Condition(s) For Operation and Action(s) for the associated auxiliary feedwater pump made inoperable by the channel.

b. With the number of OPERABLE channels less than the Total Number of Channels by more than one for voltage sensors or timers, restore all but one channel to OPERABLE status within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or enter applicable Limiting Condition(s) For Operation and Action(s) for the associated auxiliary feedwater pump made inoperable by the channels.

ACTION 36 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b. For the affected protection set, the Trip Time Delay for one affected steam generator (T) is adjusted to match the Trip Time Delay for multiple affected 5

steam generators (TM) within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

c. The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.2.1.1.

ACTION 37 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided that within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , for the affected protection set, the Trip Time Delays (T 5 and TM) threshold power level for zero seconds time delay is adjusted to 0% RTP.

ACTION 38 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided that within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , for the affected protection set, the Steam Generator Water Level Low-Low (EAM) channels trip setpoint is adjusted to the same value as Steam Generator Water Level Low-Low (Adverse).

September 13, 2006 SEQUOYAH UNIT 1

- 3/4 3-23a Amendment No. 141, 160, 182, 188, 207, 310

INSTRUMENTATION ACCIDENT MONITORING INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.7 The accident monitoring instrumentation channels shown in Table 3.3-10 shall be OPERABLE.

APPLICABILITY: MODES 1, 2 and 3.

ACTION: As shown in Table 3.3-10 SURVEILLANCE REQUIREMENTS 4.3.3.7 Each accident monitoring instrumentation channel shall be demonstrated OPERABLE:

a. Every 31 days by performance of a CHANNEL CHECK, and

b. Every 18 months by performance of a CHANNEL CALIBRATION.*

For Containment Area Radiation Monitors, a CHANNEL CALIBRATION may consist of an electronic calibration of the channel, not including the detector, for range decades above lORIh and a single calibration check of the detector below 1 OR/h with either an installed or portable gamma source.

December 07, 1990 SEQUOYAH - UNIT 1 3/4 3-55 Amendment No. 40, 112, 149

TABLE 3.3-10 ACCIDENT MONITORING INSTRUMENTATION TOTAL NO. MINIMUM INSTRUMENT OF CHANNELS CHANNELS ACTION REQUIRED

1. Reactor Coolant THOT (Wide Range)

(Instrument Loops68-001,-024,-043,-065) 4(1/RCS Loop) 4(1/RCS Loop) 1

2. Reactor Coolant TCOLD (Wide Range) 4(1/RCS Loop) 4(1/RCS Loop) 1 (Instrument Loops 68-01 8,-04 1 ,-060,-083)

3. Containment Pressure (Wide Range) 2 2 1 (Instrument Loops 30-310-311)

4. Containment Pressure (Narrow Range) 2 2 1 (Instrument Loops 30-044-045)

5. Refueling Water Storage Tank Level 2 2 1 (Instrument Loops63-050,-051)

6. Reactor Coolant Pressure (Wide Range) 3 3 2 (Instrument Loops68-062,-066,-069)

7. Pressurizer Level (Wide Range) 3 3 2 (Instrument Loops68-320,-335,-339)

8. Steam Line Pressure 2/steam line 2/steam line 1 (Instrument Loops 1 -002A,-002B ,-009A,-009B ,-

020A,-020B,-027A,-027B)

9. Steam Generator Level (Wide Range) 4(1/steam 4(1/steam 1 (Instrument Loops 3-043,-056,-098,-11 1) generator) generator)

10. Steam Generator Level (Narrow Range) 2/steam 2/steam 1 (Instrument Loops 3-039,-042,-052,-055,-094,- generator generator 097,-i 07,-i 10) ii. Auxiliary Feedwater

a. Flow Rate 1/steam 1/steam 5 (Instrument Loops 3-1 63,-i 55,-i 47,-i 70) generator generator

b. Valve Position Indication 3/steam 3/steam 5 (Instrument Loops 3-i 64,-i 64A,-i 72,-i 56, generator generator

-i 56A,-i 73,-148,-i48A,-1 74,-i 71,-i 71A,-i 75)

July 9, 1992 SEQUOYAH - UNIT 1 314 3-56 Amendment No.46, 114, 149, 159

TABLE 3.3-10 (Continued)

ACCIDENT MONITORING INSTRUMENTATION MINIMUM TOTAL NO CHANNELS INSTRUMENT OF CHANNELS REQUIRED ACTION

12. Reactor Coolant System Subcooling 2 2 1 Margin Monitor (Instrument Loops94-101 ,-1 02)

13. Containment Water Level (Wide Range) 2 2 1 (Instrument Loops 63-178-179)

14. Incore Thermocouples 65

a. CoreQuadrant(1) 2(1/Train) 1

b. Core Quadrant (2) 2(1/Train) I

c. Core Quadrant (3) 2(1/Train) 1

d. Core Quadrant (4) 2(1/Train) 1

15. Reactor Vessel Level Instrumentation 6

a. Dynamic Range (Instrument Loops 2 1 68-367, 370)

b. Lower Range (Instrument Loops 68- 2 1 368, 371)

c. Upper Range (Instrument Loops 68- 2 1 369, 372)

16. Containment Area Radiation Monitors

a. Upper Compartment (Instrument Loops90-271,-272) 2 1 4

b. Lower Compartment (Instrument 2 1 4 Loops90-273,-274)

October 4, 1995 SEQUOYAH - UNIT 1 3/4 3-56a Amendment No. 112, 149, 159, 213

TABLE 3.3-10 (Continued)

ACCIDENT MONITORING INSTRUMENTATION TOTAL NO. MINIMUM INSTRUMENT OF CHANNELS CHANNELS ACTION REQUIRED

17. Neutron Flux

a. Source Range 2 1 2#

(Instrument Loops 92-5001-5002)

b. Intermediate Range 2 2 1 (Instrument Loops 92-5003,-5004)

18. ERCW to AFW Valve Position

a. Motor Driven Pumps 1/Train/Pump 1/Train/Pump 1 (Instrument Loops 3-116A, (2 Valves/Train) (2 Valves/Train)

-116B, -126A, -126B)

b. Turbine Driven Pumps 2 Trains 2 Trains I (Instrument Loops 3-136A, (2 Valves/Train) (2 Valves/Train)

-136B, -179A, -179B)

19. Containment Isolation iNalve lNaIve## 3 Valve Position (Panels TR-A XX-55-6K

& TR-B XX-55-6L)

Source Range outputs may be disabled above the P-6 (Block of Source Range Reactor Trip) setpoint.

1. Not required for isolation valves that are closed and deactivated.

July 9, 1992 SEQUOYAH UNIT 1- 3/4 3-56b Amendment No. 112, 149, 159

TABLE 3.3-10 (Coitinued)

ACTION STATEMENTS ACTION 1 - NOTE: Also refer to the applicable action requirements from Tables 3.3-1 and 3.3-3, and LCO 3.3.3.5 since they may contain more restrictive actions.

a. With the number of channels one less than the minimum channels required, restore the inoperable channel to OPERABLE status within 30 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and in HOT SHUTDOWN within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b. With the number of channels two less than the minimum channels required, restore at least one inoperable channel to OPERABLE status within 7 days, or be in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

ACTION 2 - NOTE: Also refer to the applicable action requirements from Tables 3.3-1 since it may contain more restrictive actions.

a. With the number of channels one less than the minimum channels required, restore the inoperable channel to OPERABLE status within 30 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b. With the number of channels two less than the minimum channels required, restore at least one inoperable channel to OPERABLE status within 7 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

c. With the number of channels three less than the minimum channels required, restore one channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

ACTION 3 NOTE:

- Also refer to the applicable action requirements from LCO 3.6.3 since it may contain more restrictive actions.

1. 1. a. With the accident monitoring indication for one of the penetration inboard or outboard valve(s) inoperable, restore the inoperable valve(s) accident indication to OPERABLE status within 30 days, or isolate each affected penetration within 30 days by use of at least one deactivated automatic valve secured in the isolated position, or isolate each April 11,2005 SEQUOYAH - UNIT 1 3/4 3-57 Amendment No. 46, 149, 159, 301

TABLE 3.3-10 (Continued)

ACTION STATEMENTS (Continued) affected penetration within 30 days by use of at least one closed manual valve or blind flange, or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and HOT SHUTDOWN within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

1. 1. b. With the accident monitoring indication for both an inboard and outboard valve(s) on the same penetration inoperable, restore at least the inboard or outboard inoperable valve(s) indication to OPERABLE status within 7 days, or isolate each affected penetration within 7 days by use of at least one deactivated automatic valve secured in the isolated position, or isolate each affected penetration within 7 days by use of at least one closed manual valve or blind flange, or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and HOT SHUTDOWN within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

1. 1. On a penetration where accident indication is declared INOPERABLE on a valve but on the opposite side of the penetration an accident indication valve does not exist (such as with a closed system or a check valve), only ACTION 3(a) must be entered. However, valves FCV-63-158 & -

172 are both inboard penetration valves, but if both valves have inoperable accident indication, ACTION 3(b) must be entered until at least one of the valves accident indication is restored to OPERABLE status. Valves FCV-30-46 & VLV-30-571, FCV-30-47 & VLV-30-572, and FCV-30-48

& VLV-30-573 are all outboard penetration valves, but if both valves have inoperable accident indication, ACTION 3(b) must be entered until at least one of the valves accident indication is restored to OPERABLE status.

April 11,2005 SEQUOYAH - UNIT 1 3/4 3-57a Amendment No. 159, 301

TABLE 3.3-10 (Continued)

ACTION STATEMENTS (Continued)

ACTION 4 - With the number of channels less than the minimum channels required, initiate an alternate method of monitoring containment area radiation within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months and either restore the inoperable channel(s) to OPERABLE status within 30 days, or prepare and submit a special report to the Commission pursuant to Specification 6.9.2.1 within the next 14 days that provides actions taken, cause of the inoperability, and plans and schedule for restoring the channels to OPERABLE status.

ACTION 5 NOTE:

- Also refer to the applicable action requirements from LCO 3.3.3.5 since it may contain more restrictive actions.

a. With the number of channels on one or more steam generators less than the minimum channels required for either flow rate or valve position, restore the inoperable channel to OPERABLE status within 30 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b. With the number of channels on one or more steam generators less than the minimum channels required for flow rate and valve position, restore the inoperable channel(s) to OPERABLE status within 7 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

April 11,2005 SEQUOYAH UNIT 1

- 3/4 3-57b Amendment No. 112, 149, 159, 301

JPM SRO A.2 Page 1 of 7 Rev. 0 SEQUOYAH NUCLEAR PLANT SRO ADMIN A.2 Evaluate Arc Clothing Requirements and Tag Flash Verification Requirements

JPM SRO A.2 Page 2 of 7 Rev. 0 SRO JOB PERFORMANCE MEASURE Task: Evaluate Arc Clothing Requirements and Tag Verification Requirements Task#: 3420320302 Task Standard: The examinee determines the minimum protective clothing requirements for manipulating electrical breakers of a Flash Hood (ATPV 100 or 100 cal) and Flash Suit (ATPV 100 or 100 cal) during breaker manipulation and that independent verification is required when placing tags.

Time Critical Task: YES: NO: X KIA ReferencelRatings: 2.2.13 (3.8)

Method of Testing:

Simulated Performance: Actual Performance: X Evaluation Method:

Simulator In-Plant Classroom X Main Control Room Mock-up Performer:

Trainee Name Evaluator: I Name! Signature DATE Performance Rating: SAT: UNSAT:

Validation Time: 6 mm Total Time:

Performance Time: Start Time: Finish Time:

COMMENTS

JPM SROA.2 Page 3 of 7 Rev. 0 SPECIAL LNSTRUCTLONS TO EVAUJATOR:

1 Critical steps are identified in step SAT/UNSAT column by bold print Critical Step.

2. Any UNSAT requires comments.

ToolslEquipmentlProcedures Needed:

1. NPG SPP-10.2, Clearance Procedure to Safely Control Energy

2. NPG-SPP-10.3, Verification Program

3. Tl-300, Electrical Arc Flash Personal Protective Equipment & Protection Boundary Matrices

4. Copy of clearance 2- 82-1807

References:

Reference Title Rev No.

1. NPG SPP-10.2 Clearance Procedure to Safely Control Energy 1

2. NPG-SPP-10.3 Verification Program 0

3. Tl-300 Electrical Arc Flash Personal Protective Equipment 19

& Protection Boundary Matrices 4 0-GO-la ELECTRICAL APPARATUS OPERATION 45 Read to the examinee:

DIRECTIONS TO TRAINEE:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM. I will provide initiating cues and reports on other actions when directed by you. When you complete the task successfully, the objective for this job performance measure will be satisfied. Ensure you indicate to me when you understand your assigned task. To indicate that you have completed your assigned task return the handout sheet I provided you.

HAND JPM BRIEFING SHEET TO EXAMINEE AT THIS TIME!

INITIAL CONDITIONS:

1. Unit 2 is in Mode I

2. Clearance 2- 82-1807 is being developed on Diesel 2A2 Starting Air Compressor.

3. The clearance will require opening Diesel 2A2 Starting Air Compressor breaker located on Diesel Aux Board 2A1-A.

INITIATING CUES:

1. You are the WCC SRO and will complete developing clearance 2-82-1807

2. You will identify:

a. MINIMUM Arc Flash protective clothing requirements above normal PPE for the individual performing the breaker manipulation

b. The verification requirements for the actual placement of the clearance cards.

3. Inform the evaluator when you are complete.

JPM SRO A.2 Page 4 of 7 Rev. 0 Start Time Obtain a copy of clearance 2- 82-1807.

STEP 1 : SAT UNSAT Standard: Copy of clearance 2- 82-1807 is obtained Cue Provide a copy of clearance 2- 82-1807.

Comment Obtain a copy of TI-300 Electrical Arc Flash Personal Protective STEP 2 : Equipment & Protection Boundary Matrices SAT UNSAT Standard Copy of TI-300, Electrical Arc Flash Personal Protective Equipment &

Protection Boundary Matrices is obtained When directed, provide a copy of Tl-300, Electrical Arc Flash Personal Cu i Protective Equipment & Protection Boundary Matrices.

Comment

JPM SRO A.2 Page 5 of 7 Rev. 0 Determine the MINIMUM Arc Flash protective clothing equiremerts STEP 3 above normal PPEfor the individual opening Diesel 2A2 Starting Air SAT Compressor breaker.

UNSAT Critical Step Examinee determines the MINIMUM Arc Flash protective clothing Standar& requirements above normal PPE for the individual opening Diesel 2A2 Starting Air Compressor breaker is a Flash Hood (ATPV 100 or 100 cal) and a Flash Suit (ATPV 100 or 100 cal).

Comment The reference for the MINIMUM Arc Flash protective clothing Examiner requirements is contained in Tl-300, Electrical Arc Flash Personal Note: Protective Equipment & Protection Boundary Matrices Appendix A (Page 7 of 24)

Appendix A (Page 7 of 24>

ARC FLASH PERSONAL PROTECTIVE EQUIPMENT (PPE)IPROTECTIVE BOUNDARY MATRICES Examiner orkg *,w.,E ArrF:sr DaW?a ;ceS!-eo F HaFashboj Ra#SU FntSt Note*. I 4SO<,SLtiX 84 241*

kTPVS) ATF IATPV3t ATP IC6I ATP31)

DD-2Q1-FOA 2

[

Examiner This step is critical because it identifies the minimum PPE required to Note: complete the breaker manipulation.

JPM SROA.2 Page 6 of 7 Rev. 0 Obtain a copy of NPG-SPP-10.3, Verification Program STEP 4 : SAT UNSAT Standard: Copy of NPG-SPP10.3, Verification Program is obtained.

When directed, provide a copy of NPG-SPP-10.3, Verification Program.

Comment Determine the MINIMUM verification requirements for the actual STEP 5 : placement of the clearance cards SAT UNSAT Critical Step Standard Examinee determines the MINIMUM verification requirements for the actual placement of the clearance cards is independent verification Comment 3.4.4 Independent Verification Requirements IV is used to confirm that an activity or condition has been implemented in conformance with specified requirements. The individual performing the IV shall physically check the condition E xam I ner without relying on observation or verbal confirmation by the initial performer. However, the Note: independent venfier may be involved in unrelated portions of the same activity. IV is required for the following (except for components which meet the criteria in Section 3.4.5 for concurrent verification):

E. Placement and release of hold order tags.

Examiner The reference for the MINIMUM is NPG-SPP-10.3, Verification Program Note: step 3.4.4.E Examiner This step is critical because it identifies the minimum verification Note: requirement for clearance placement.

Terminating The task is complete when the Examinee returns the cue sheet to Cue: the examiner. STOP Stop Time

JPM SRO A.2 Page 7 of 7 Rev. 0 JPM BRIEFING SHEET DIRECTIONS TO TRAINEE:

The examiner will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this job performance measure will be satisfied.

INITIAL CONDITIONS:

1. Unit 2 is in Mode I

2. Clearance 2- 82-1 807 is being developed on Diesel 2A2 Starting Air Compressor.

3. The clearance will require opening Diesel 2A2 Starting Air Compressor breaker located on Diesel Aux Board 2A1-A.

INITIATING CUES:

1. You are the WCC SRO and will complete developing clearance 2- 82-1807

2. You will identify:

a. MINIMUM Arc Flash protective clothing requirements above normal PPE for the individual performing the breaker manipulation

b. The verification requirements for the actual placement of the clearance cards.

3. Inform the evaluator when you are complete.

Acknowledge to the examiner when you are ready to begin.

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

,cai 4.,II(..t JVeIIIaci. .utyaii I WULIUI na, IL .nr- .L LJ, ragout: 2-TO -2009-0024 WA Form 17982 [10-2008J Form Date: 10-2008 clearance: 2-82-1807 -W/W 2/18/201 1 14:16:5 Component to be WQrked 2-CMP - 82- 241 2A2 STARTING AIR COMPRESSOR 25.5 CFM 2-DGB-722-D/G 2A_DG 2A-A Engine Room Remarks DSL 2A2 STARTING AIR COMPRESSOR 25.5 CFM This clearance is written to maintain system configuration control. Configuration control of components within the boundary not listed by this clearance SHALL remain in the required configuration unless controlled by another approved plant procedure.

Review & operate equipment only lAW 0-S0-82-3 & O-S0-82-7.

SRO to evaluate the TI-300 Arc Flash Requirements for breaker manipulation.

Placement Instructions

1. Place clearance.

Caution Tag Information Release Instructions

1. Release clearance.

Clearance Attributes:

Attribute Attribute Description Value

?equested By equestors_Organization f storsPhoneand Pager -

L umber Vork Week or Outage Window

cheduled Date

)utaqe Related Clearance?

ontainment Penetration Breached?

round Discs Issued?

Work Order I CPAL List:

Clearance Verification:

Status Description Name Verification Date

ection Written Written

ection Placement Reviewed Placement Reviewed -

pproved for Placement Placement_Approved --________ -- - -

ssued Issued

ection Release Modified Modified pproved for Release Release Reviewed & Approved .,...-.--

pproved for Archive -

Released Ground Disc List:

Porm 17982110-20081 1/1

Clearance Tag List DO NOT USE FOR TAG PLACEMENT OR REMOVAL Sequoyah Nudear Plant Tagout 2-TO -2009-0024 SPP-10.2 Clearance: 2- 82-1807 -W/W 02/18/2011 14:16 Tag :Eqwpm1t Ver: Pla Placement Place. 1st Place. 2nd , Ver Rest Rest. Config. Rest. 1st Rest. 2nd Type Req. Seq Configuration Verif Verif Req Seq :*AS Left (If Duff.) Verif Verif

Equipment Description Date/Time Date/Time Date/Time Date/Time Serial No.* Equipment Location 1* Notes

Notes

)anger 0-HS 82- 241 - 1 OFF NV 2 AUTO

.0 Sel Sw Auto-Off-Man Eng

2A2Bay2A-A 0-DGB-722-D/G 2A_DG 2A-A Control Board, Ann Pnl

. 45N771-2 Danger 2-T 82- 241 2 OFF NV , 1 ON 0 E* DIESEL GEN 2A-A AIR 1* Evaluate TI-300 COMPRESSOR 2 requirements

2-DGB-740-FQ _480V Diesel Aux Board 2A1-A, compt 6C Component Print Number O-HS 82 241 45 N77 1-2 2-BCTC 241 45N732-1 WA ForAi 11 --

[11-20051 Page loLl

SQN ELECTRICAL ARC FLASH PERSONAL TI-300 Unit 0, 1, & 2 PROTECTIVE EQUIPMENT & Rev. 0019 PROTECTION BOUNDARY MATRICES Page 15 of 36 Appendix A (Page 7 of 24)

ARC FLASH PERSONAL PROTECTIVE EQUIPMENT (PPE)/PROTECTIVE BOUNDARY MATRICES Required PPE Working Incident Arc Flash Location Distance Daily Wear 1 Face Shield Flash Hood Flash Hood Flash Suit Flash Suit 6

Energy Boundary (inches) )

2 (Cal/cm (ATPV 8) (ATPV 8) (ATPV 31) (ATPV 100) (ATPV 31) (ATPV 100)

(feet) 480VC&ABD2A2A2BDC201JKA 18.0 12.1 6.1 X X See Note 11 480VC&AVTBD2B1B2BDC2O1JLB 18.0 9.2 5.2 X X See Note 11 480V C&A VT BD 2B2B2BDC201JMB 18.0 12.6 6.3 X X See Note 11 480V C&V CONT BD A 0-BDC-201-HD

- 18.0 3.6 3.0 X X See Note 18 480VC&VCONTBDB-0-BDSC-201-HE 18.0 39.2 10.9 x x 480V CDWES BLDG MCC 18.0 4.6 3.4 X X See Note 18 0-BDC-201-JV 480V COND DEM BLDG 18.0 73.3 15.3 X X 0-BDC-201-FZ 48OVDSLAUXBD 1A1A 18.0 34.0 10.1 X x 1-BDC-201-FO-A 480V DSL AUX BD 1A2A 18.0 34.6 10.2 X X 1-BDC-201-FP-A 480V DSL AUX BD 1B1B 18.0 29.4 9.3 X X 1-BDC-201-FS-B 48OVDSLAUXBD IB2B 18.0 29.6 9.4 X X 1-BDC-201 -FT-B 480V DSL AUX BD 2A1A 18.0 32.6 9.9 X X 2-BDC-201-FQ-A 48OVDSLAUXBD2A2A 18.0 29.3 9.3 X X 2-BDC-201 -FR-A 48OVDSLAUXBD2B1B 18.0 35.1 10.3 X X 2-BDC-201 -FU-B 480V DSLAUX BD 2B2B 18.0 35.9 10.4 X X 2-BDC-201-FV-B 480V F&W HDLG BD A 18.0 3.6 3.0 X X See Note 18 0-BDC-201-HB 480V F&W HDLG BD B 18.0 36.0 11.4 X X 0-BDC-201-HC 480V LUB OIL BD 18.0 51.9 12.7 X X 0-BDC-20 1-HF 480V MK WTR TRMT BD 18.0 5.9 4.0 X X See Note 18 0-BDC-201-HA

NPG Standard Verification Program NPG-SPP-1 0.3 Programs and Rev. 0000 Processes Page 8 of 18 3.3.4 Alternate Verification Techniques Alternate verification techniques may be used by the verifier where specified by approved procedures, valve and breaker line-up checklists, or at the discretion of shift supervisory personnel. Examples include the following:

A. Use of remote position indicators. (Indicating lights in the control room, at the switchgear, or at local controls are the normal method of determining motor-operated and air-operated valve position.)

B. Use of process parameters (e.g., pressure, flow, vibration, current, voltage, potential lamps, etc.).

C. Observation of the valve stem to aid in determination of valve position if the valve stem is marked by paint (when fully closed) or other positive verification methods.

D. Authorized scribe marks on valve stems, properly labeled with the throttled position.

E. Functional mechanical position indicators.

F. A post maintenance/modification functional test provided the testing verifies each component under consideration.

33.5 Circuit Breakers Circuit breaker verification shall include a local inspection of the breaker, control power switches or fuses, and other equipment as outlined below:

A. To verify a breaker is removed from service, the independent or concurrent verifier shall ensure control power is isolated (if required) by inspecting appropriate switches, fuses or fuse blocks, and ensure the breaker is racked out to the disconnected position, as applicable.

B. To verify a breaker is restored to service, the independent or concurrent verifier shall ensure control power is energized by inspecting appropriate switches, indicating lights, fuses or fuse blocks, and shall ensure the breaker is fully racked in with closing springs charged as applicable. Where practical, the end device should be operated following the reinstallation of a breaker. The verifier also shall ensure the cubicle door is in good condition with all fasteners tight.

3.4 Verification Requirements When determination of these requirements is not clear, the responsible manager shall designate the requirements. If there is disagreement, the Operations Manager shall designate the requirements.

JPM SRO A.3 Page 1 of 7 Rev. 0 SEQUOYAH NUCLEAR PLANT SRO ADMIN A3 Pre Job Analysis for Emergent Work in the RCA

JPM SRO A.3 Page 2 of 7 Rev. 0 SRO JOB PERFORMANCE MEASURE Task: Pre Job Analysis for Emergent Work in the RCA Task#: 3430290302 Task Standard: Examinee calculates a total dose of 160 mrem and based on that calculation, applies the result to On Line Work Management Appendix A to conclude the evolution is a

category High Risk.

Time Critical Task: YES: NO: X KIA ReferencelRatings: 2.3.13 (3.8)

Method of Testing:

Simulated Performance: Actual Performance: X Evaluation Method:

Simulator In-Plant Classroom X Main Control Room Mock-up Performer:

Trainee Name Evaluator: I Name I Signature DATE Performance Rating: SAT: UNSAT:

Validation Time: 14 mm Total Time:

Performance Time: Start Time: Finish Time:

COMMENTS

JPMSROA.3 Page 3 of 7 Rev. 0 SPECIAL INSTRUCTIONS TOEVALUATOR: -

1. Critical steps are identified in step SAT/UNSAT column by bold print Critical Step.

2. Any UNSAT requires comments.

ToolslEquipment/Procedures Needed:

1. NPG-SPP-07.i, On Line Work Management

2. Calculator

3. Survey map A216 U-i Pipe Chase

4. Survey map A217 U-2 Pipe Chase

5. Survey map 408 U-i Mixed Bed Valve Gallery

6. Survey map 417 U-2 Mixed Bed Valve Gallery

References:

Reference Title Rev No.

1. NPG-SPP-07. 1 On Line Work Management 3

2. RCI-3 Read to the examinee:

DIRECTIONS TO TRAINEE:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM. I will provide initiating cues and reports on other actions when directed by you. When you complete the task successfully, the objective for this job performance measure will be satisfied. Ensure you indicate to me when you understand your assigned task. To indicate that you have completed your assigned task return the handout sheet I provided you.

HAND JPM BRIEFING SHEET TO EXAMINEE AT THIS TIME!

INITIAL CONDITIONS:

1. Unit2isinMODEl

2. You are the WCC SRO and are performing a review of a work package to be merged into the schedule in two weeks.

3. The work is in the vicinity of valve 2-63-750 Test Conn on RHR Suction from RWST located in the Auxiliary Bldg 653 elevation pipe chase.

4. The total time to perform the job is 12 mm INITIATING CUES:

1. Calculate the total dose that the worker will accumulate performing the job

2. Using the total dose, perform an Impact Assessment of the level of risk while performing the task using NPG-SPP-07.1 On Line Work Management, Appendix A On Line Work Management Work Management Process Description.

3. Inform the evaluator when you are complete.

JPM SROA.3 Page 4 of 7 Rev. 0 Start Time STEP 1 Obtain the correct copy of a Survey map.

SAT UNSAT Critical step Standard Examinee discriminates and chooses Survey map A217 U-2 Pipe Chase of the four given.

Provide a copy of the following survey maps:

. Survey map A216 U-i Pipe Chase

&

Survey map A217 U-2 Pipe Chase

Survey map 408 u-i Mixed Bed Valve Gallery

Survey map 417 U-2 Mixed Bed Valve Gallery Comment Examiner Both the unit i and unit 2 Pipe Chase and Mixed Bed Valve Gallery Note survey maps are provided.

Examiner This step is critical because the examinee needs to differentiate between Note survey maps to get the correct results.

JPM SROA.3 Page 5 of 7 Rev. 0 STEP 2 : Calculate the dbse :

SAT UNSAT Critical step Standard Examinee calculates a total dose of 160 mrem will be accumulated performing the task.

Comment Examiner This step is critical because the examinee needs to calculate the Note correct dose to get the correct result from the Impact Assessment.

The work will be performed near valve 2-63-750 Test Conn on RHR Suction from RWST. General area dose rate from survey map A217 Examiner from a hot spot in the area is 800 mr/hr. The job as indicated from the Note initiating cue will take 12 minutes.

800 mrem/hr X 60 mm/i hr ÷ 12 mm = 160 mrem Obtain a copy of NPG-SPP-07.1 On Line Work Management STEP 3 : Appendix A On Line Work Management Work Management Process SAT Description.

UNSAT Copy of NPG-SPP-07. I On Line Work Management Appendix A On Standard: Line Work Management Work Management Process Description is obtained.

Provide a copy of NPG-SPP-07.1 On Line Work Management Appendix A On Line Work Management Work Management Process Description.

Comment

JPM SRO A.3 Page 6 of 7 Rev. 0 Matrix 1 (Impact Assessment)

STEP 4 : SAT Category HIGh Medium I Low Routine Radiation Dose 150 mrem 100 mrem 50 mrem 50 mrem UNSAT Critical Step Standard The examinee performs an impact assessment and determines the risk level to be HIGH due to the projected dose of 150 mrem for the job.

Comment The first matrix (Matrix 1) is used to determine a level of risk in performance of the task. The horizontal axis represents the level of risk, decreasing from left to right. The vertical axis is a list of items for Examiner consideration and includes the traditional risk considerations from risk Note assessment colors and LCO restraints to less traditional risk considerations such as task frequency, worker experience, and task complexity.

(5) Radiation Dose: Setting site-specific thresholds to trigger the need for enhanced preparation and oversight for planned activities is critical in managing overall risk, not only from the standpoint of personnel protection Examiner but also for out-of-service time. Higher dose activities can increase the Note amount of time needed for implementation. Required activities such as ALARA briefings, radiation surveys after components are isolated and drained, and contamination checks for equipment breaches can impact out-of-service time. In addition, worker stay times may be limited by area dose rates or required personnel protective equipment.

Examiner This step is critical because the examinee needs to make the Note determination of high risk in order to achieve the terminal standard.

Terminating The task is complete when the Examinee returns the cue sheet to Cue: the examiner. STOP Stop Time

JPMSROA.3 Page 7 of 7 Rev. 0 JPM BRIEFING SHEET DIRECTIONS TO TRAINEE:

The examiner will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this job performance measure will be satisfied.

INITIAL CONDITIONS:

1. Unit2isinMODE 1

2. You are the WCC SRO and are performing a review of a work package to be merged into the schedule in two weeks.

3. The work is in the vicinity of valve 2-63-750 Test Conn on RHR Suction from RWST located in the Auxiliary Bldg 653 elevation pipe chase.

4. The total time to perform the job is 12 mm INITIATING CUES:

1. Calculate the total dose that the worker will accumulate performing the job

2. Using the total dose, perform an Impact Assessment of the level of risk while performing the task using NPG-SPP-07.1 On Line Work Management, Appendix A On Line Work Management Work Management Process Description.

3. Inform the evaluator when you are complete.

Acknowledge to the examiner when you are ready to begin.

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

Summary of Highest Readiiigs Iap: A2I4LWMF A2IG Unit I Pipe Chase Aiix S3 Smears Air Samples Wipes Survey 110310-7 Surveyed by Arnold. Alonzo J. on 1113OIO at 14

19) 250,000 OPM?100 cm2 p 1 lApproved on: l13:20l0 16:37

20) 100,000 DPM100 cm2 p

18) 100,000 DPM10U cm2 ply

17) 60000 DPMIIOO om2 pi

15) 40000 OPM1D0 om2 py

16) 30000 DPM100 om2 p

8) 20000 OPFvV100 om2 p

3) 20.000 DFMIIOO om2 ply

13) 4000 DPM?100 om2 ply

14) 2000 DFM100 cm2 ply

11) 2000 DPMf100 cm2 ply

12) 1200 DFtW100 om2 ply

9) 1000 DPM/100 om2 ply

7) 1000 DPWIOO om2 p

6) 1000 DFMI100 om2 p

5) 1000 OFM?100 om2 py I 1-VLV-03-ThO 11 Symbol Legend (for example only)

Dose Rate HS-50 I Hot Spot Reading r-Fi5Al Posting

+ T5-30 cm Reading m-r-ii

[_j.e.oerierai 5 4

p Drip Bag

()9mear 1 rSflWle RM L3i

pap: A217.WMF A217 Unit 2 Pipe Chase Aux 653 Surnrnaiy of Hijhest Rediiigs jsuniey 110209-7 Surveyed by Muiins. Annette P. on 11/2:2009 at 15:02 Snears Air Samples & Wipes 4pprove4 on: 11212009 16:10

15) 14008 DPMIIDD cm2 p lMpe 1) <100 CPM

8) 10000 OPM?100 cm2 p pe 2) <100 CPM

7) 2000 IJPIWI0U ern2 p

6) 2000 OPMI0O om2

12) 1000 OPM?100 cm2 p

5) 1000 OPMlOD om2 pi

2) 1000 OPMI100 cm2 p?

14) <1000 DPW100 om2 p

13) <1000 DPMt100 om2 p

11) <1080 0PuV100 cm2 p

10) <1000 DPMI100cm2 p

9) <1000 OFMIOO cm2 p?

4) <1000 DPMIO0 cm2 p

3) <1000 IJPMlOO cm2 p

1) <1000 DFM100 cm2 p?

2-VLV-72-20 Symbol Legend (for example only)

Dose Rite HS-50 Hot Spot Reading I + 7j-O cm Readn 3

DriP Bag Gererl Prea 9mear 4ir SrpI RM f wp

1ap: A448WMF A4H Unit I

- Mixed Bed VaWe lalieiy 1su1iey IOi2I-2O Suieyed by Wood. Bruce R on I12,2Oi at O:4 frLI)I)Iove(I 011 10113,2010 00:I Surnmay of Hijhest Readinjs Smears Air Samples & Wiies

6) 40.000 DFMJ100 om2 py SLI1pe 1) <100 CFM

5) 1000 DPM100 om2 p

4) 1000 DPM100 cm2 p

3) 1,000 DP?W100 om2 p

2) 1000 DPMI0O om2 p [iIRadiaUon Area

1) 1,000 DPM100 om2 p

6) N/I) DPMI0O om2 p

6) <20 DPM100 cm2 a.

Symbol Legend (for example only)

Dose Rate Tl-s-5o Hat Spot 1O.-Cortaot Reading

+ ? 30 cm Readin RCA 1 Posting 20 General Prea Drip Bag 15 9mear 1,,4pr rmpI RM 3wp

Summaiy of HijIiest Readings Smears Air Saniples & Wipes

9) 300,000 DPM10O cm2 p? S1pe 1) <100 CPM 1ap: A417.WMF A417 Mixed Bed Valve 4allery

3) 300000 OPNV100 cm2 p Survey 121609-2 Surveyed 1w Smith Steve L. on l216.2OO9 at 10:09

2) 300000 OPNVI00 cm2 p Approved oti: 12.16.2009 14:16

5) 180000 OPMf100 cm2 p

4) 160,000 DPFW100 om2

1) 120000 OPM100 cm2 p

11) 100,000 DPMfl0Ocm2 p(y

10) 100,000 DPM100 cm2 p(

8) 100,000 0PM100 cm2 pi

6) 100.000 OPM?100 cm2 p

14) 75.000 DFM/100 orn2 p

7) 75,000 0 PM/lOU cm2

12) 60,000 OPMIOO om2 p/y

13) 50,000 0PM/100 cm2 ply

16) 30.000 OPMJ100 cm2 ply

15) 30.000 OPM/100 cm2 ly I II Hqh nt Symbol Legend (for example only)

Dose Rt IHS-50 Hot Spot i l0Coritact Reading Posting

-30 cm Readlnw

[coer.eral Pcea Drip Bag (15) 8mer .*Pr Srripl RM $] p

NPG Standard On Line Work Management NPG-SPP-07.l PrQgrams aud Revs 0003 Processes Page 60 of 169 Appendix A (Page 28 of 32)

On Line Work Management Work Management Process Description For those large component or system outages that are LCO/AOT related, the level of potential impact would dictate the appropriate level of preparation, approval, oversight, and assessment. Matrices 2 and 3 are examples of methods used in the industry to lower risk, minimize out-of-service (OOS) time, and assess performance. The provided methods are guidelines and are not meant to be all inclusive.

They should be used to help develop station programs or enhance existing programs. When dealing with the assessment of managed risk refer to NPG-SPP-07.3 (Work Activity Risk Management Process)

Matrix I (Impact Assessment)

Category High Medium Low Routine PRAIPSA Orange Yellow White Green (1)

Available LCO!AOT Time 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 7 days 14 days > 14 days (2)

Percentage of LCO Time to 75% 50% 25% < 25%

be Used (3)

Maintenance Planned duration Rule 005 Time will result in the 75% of 50% of < 50% of (4) system being in or available time available time available time near A-i_status Radiation Dose 150 mrem 100 mrem 50 mrem < 50 mrem (5)

Generation high low low high consequence I Risk consequence I consequence I consequence I high probability (6) low probability high probability low probability Power Reduction 20% 10% < 10% None (7)

Human First-time task; Infrequently Routine tasks Routine tasks Performance! infrequently performed tasks with personnel with personnel Personnel performed tasks with personnel unfamiliar with familiar with Safety with personnel familiar with the the work the work (8) unfamiliar with the work work Task Multidepartmental Normal inter- Normal inter- Normal inter Complexity support required for departmental departmental departmental (9) many support required support support multidiscipline for several required with required for tasks in parallel multidiscipline few multi- single tasks in parallel discipline tasks discipline tasks in parallel

JPM SRO A.4 Page 1 of 10 Rev. 0 SEQUOYAH NUCLEAR PLANT SRO ADMIN A.4 Evaluate Conditions For Emergency Classification

JPM SRO A.4 Page 2 of 10 Rev. 0 SRO JOB PERFORMANCE MEASURE Task: Evaluate Conditions For Emergency Classification Task#: 3440030302 Task Standard: Classification of Site Area Emergency, EAL Number 1.1.1 P and 1.2.2 P is declared within 15 minutes of starting the task.

The TVA Initial Notification for Site Area Emergency is completed within 10 minutes of event declaration.

Time Critical Task: YES: X NO:

K/A Reference/Ratings: 2.4.41 (4.6)

Method of Testing:

Simulated Performance: Actual Performance: X Evaluation Method:

Simulator In-Plant Classroom X Main Control Room Mock-up Performer:

Trainee Name Evaluator: I Name I Signature DATE Performance Rating: SAT: UNSAT:

Validation Time: 21 mm Total Time:

Performance Time: Start Time: Finish Time:

COMMENTS

JPM SRO A.4 Page 3 of 10 Rev. 0 SPECIAL INSTRUCTIONS TO EVALUATOR:

1. Critical steps are identified in step SAT/U NSAT column by bold print Critical Step.

2. Any UNSAT requires comments.

Tools/EquipmentlProcedures Needed:

1. EPIP- 1, EMERGENCY PLAN CLASSIFICATION MATRIX

2. EPIP-2 NOTIFICATION OF UNUSUAL EVENT

3. EPIP-4, SITE AREA EMERGENCY

4. A clock must be available in classroom that all examinees and evaluator can see

References:

Reference Title Rev No.

tlP-1 EMERGENCY PLAN CLASSIFICATION MATRIX 45 2 EPIP-2 NOTIFICATION OF UNUSUAL EVENT 30

3. EPIP-4 SITE AREA EMERGENCY 32 Read to the examinee:

DIRECTIONS TO TRAINEE:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM. I will provide initiating cues and reports on other actions when directed by you. When you complete the task successfully, the objective for this job performance measure will be satisfied. Ensure you indicate to me when you understand your assigned task. To indicate that you have completed your assigned task return the handout sheet I provided you.

HAND JPM BRIEFING SHEET TO EXAMINEE AT THIS TIME!

INITIAL CONDITIONS:

1. Unit 1 is currently in a NOUE based upon system degradation, 2.1 due to loss of both channels of control room annunciators as well as the annunciator printer and CRT.

2. EPIP-2, NOTIFICATION OF UNUSUAL EVENT is in progress at step 3.2.3

3. Subsequently a Reactor trip occurred

4. Safety Injection actuated and E-1, Loss of Reactor or Secondary Coolant, was entered.

5. FR-C.2, Response to Degraded Core Cooling, is being performed due to an Orange condition on the CSF Status Trees.

6. ICS is available.

7. The ODS is NOT available.

8. The TSC is NOT operational.

9. Emergency Paging System (EPS) is not available in MCR.

10. There are no indications of an Onsite Security Event.

JPM SRO A.4 Page 4 of 10 Rev. 0 INITIATING CUES

1. You are the Emergency Director in the Control Room until the TSC is staffed.

2. Given the initial conditions classify the event using EPIP-1, Emergency Plan Classification Matrix AND complete a TVA Follow up information Form.

3. When you raise your hand you will signify that you have completed the event declaration. At that time the Examiner will provide you with a TVA Notification Form. You will then complete the TVA Notification Form.

4. When you have completed the TVA Notification Form, raise your hand to inform the Examiner you are done.

5. There is an element of this task that is Time Critical.

JPM SROA.4 Page 5 of 10 Rev. 0 Start Time Obtain a copy of EPIP-2 NOTIFICATION OF UNUSUAL EVENT STEP 1 : SAT UNSAT Examinee obtains a copy of EPIP-2 NOTIFICATION OF UNUSUAL Standard:

EVENT.

Provide a copy of EPIP-2 NOTIFICATION OF UNUSUAL EVENT marked c- up through step 3.2.3 Comment Obtain a copy of EPIP-1, EMERGENCY PLAN CLASSIFICATION STEP 2 : MATRIX. SAT UNSAT Examinee obtains a copy of EPIP-1, EMERGENCY PLAN Standard:

CLASSIFICATION MATRIX.

Provide a copy of EPIP-1, EMERGENCY PLAN CLASSIFICATION MATRIX.

Comment

JPM SRO A.4 Page 6 of 10 Rev. 0 INSTRUCTIONS Note: A condition is considered to be MET if, in the judgment of the SED, the Procedure condition will be MET IMMINENTLY (i.e.:

with two hours). The classification shall be made as soon as this determination is made.

STEP 3 : 1. In the matrix to the left, RE\/IEW the SAT initiating conditions in all three barrier columns and circle the conditions that UNSAT are MET.

2. In each of the three barrier columns, IDENTIFY if any Loss or Potential Loss INITIAliNG CONDITIONS have been MET.

Examinee reviews the EMERGENCY PLAN CLASSIFICATION MATRIX Standard: .

and identifies initiating conditions provided in the initial conditions.

Comment

JPM SRO A.4 Page 7 of 10 Rev. 0 STEP 4 : 3. COMPARE the number of barrier . SAT Losses and Potential losses to the criteria below and make the . UNSAT appropriate declaration. - Critical Step Emergency Class Criteria Site Area Emergency LOSS or Potential LOSS of any two barriers The examinee compares barrier losses and classifies the event as a SIte Area Emergency within 15 minutes of starting the task.

Potential LOSS of the Fuel Clad Barrier 1.1.1 due to Core Cooling Orange Standard: (F-C.2) entry and Potential LOSS of the RCS Barrier I .2.2. Non Isolatable RCS leak exceeding the capacity of one charging pump in the normal charging alignment OR RCS leakage results in entry into E-1 .

Comment EXAMINER This is a critical step because of the requirement to arrive at the NOTE: correct classification within 15 minutes.

EXAMINER NOTE: Annotate the stop time for the event classification here.

EXAMINER Examinee continues with the task to complete the State Notification NOTE: Form using EPIP-4, SITE AREA EMERGENCY. The critical time element continues.

EXAMINER NOTE: Annotate the start time for the State Notification here.

EXAMINER NOTE: The start data is provided to the examinee on the JPM briefing sheet.

EXAMINER NOTE: Examinee transitions to EPIP-4 SITE AREA EMERGENCY

JPM SRO A.4 Page 8 of 10 Rev. 0 Obtain a copy of EPIP-4 SITE AREA EMERGENCY STEP 5 : SAT U N SAT Standard: Examinee obtains a copy of EPIP-4, SITE AREA EMERGENCY.

Provide a copy of EPIP-4, SITE AREA EMERGENCY Comment NOTE: IF there are personnel injuries, THEN IMPLEMENT EPIP-1O. Medical Emergency Response.

Procedure Note NOTE: IF there are immediate hazards to plant personnel, THEN consider immediately implementing EPIP-8 Personnel Accountability and Evacuation in parallel with this procedure 3.1 SITE AREA EMERGENCY DECLARATION BY THE MAiN CONTROL ROOM STEP 6 : SAT Upon classifying events as a SITE AREA EMERGENCY the SM/SED shall:

U N SAT

[1] IF TSC is OPERATIONAL, (SED transferred to TSC), THEN GO TO Section 3.2 (Page 7).

[2) RECORD time of Declaration.

[3] ACTIVATE Emergency Paging System (EPS) as follows:

Standard: The examinee addresses steps 3.1.1 through 3.1.3 Comment

JPM SRO A.4 Page 9 of 10 Rev. 0 3.1 SITE AREA EMERGENCY DECLARATION BY THE MAIN CONTROL ROOM STEP 7 : SAT Upon classifying events as a SITE AREA EMERGENCY the SM/SED shall:

[4] COMPLETE Appendix B, TVA Initial Notification for Site Area Emergency. UNSAT The examinee completes an Appendix B, WA Initial Notification for Site Critical Step Standard: Area Emergency with no errors on items noted with an

on the answer key within 10 minutes of event declaration.

EXAMINER This is a critical step because of the requirement to provide notification NOTE: of an event to the state within 10 minutes.

EXAMINER Annotate the stop time for the completion of the state notification form NOTE. here.

Comment Terminating The task is complete when the Examinee returns the cue sheet to ue. the examiner.

Stop Time

JPM SRO A.4 Page 10 of 10 Rev. 0 JPM BRIEFING SHEET DIRECTIONS TO TRAINEE:

The examiner will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this job performance measure will be satisfied.

INITIAL CONDITIONS:

1. Unit 1 is currently in a NOUE based upon system degradation, 2.1 due to loss of both channels of control room annunciators as well as the annunciator printer and CRT.

2. EPIP-2, NOTIFICATION OF UNUSUAL EVENT is in progress at step 3.2.3

3. Subsequently a Reactor trip occurred.

4. Safety Injection actuated and E-1, Loss of Reactor or Secondary Coolant, was entered.

5. FR-C.2, Response to Degraded Core Cooling, is being performed due to an Orange condition on the CSF Status Trees.

6. ICS is available.

7. The ODS is NOT available.

8. The TSC is NOT operational.

9. Emergency Paging System (EPS) is not available in MCR.

10. There are no indications of an Onsite Security Event.

INITIATING CUES:

1. You are the Emergency Director in the Control Room until the TSC is staffed.

2. When you raise your hand you will signify that you have completed the event declaration. At that time the Examiner will provide you with a TVA Notification Form. You will then complete the WA Notification Form.

3. When you have completed the TVA Notification Form, raise your hand to inform the Examiner you are done.

4. There is an element of this task that is Time Critical.

Acknowledge to the examiner when you are ready to begin.

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

r .i.. r iii i. i i.. i 4 I E P I P4 A

,L! APPENDIX B TVA INITIAL NOTIFICATION FOR SITE AREA EMERGENC Y

TVA INITIAL NOTIFICATION FOR SITE AREA EMER GENCY 1 This is a Drill [J This is an Actual Event - Repeat This is an Actual Event

2. This s SED Sequoyah has declared a affecting. SITE AREA EMERGENCY Unit 1 E Unit 2 Both Unit 1 and Unit 2

3. EAL Designator(s): I. lIP 1.1.1 P

4. Brief Description of the Event:

r vv !i$ vi C i2 !)I-.iL je

-L

5. Radiological Conditions: (Check one box under each Airborne AND Liquid column.)

Airborne Releases Offsite

. Minor releases within federally approved limits

Liquid Releases Offsite Minor releases within federally approved limits R Releases above federally approved limits 1 E Releases above federally approved limits 1

Release information not known Release information not known (Tech Specs) (Tech Specs)

6. Event Declared: * *Dt tt(g1IIes TiME

7. Provide Protective Action Recommendation:

D47

NoneE

8. When completed, FAX this information to the ODS or TEMA as required by Sections 3.1 or 3.2.

ODS Fax: 5-751-8620. TEMA Fax: 9-1-615-242-9635

9. Please repeat back the information you have received to ensure accuracy.

FORWARD COMPLETED PROCEDURE TO DArE F P 14 of 15 REVISION 32 EMERGENCY PREPAREDNESS MANAGER

- S

- -w _ S TENNESSEE VALLEY AUTHORITY SEQUOYAH NUCLEAR PLANT EMERGENCY PLAN IMPLEMENTING PROCEDURE EPIP2 NOTIFICATION OF UNUSUAL EVENT REVISION 30 PREPARED BY: BILL PEGGRAM RESPONSIBLE ORGANIZATION: EMERGENCY PREPAREDNESS APPROVED BY: RUSSELL THOMPSON EFFECTIVE DATE: 12/21/2010 LEVEL OF USE: REFERENCE USE QUALITY-RELATED i pg es 0

Revision History Rev Date Pages Rviseci Reason for Revision - -

20 08/26/2002 Corrections, editorials and pagination cleanup. Clarified step 3.1, Step 3 to avoid redundancy. This is a intent revision.

21 10/22/2002 Revised to remove activation of the TSC/OSC at the NOUE. This is an intent revision.

22 04/22/2003 General revision to restructure EPIP for better flow. Moved ODS notification earlier in procedure. Added EPIPs 6, 7 & 16 as references.

Intent revision.

23 06/26/2003 Non intent change. Correct typo on phone number.

24 10/23/2003 4, ,

Intent change. Added step to record time of declaration upon entry into the procedure. Split step that had two actions in one step. Specified Security implement EPIP-1 1 25 04/22/2004 Intent change. Added guidance to use EPIP-6 Appendix B for guidance 11 when briefing NRC on ENS line.

26 09/23/2004 Intent change. Removed TEMA satellite phone number. Removed one 5 7 10 cell No. and added Nextel Nos. for EP.

27 04/26/2006 Revision Change: replaced SSI-1 with SSI-7.1. Replaced the EP Mgr 4 10 12 13 names and phone numbers with a reference to the weekly REP duty list.

Changed App.B, Step 9 from being the time and date info was provided to the ODS to faxing App. B to the ODS. Made App. C consistent with App.

by putting THIS IS A DRILL before THIS IS A REAL EVENT.

28 01/23/2007 Plan effectiveness determinations reviews indicate the following revisions 6 10 do not reduce the level of effectiveness of the procedure or REP:

Annual review. Added to announce NOUE on old plant PA, 4800 bridge Revised responsibility of dose assessment from Chemistry to RP.

29 02/19/2010 Plan effectiveness determinations reviews indicate the following revisions 12 do not reduce the level of effectiveness of the procedure or REP:

Annual review. PER162926-001-Added additional directions to contact TEMA to Step 9 of App B.

30 12/21/2010 Plan effectiveness determinations reviews indicate the following revisions 4 5 12 13 do not reduce the level of effectiveness of the procedure or REP:

Annual review. Revised title of NPG-SPP-03.5. Revised the title of EPIP 10, PER 226308-001. Moved faxing the ODS App. B ahead of calling the ODS to expedite the notification PER167954-008. Reversed steps 8 and 9 on Appendix B. Added ODS and TEMA Fax numbers to Step 8 of Appendix B. Reordered steps 1 1 and 12 of Appendix C to reflect faxing the ODS or CECC Director prior to following up with submission of Appendix C.

FORWARD COMPLETED PROCEDURE TO PAGE 2 of 13 REVISION 30 EMERGENCY PREPAREDNESS MANAGER

Table of Contents 1 .0 PURPOSE .....................

4 -

2.0 REFERENCES

.4 3.0 INSTRUCTIONS 3.1 Activation of the Emergency Plan 4 3.2 Monitor Conditions 4 3.3 Termination of the Event 6 8

4.0 RECORDS RETENTION 4.1 Records of Classified Emergencies 9 4.2 Drill and Exercise Records 9 9

5,0 ILLUSTRATIONS AND APPENDICES 5.1 Appendix A, Notifications and Announcements 9 5.2 Appendix B, TVA Initial Notification NOUE 10 5.3 Appendix C, NOUE Follow-up Information 12 13 FORWARD COMPLETED PROCEDURE TO PAGE 3 of 13 REVISION 30 EMERGENCY PREPAREDNESS MANAGER

1.0 PURPOSE IA To provide, a method for t[my notifications ofapprop [ate-+ndividuals or organizations when the Shift Manager (SM)/Site Emergency Director (SED) has determined by EPIP-1 that events have occurred that are classified as a NOUE.

1.2 To provide the SED/SM a method for periodic reanalysis of current conditions to determine whether the NOUE should be terminated or continued.

2.0 REFERENCES

2.1 Interface Documents

[1] NPGSPP-03.5, Regulatory Reporting Requirements

[2] EPIP-3, Alert

[3] EPIP-4, Site Area Emergency

[4] EPIP-5, General Emergency

[5] EPIP-6, Activation and Operation of the Technical Support Center

[6] EPIP-7, Activation and Operation of the Operations Support Center, OSC

[7] EPIP8, Personnel Accountability and Evacuation

[8] EPIP-10, Medical Emergency Response

[9] EPIP-13, Dose Assessment

[10] EPIP-14, Radiation Protection Response

[11] EPIP-16, Termination and Recovery

[12] CECC EPIP-9, Emergency Environmental Radiological Monitoring Procedures

[13] SSI-7.1, Post Requirements and Responsibilities, Central and Secondary Alarm Stations 3.0 INSTRUCTIONS 4 NOTE: J IF there are personnel injuries, THEN IMPLEMENT EPIP-lO, Medical Emergency

_ Response.

ff) IF there are immediate hazards to plant personnel, THEN consider immediately implementing EPIP-8 Personnel Accountability and Evacuation in parallel with this procedure.

3.1 ACTIVATION OF THE EMERGENCY PLAN Upon classifying events as an NOUE the SM/SED shall:

71% RECORD Time of Declaration.

Time FORWARD COMPLETED PROCEDURE TO PAGE 4 of 13 REVISION 30 EMERGENCY PREPAREDNESS MANAGER

31 ACTIVATION OF THE EMERGENCY PLAN (Continued)

I t4$O$jY ODS should be notified within 5 minutes after declaration of the event.

COMPLETE Appendix B, TVA Initial Notification for NOUE. V FAX completed Appendix B to the ODS.

Initial Time 5-751-8620 (Fax)

CALL ODS and READ completed Appendix B.

ODS: Ringdown Line or 7

L

° 170 5 or 5-751-2495 or 9-785-1700 MONITOR for confirmation call from ODS that State/Local notifications complete: RECORD time State notified.

Notification Time

[5] IF ODS CANNOT be contacted within 10 minutes of the 1 declaration, THEN

[a] CONTACT Tennessee Emergency Management Agency (TEMA) and READ completed Appendix B.

Initial Time, 9-1-800-262-3300 or 9-1-615-741-0001

[b] FAX completed Appendix B to TEMA.

9-1-615-242-9635 (Fax)

PERFORM Appendix A, Notifications and Announcements.

(Delegate as needed.)

FORWARD COMPLETED PROCEDURE TO PAGE 5 of 13 REVISION 30 EMERGENCY PREPAREDNESS MANAGER

3.2 MONITOR CONDITIONS V MONITOR radiatiorr monitors. V K [2] WHEN indication exists of an unplanned radiological release, THEN ENSURE Dose Assessment is performed. U

[a] IF the CECC has not assumed Dose Assessment responsibility, THEN NOTIFY Radiation Protection to perform a dose assessment using EPIP-13, Dose Assessment AND PROVIDE the following information:

1. Type Of Event (SGTR!L, LOCA, WGDT, Cntmt Bypass)

2. Release Path (SG/PORV, Aux, ShId, Turb, Serv, Cond)

3. Expected Duration (If unknown assume 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months duration) 7865(RP Lab) or 6417(RP Lab) or Use REP Call List to contact a qualified individual in RP, who is onsite, to perform the dose assessment J) MONITOR plant conditions:

EVALUATE using EPIP-1:

1. IF conditions satisfy criteria of ALERT(s) or higher classification, THEN initiate EPIP-3, EPIP-4, or EPIP-5 as appropriate. U

2. IF additional conditions satisfy criteria of other NOUE(s) THEN Complete Appendix C.

3. IF conditions warrant a need for follow-up information, THEN complete Appendix C. U

[b] IF plant conditions warrant, THEN ACTIVATE assembly and accountability using EPIP-8.

FORWARD COMPLETED PROCEDURETO PAGE 6 of 13 REVISION 30 EMERGENCY PREPAREDNESS MANAGER

. SEQUOYAH EMERGENCY PLAN CLASSIFICATION MATRIX EPIP-1 1.1 Fuel Clad Barrier 1.2 RCS Barrier I 1. Critical Safety Function Status 1. Critical Safety Function Status LOSS Potential LOSS Potential LOSS Core Cooling F<ed Core Cooling Orange Not Applicable Pressurized Thermal (FR-C.1) (FR-C.2) Shock Red (FR-P.1)

OR OR Heat Sink RED (FR-Hi) and RHR Shutdown Heat Sink RED (FR-Hi)

Cooling not in service and RHR Shutdown

-OR- -

Cooling not in service

2. Primary Coolant Activity Level -OR 1.i* Potential LOSS 2. RCS Leakage I LOCA RCS sample activity is Not Applicable .I* Potential LOSS greater than 300 uCilgm RCS leak results in Non Isolatable RCS leak dose equivalent 1131 subcooling <40 °F as exceeding the capacity

-OR- indicated on Xl-94-101 of one charging pump in

3. lncore Thermocouple Hi Quad Average or 102 (EXOSENSOR) the normal charging LOSS Potential_LOSS alignment Greater than 1200 °F on Greater than or equal to Xl-94-101 or 102 700 °F on Xl-94-101 or OR (EXOSENSOR) 102 (EXOSENSOR)

-OR- RCS leakage results in 4 Reatnr VcsI Wr Level entry into E-1 LOSS Potential_LOSS Not Applicable VALID RVLIS level -OR I Steam nritnr Tiib Rupture

<42% on Ll-68-368 or Ll-68-371 with no RCP LOSS Potential_LOSS running SGTR that results in a Not Applicable

-OR- Safety Injection

5. Containment Radiation Monitor actuation

I* Potential LOSS VALID reading of OR Not Applicable greater than:

Entry into E-3 2.8E+01 Rem/hr on RM-90-271A or -272A -OR-4.

OR LOSS Potential_LOSS VALID FVLIS level Not Applicable 2.9E+01 Rem/hr on <42% on Ll-68-368 or RM-90-273A or -274A Ll-68-371 with no RCP (see instruction note 4) running

-OR -OR-

6. SED Judgment 5. SED Judgment Any condition that, in the judgment of the SM or Any condition that, in the judgment of the SM or SED, indicates loss or potential loss of the Fuel SED, indicates loss or potential loss of the RCS Clad Barrier comparable to the conditions listed Barrier comparable to the conditions listed above. above.

Page 9 of 47 Revision 45

ML112160582

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