Text

Initial Exam 2011-302 Final Administrative JPMs
	ML12167A015
Person / Time
Site:	Turkey Point
Issue date:	06/15/2012
From:	; Division of Reactor Safety II
To:	; Florida Power & Light Co
References
	50-250/11-302, 50-251/11-302
	Download: ML12167A015 (670)
	v • d • e

{{#Wiki_filter:_______________ Appendix C Job Performance Measure Form ES-C-I Worksheet Facility: Turkey Point Task No: 01046031100 Calculate Number of Gallons of Primary Water Required to Raise Power Task

Title:

from 80% to 100% JPM No: 01046031104 K/A

Reference:

G2.1 .25 RO 3.9 SRO 4.2 Examinee: NRC Examiner: Facility Evaluator: Date: Method of Testing: Classroom Simulated Actual Performance Performance Yes Classroom X Simulator Plant HAND JPM BRIEFING SHEET TO EXAMINEE AT THIS TIME! Read to the examinee: I 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:

Unit 3 has been at 80% Power for 96 hours.
Rod Height: D-188
Boron Concentration: 1200 ppm
Core Burnup: 4,000 MWD/MTU Desired Conditions after Power Increase:
Reactor Power: 100%
Rod Height: D-228 Initiating Cue:
You have been directed to determine the desired boration or dilution for a Unit 3 power change from 80-100%.

2011 NRC Exam (RO) JPM-A.1.a NUREG 1021 Rev 9 Appendix C

Appendix C Page 2 of 20 Form ES-C-I Task Standard: o Calculates Number of Gallons of Primary Water Required to Raise Power from 80%-l00%. Final value must fall between 853 gallons and 1026 gallons. Actual value determined on a calculator is 1026 gallons. Required Materials:

Calculator Plant Curve Book, Section 2 o 0-OP-046, CVCS Boron Concentration A 1

Contro ttachment l5 Reactivity Worksheet General

References:

1. 3--GOP-305, Hot Standby To Cold Shutdown

2. Plant Curve Book

3. 0-OP-046, CVCS Boron Concentration Control Time Critical Task: No Validation Time: 35 minutes 2011 NRC Exam (RO) JPM-A. l.a NUREG 1021 Rev 9 Appendix C

1MULAToRsp Not Applicable 2011 NRC Exam (RO)JPM-Ala NUREG 1021 Rev9AppendjxC

Appendix C Page 4 of 20 Form ES-C-I Denote critical steps with a check mark (q) Start Time STEP I SAT Obtain required reference materials. U N SAT Applicant obtains a copy of O-OP-046, CVCS Boron Concentration Control, Attachment 5, and the Plant Curve Book, STANDARD Section 2. Provide Applicant with a copy of O-OP-046, CVCS Boron Concentration Control, Attachment 5, and the Plant Curve Book, C UE Section 2. COMMENT 2011 NRC Exam (RO) JPM-A.1.a NUREG 1021 Rev 9 Appendix C

Appendix C Page 5 of 20 Form ES-C-I Calculate the Rod Worth (A). SAT Rod Worth (A): UNSAT o Plant Curve Book, Section 2, Figure 5 (Do not interpolate between graphs.)

            . For power changes in Mode 1, use Hot Full Power numbers STEP 2         (equilibrium xenon.)

q o For power changes in Mode 2, use Hot Zero Power numbers (no xenon.)

            . Withdrawal rods   = plus (+) reactivity

Insert rods = minus (-) reactivity (0-OP-046, Attachment 5, Step 1)

From Plant Curve Book, Section 2, Figure 5 (for 4,000 MWD/MTU): Determines 80% value (D-188) is 90 pcm for HFP. Enters +90 pcm in the Present Rod Worth blank in Step I of Attachment 5. STANDARD Determines 100% value (D-228) is 0 pcm. Enters 0 pcm in the Desired Rod Worth blank in Step 1 of Attachment 5. Applicant subtracts the Desired Rod Worth from the Present Rod Worth and enters the difference of +90 pcm in the (A) blank in Step I of Attachment 5. CUE COMMENT 2011 NRC Exam (RO)JPM-A.1.a NUREG 1021 Rev9AppendixC

Appendix C Page 6 of 20 Form ES-C-I STEP 3 Sign the Performed By blank STANDARD Applicant signs name in the Performed By blank in Step 1 of Attachment 5. EVALUATOR CUE: CUE Another operator will verify the calculations when you are complete. COMMENT 2011 NRC Exam (RO) JPM-A.1.a NUREG 1021 Rev9AppendixC

Appendix C Page 7 of 20 Form ES-C-I Calculate the Power Defect (B). SAT Power Defect (B): UNSAT STEP 4 o Plant Curve Book, Section 2, Figure 6A q

Raise Power = minus (-) reactivity
Lower Power = plus (+) reactivity (0-OP-046, Attachment 5, Step 2)

From Plant Curve Book, Section 2, Figure 6A (for 4,000 MWD/MTU): Applicant determines 80% value (1200 ppm) is 1296. Enters 1296 in the Present Pwr Defect blank in Step 2 of Attachment 5. STANDARD Applicant determines 100% value (1200 ppm) is 1582. Enters 1582 in the Desired Pwr Defect blank in Step 2 of Attachment 5. Applicant subtracts the Desired Pwr Defect from the Present Pwr Defect and enters the difference of -286 in the (B) blank in Step 2 of Attachment 5. CUE COMMENT 2011 NRC Exam (RO) JPM-A. l.a NUREG 1021 Rev 9 Appendix C

Appendix C Page 8 of 20 Form ES-C-I STEP 5 Sign the Performed By blank STANDARD Applicant signs name in the Performed By blank in Step 2 of Attachment 5. CUE COMMENT 2011 NRC Exam (RO) JPM-A.1.a NUREG 1021 Rev9AppendixC

Appendix C Page 9 of 20 Form ES-C-I Calculate the Desired Change in pcm (C). STEP 6 SAT q UNSAT (O-OP-046, Attachment 5, Step 3) Applicant enters +90 in the (A) blank in Step 3 of Attachment 5. Applicant enters -286 in the (B) blank on Step 3 of Attachment STANDARD 5. Applicant adds the (A) and (B) values and enters the sum of

    ..      -196 in the (C) blank in Step 3 of Attachment 5.

CUE COMMENT 2011 NRC Exam (RO) JPM-A.1 .a NUREG 1021 Rev 9 Appendix C

Appendix C Page 10 of 20 Form ES-C-I STEP 7 Sign the Performed By blank STANDARD Applicant signs name in the Performed By blank in Step 3 of Attachment 5. CUE COMMENT 2011 NRC Exam (RO) JPM-A.1 .a NUREG 1021 Rev9AppendixC

Appendix C Page II of 20 Form ES-C-I NOTE I For at-power load changes, this step will produce boration or dilution required amounts that I can deviate by a factor of two or more from the amounts given by the Reactivity I Manipulation Table provided by Reactor Engineering. This is due to the inclusion of NOTE I Xenon-135 effects in the Reactivity Manipulation Table which are not provided for the I determination made in this step. Addition of the dilution or boration amounts is I recommended to be done in an incremental fashion if no Reactivity Manipulation Table is I provided by Reactor Engineering. I I Calculate Integral Boron Worth. SAT Integral Boron Worth: UNSAT

            . Plant Curve Book, Section 2, Figure 7A
            . Boration       =  minus     (-)  reactivity STEP 8     e   Dilution     =   plus (+) reactivity
    *\J Calculate Desired Boron Concentration (CB) as follows:

Check current boron concentration (CB) (O-0R046, Attachment 5, Step 4) STANDARD Applicant enters given value of 1200 in the blank beside Check current boron concentration (CB). CUE COMMENT 2011 NRC Exam(RO)JPM-A.1.a NUREG 1021 Rev9AppendixC

Appendix C Page 12 of 20 Form ES-C-I Determine Present boron worth. STEP9 SAT (0-OP-046, Attachment 5, Step 4) H UNSAT From Plant Curve Book, Section 2, Figure 7A (for 4,000 MWD/MTU): STANDARD Applicant determines that the boron worth for 1200 ppm is 10674 and enters 10674 in the Present boron worth from Sect 2, Fig 7A blank in Step 4 of Attachment 5. CUE COMMENT 2011 NRC Exam (RO) JPM-A.1.a NUREG 1021 Rev 9 Appendix C

Appendix C Page 13 of 20 Form ES-C-I Calculate Desired boron worth. STEP 10 (O-OP-046, Attachment 5, Step 4) Applicant enters -196 in the (C) blank in Step 4 of Attachment 5. STANDARD Applicant determines Desired boron worth by subtracting the (C) value of -196 from the Present boron worth of -10674. Applicant enters the difference of -10478 in the Desired boron worth blank in Step 4 of Attachment 5. CUE COMMENT 2011 NRC Exam (RO) JPM-A.1.a NUREG 1021 Rev9AppendixC

Appendix C Page 14 of 20 Form ES-C-I Determine Desired C . 8 STEP 11 SAT UNSAT (0-OP-046, Attachment 5, Step 4) From Plant Curve Book, Section 2, Figure 7A (for 4,000 MWD/MTU): Applicant determines Desired boron concentration by interpolating between 10424 and 10507 on the table. STANDARD . Applicant enters 1176-1180 in the blank beside Determine desired CB from Section 2, Figure 7A on Attachment 5. CUE

                . The Desired born worth, calculated in Step 4 of Attachment 5, is -10478.

o On Figure 7A, this falls between the range of 10507 and 10424. o 1050710424= 83. c 1047810424= 54. e 54/83 = 0.6506. e 1180-1170=10. COMMENT a 10 x 0.6506 = 6.506. a 1170+6.506= 1176 Calculation on Step 5 of Attachment 5 and Explanation of Tolerances: Gurrnt in ppm 5O79O x in [ Current CE Ifl ppm ] = 5O79O < 1 (( t176 1200

            =  50,790 x In [1.0204081632] = 50,790 X .0202027073175              =

1026.0955 gallons (rounded down to 1026) 2011 NRC Exam (RO) JPM-A. l.a NUREG 1021 Rev 9 Appendix C

Appendix C Page 15 of 20 Form ES-C-I STEP 12 Sign the Performed By blank STANDARD Applicant signs name in the Performed By blank in Step 4 of Attachment 5. CUE COMMENT 2011 NRC Exam (RO) JPM-A.1.a NUREG 1021 Rev9AppendixC

Appendix C Page 16 of 20 Form ES-C-I NOTE I 50790 is the nominal volume of the RCS and the CVCS. BAST ppm is the most recent I i BAST concentration or a nominal value of 5664 ppm.

              ---------------------I STEP 13 Determine if a dilution or a boration is required.

q Applicant compares the Desired Boron Concentration to the Current Boron Concentration. STANDARD Applicant determines that Desired Boron Concentration (1176 - 1 1 80) is less than Current Boron Concentration (1200) and goes to Step 5 of Attachment 5. CUE COMMENT 2011 NRC Exam (RO) JPM-A.1.a NUREG 1021 Rev 9 Appendix C

Appendix C Page 17 of 20. Form ES-C-I r°; NOTE I 50, 790 is the nominal volume of the RCS and the CVCS. EAST ppm is the most recent BAST concentration or a nominal vaiue of 5664 ppm. Calculate Gallons of Primary Water for the dilution. STEP 14 SAT UNSAT (0-OP-046, Attachment 5, Step 5) Applicant enters 1200 in the Current CB in ppm blank in the equation in Step 5 of Attachment 5. Applicant enters 1176 -1180 in the Desired CB in ppm in the equation in Step 5 of Attachment 5. STANDARD Applicant then solves the equation for Gallons. Enters between 853 and 1026 gallons in the blank before Gallons in Step 5 of Attachment 5. (See Key for explanation of tolerances.) CUE COMMENT 2011 NRC Exam (RO) JPM-A.1.a NUREG 1021 Rev9AppendixC

Appendix C Page 18 of 20 Form ES-C-I STEP 15 Sign the Performed By blank. STANDARD Applicant signs name in the Performed By blank in Step 5 of Attachment 5. TERMINATING CUE: CUE The JPM is complete when the Applicant returns the JPM Briefing Sheet to the Evaluator. COMMENT Stop Time 2011 NRC Exam (RO)JPM-A.1.a NUREG 1021 Rev 9 Appendix C

Appendix C Page 19 of 20 Form ES-C-I Verification of Cnmpietiam Job Performance Measure No. 01046031104 Examinees Name: Examiners Name: Date Performed: Facility Evaluator: Number of Attempts: Time to Complete: Question Documentation: Question:

Response

Result: Satisfactory/Unsatisfactory Examiners signature and date: 2011 NRC Exam (RO) JPM-A.1.a NUREG 1021 Rev 9 Appendix C

JPM BRIEFING SHEET I 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:

Unit 3 has been at 80% Power for 96 hours.
Rod Height: D-188
Boron Concentration: 1200 ppm
Core Burnup: 4,000 MWD/MTU Desired Conditions after Power Increase:
Reactor Power: 100%
Rod Height: D-228 Initiating Cue:
You have been directed to determine the desired boration or dilution for a Unit 3 power change from 80-100%.

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. 2011 NRC Exam (RO) JPM-A.1.a NUREG 1021 Rev9AppendixC

JPM BRIEFING SHEET I 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 wifl be satisfied. Initial Conditions:

Unit 3 has been at 80% Power for 96 hours.
Rod Height: D-188
Boron Concentration: 1200 ppm
Core Burnup: 4,000 MWD/MTU Desired Conditions after Power Increase:
Reactor Power: 100%
Rod Height: D-228 Initiating Cue:
You have been directed to determine the desired boration or dilution for a Unit 3 power change from 80-100%.

Acknowledge to the examiner when you are ready to begin. HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU HAVE SATISFACTORILY COMPLETED THE ASSIGN ED TASK. 2011 NRC Exam (RO) JPM-A.1 .a NUREG 1021 Rev 9 Appendix C

ATTACHMENT 5 (Page 1 of3) REACTIVITY WORKShEET PART 1: Power Change Only

1) Rod Worth (A)

Plant Curve Book, Section 2, Figure 5 (Do not interpolate between graphs.) For power changes in Mode 1, use Hot Full Power numbers (equilibrium xenon.) For power changes in Mode 2, use Hot Zero Power numbers (no xenon.) Withdrawal rods plus (+) reactivity Insert rods = minus (-) reactivity Calculate change in rod worth as follows: [ pcmj Present Rod Worth [ pcmj Desired Rod Worth

                                                        &-) 90       pcm
                                                    =   (+1-)    (A)

Performed by Verified by

2) Power Defect (B)

Plant Curve Book, Section 2, Figure 6A Raise Power minus (-) reactivity Lower Power = plus (+) reactivity Calculate change in power defect as follows: [ipcm] - [l$Z=pcrn] = (4 pcm Present Pwr Defect - Desired Pwr Defect (+1-) (B) Performed by Verified by

3) Calculate the Desired Chan2e in pcm (C)

[G-) 2 pcm ]+ [(+ = (O LI 1 pcm (A) (B) (C) Performed by Verified by W2003:TNM/mr/mr/ds

ATTACHMENT 5 (Page 2 of 3) REACTWITY WORKSHEET NOTE I For at-power load changes, this step will produce boration or dilution required amounts that can deviate by a factor of two or more from the amounts given by the Reactivity Manipulation Table provided by Reactor Engineering. This is due to the inclusion of Xenon-135 effects in the Reactivity Manipulation Table which are not provided for the I determination made Th this step. Addition of the dilution or boration amounts is I i recommended to be done in an incremental fashion if no Reactivity Manipulation Table is provided by Reactor Engineering.

4) Integral Boron Worth Plant Curve Book, Section 2, Figure 7A Boration minus (-) reactivity Dilution = plus (+) reactivity Calculate Desired Boron Concentration (CB) as follows:

Check current boron concentration (CB) = ppm [(-) (O(o7f pcm].. { (-f-s pcmj = +i t Present boron worth (C) = Desired boron worth from Sect 2, Fig 7A Determine desired CB from Section 2, Figure 7A = 1 i7 I I .9 ppm Performed By Verfled By a a I NO I 50,790 is the nominal volume of the RCS and the CVCS. BAST ppm is the most recent BAST concentration ora nominal value of 5664 ppm.

      *aa                                                                             1

5) IF desired Boron Concentration is less than the current Boron Concentration, THEN calculate the dilution required as follows:

50,790 x ln [ Current CB in ppm Gallons of Primary L Desired CB in ppm 50,790 x ln r 1aCt ppm L I 17b O 1 0 ppm J bGa1lons Gallons of Primary Water Performed By Ver,fled By W2003:TNM/mr/mr/cis

ATTACHIvIENT 5 (Page 3 of 3) REACTIVITY WORKSHEET

6) II? desired Boron Concentration is higher than the current Boron Concentration, THEN calculate the boration required as follows:

AST ppm] [Cunent RCS ppm 50,790 x In I Gal of Boric Acid [BAST ppm] [Desired RCS ppmjj ppm] [ - RCS ppnj 50,790 x In I H Gallons L[ ppm] - [_____ RCS ppmjj Gal of Boric Acid Performed By Verified By PART 2: Temperature Change Only

1) Temperature change requirements To raise temperature, refer to Plant Curve Book, Section 3, Figure 2B.

To lower temperature, refer to Plant Curve Book, Section 2, Figures 9 and 9A. Determine desired temperature change: (+1-) °F To dilute: [________

                                  °F] x   [________

gal/°F] = gal Water Sect 3, Fig 2B To borate: [________

                                  °F] x   [_______

pcml°F] pcm Sect 2, Fig 9/9A [________ pcm] x {gallpcm] gal of Boric Acid Performed By Verified By W2003:TNM/mr/mr/cls

ATTACHMENT 5 (Page 1 of 3) REACTIVITY WORKSHEET PART 1: Power Change Only

1) Rod Worth (A)

Plant Curve Book, Section 2, Figure 5 (Do not interpolate between graphs.) For power changes in Mode 1, use Hot Full Power numbers (equilibrium xenon.) For power changes in Mode 2, use Hot Zero Power numbers (no xenon.) Withdrawal rods = plus (+) reactivity Insert rods minus (-) reactivity Calculate change in rod worth as follows: [ pcm] pcm] = (+/-1-) pcm Present Rod Worth Desired Rod Worth = (+1-) (A) Performed by Verified by

2) Power Defect (B)

Plant Curve Book, Section 2, Figure 6A Raise Power minus (-) reactivity Lower Power plus (+) reactivity Calculate change in power defect as follows: { pcm] - [ pcm] = (+1-) pcm Present Pwr Defect - Desired Pwr Defect = (+/-1-) (B) Performed by VerUied by

3) Calculate the Desired Change in pcm (C)

[(+1-) pcm] + [(+1-) pcm I = (+1-) pcm (A) (B) (C) Performed by VerUied by W2003:TNM/mr/mr/cls

ATTACHMENT 5 (Page 2 of 3) REACTIVITY WORKSHEET NOTE I For at-power load changes, this step will produce boration or dilution required amounts that I I can deviate by a factor of two or more from the amounts given by the Reactivity I Manipulation Table provided by Reactor Engineering. This is due to the inclusion of I Xenon- 135 effects in the Reactivity Manipulation Table which are not provided for the U I determination made in this step. Addition of the dilution or boration amounts is I recommended to be done in an incremental fashion if no Reactivity Manipulation Table is I provided by Reactor Engineering. I II

4) Integral Boron Worth Plant Curve Book, Section 2, Figure 7A Boration minus (-) reactivity

Dilution plus (+) reactivity

Calculate Desired Boron Concentration (C ) as follows: 8 Check current boron concentration (CB) = ppm [(-) - pcm I [(+1-) pcm 1 (+/-1-) pcm Present boron worth (C) = Desired boron worth from Sect 2, Fig 7A Determine desired CB from Section 2, Figure 7A = ppm Performed By VerifIed By _. a a C = C C = a a a I 50,790 is the nominal volume of the RCS and the CVCS. BAST ppm is the most recent BAST concentration or a nominal value of 5664 ppm. I C a = a = I

5) IF desired Boron Concentration is less than the current Boron Concentration, THEN calculate the dilution required as follows:

Current CB in ppm 50,790 x ln Gallons of Primary L Desired CB in ppm ppm 50,790 x in ppm = Gallons Gallons of Primary Water Performed By VerijIed By W2003:TNM/mr/mr/cls

ATTACHMENT 5 (Page 3 of 3) REACTIVITY WORKSHEET

6) IF desired Boron Concentration is higher than the current Boron Concentration, THEN calculate the boration required as follows:

rBAST ppm] [Cuffent RCS 50,790 x in = Gal of Boric Acid [BAST ppm] [Desired RCS ppmjj 50,790 x in r[ ppm] ppm] [ [_____ RCS ppm] Gallons RCS ppm)) Gal of Boric Acid Performed By Verified By PART 2: Temperature Change Only

1) Temperature change reguirements To raise temperature, refer to Plant Curve Book, Section 3, Figure 2B.

To lower temperature, refer to Plant Curve Book, Section 2, Figures 9 and 9A. Determine desired temperature change: (+1-) °F To dilute: [________

                                 °F] x   [________

gal/°F] = gal Water Sect 3, Fig 2B To borate: [ °F] x [ pcm/°F] = pcm Sect 2, Fig 9/9A pcm] x [gal/pcm] gal of Boric Acid Performed By Verfled By W2003:TNM/mr/mr/cls

Appendix C Job Performance Measure Form ES-C-I Worksheet Facility: Turkey Point Task No: 01201001100 Evaluate Overtime Task

Title:

Requirements JPM No: 01201001102 KlA

Reference:

G2.1.5 R02.9 SRO3.9 Examinee: NRC Examiner: Facility Evaluator: Date: Method of Testing: Classroom Simulated Actual Performance Performance X Classroom X Simulator Plant HAND JPM BRIEFING SHEET TO EXAMINEE AT THIS TIME! Read to the examinee: I 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:

Units 3 and 4 are both at 100%.
Itis 10/05/11 at0530.
The Field Supervisor is filling vacancies on shift and is evaluating the overtime requirements for two Reactor Operators.
Both Reactor Operators had THREE (3) days off prior to 10/02/11.
Their normal work schedule is 8 hr day shift.
Average previous rolling work is 8.00 hours/shift.
EmpCenter is unavailable.

Initiating Cues:

Refer to the attached proposed work schedules.
Based on the work hours provided, identify the work hour limitations violated, if any.
Prior to the proposed schedules, assume these covered workers have maintained status as Operations covered workers and have maintained minimum days off.
No waivers are permitted.

2011 NRC Exam RO & SRO JPM-A.1 .b NUREG 1021 Rev 9 Appendix C

Appendix C Page 2 of II Form ES-C-I Question I: Based on the work hours provided, identify the work hour limitations violated, if any by RO #1 between 9/30/11 through 10/05/11? Question 2: Based on the work hours provided, identify the work hour limitations violated, if any, for RO#2 between 10/06/11 and 10/07/11? Task Standard:

The Applicant identifies the limitations for Reactor Operator #1 and Reactor Operator #2 in accordance with AD-AA-1 01-1004, Work Hour Controls.

Required Materials:

AD-.AA-101-1004, Work Hour Controls General

References:

AD-AA-101-1004, Work Hour Controls Time Critical Task: No Validation Time: 30 minutes 2011 NRC Exam RO & SRO JPM-Ai .b NUREG 1021 Rev 9 Appendix C

I Appendix C Page 3 of 11 Form ES-Cfj SIMULATOR SETUP NOT Afrplicable 2011 NRC Exam RO & SRO JPM-A.1.b NUREG 1021 Rev 9 Appendix C

Appendix C Page 4 of II Form ES-C-I Denote critical steps with a check mark (J) Start Time Question I: Based on the work hours provided, identify the work hour STEP I limitations violated, if any by RO #1 between 9/30/11 through j 10/05/11? For Reactor Operator #1, the candidate identifies the work hours were violated due to: STANDARD

At least a 10 hour break between successive work periods, or an 8 hour break when a break of less than 10 hours is necessary to accommodate a crews scheduled transition between work schedules or shifts.

EVALUATOR CUE: CUE Provide the Applicant with a copy of AD-AA-101-1004, Work Hour Controls. COMMENT EVALUATOR NOTE: NOTE See worksheet for schedule calculations. 2011 NRC Exam RO & SRO JPM-A.1 .b NUREG 1021 Rev 9 Appendix C

Appendix C I Page 5 of II Form ES-C-I I Question 2: Does RO #2 meet work hour limitations to cover the shifts STEP 2 between 10/06/11 and 10/07/11? For Reactor Operator #2, STANDARD Applicant identifies that the proposed schedule would exceed the limit of 72 hours in a 7 day (168 hours) period. CUE COMMENT EVALUATOR NOTE: NOTE See worksheet for schedule calculations. Stop Time 2011 NRC Exam RO & SRO JPM-A.1.b NUREG 1021 Rev9AppendixC

Appendix C Page 6 of 11 Form ES-C-I KEY TO FOLLOW-UP QUESTIONS: Question 1: Based on the work hours provided, identify the work hour limitations violated, if any by RO #1 between 9/30/11 through 10/05/11? The work hour limitation violated is:

No more than 16 work hours in any 24 hour period.
No more than 26 work hours in any 48 hour period.
No more than 72 work hours in any 7 day (168 hour) period.
At least a 10 hour break between successive work periods, or an 8 hour break when a break of less than 10 hours is necessary to accommodate a crews scheduled transition between work schedules or shifts.
A 34 hour break in any 216 hour period.

Question 2: Based on the work hours provided, identify the work hour limitations violated, if any by RO # 2 between 9/30/11 through 10/05/11? The work hour limitation violated is:

No more than 16 work hours in any 24 hour period.
No more than 26 work hours in any 48 hour period.
No more than 72 work hours in any 7 day (168 hour) period.
At least a 10 hour break between successive work periods, or an 8 hour break when a break of less than 10 hours is necessary to accommodate a crews scheduled transition between work schedules or shifts.
A 34 hour break in any 216 hour period.

2011 NRC Exam RO & SRO JPM-A.1 .b NUREG 1021 Rev 9 Appendix C

Appendix C I Page 7 of II Form ES-C-I Verification of Completion: Job Performance Measure No. 01201001102 Examinees Name: Examiners Name: Date Performed: Facility Evaluator: Number of Attempts: Time to Complete: Question Documentation: Question:

Response

Resu It: Satisfactory/Unsatisfactory Examiners signature and date: 2011 NRC Exam RO & SRO JPM-A.1 .b NUREG 1021 Rev 9 Appendix C

Appendix C Page 8 of II Form ES-C-I JPM RIEFIN SHT I 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:

Units 3 and 4 are both at 100%.
Itis 10/05/11 at0530.
The Field Supervisor is filling vacancies on shift and is evaluating the overtime requirements for two Reactor Operators.
Both Reactor Operators had THREE (3) days off prior to 10/02/11.
Their normal shift is 8 hours day shift.
Average previous rolling work is 8.00 hours/shift.
EmpCenter is unavailable.

Initiating Cues:

Refer to the attached proposed work schedules.
Given the proposed work schedules for Reactor Operator #1 and Reactor Operator #2, answer the questions below.
Prior to these proposed schedules, assume these covered workers have maintained status as Operations covered workers and have maintained minimum days off.
No waivers are permitted.

2011 NRC Exam R0&SROJPM-A.1.b NUREG 1021 Rev9AppendixC

I Appendix C Page 9 of II Form ES-C-I Question I: Based on the work hours provided, identify the work hour limitations violated, if any by RD #1 between 9/30/11 through 10/05/11? Question 2: Based on the work hours provided, identify the work hour limitations violated, if any, for RO#2 between 10/06/11 and 10/07/11? 2011 NRC Exam RO & SRO JPM-A.1 .b NUREG 1021 Rev 9 Appendix C

Appendix C Page 10 of II Form ES-C-I REACTOR OPERATOR #1 Date Hours Applicant Notes Notes Worked 9/27/11 OFF 9/28/11 OFF 9/29/11 OFF 9/30/1 1 0630-1900

30 minute turnover 1

s t

Forced CT to cover half of Peakshift 10/1/11 0630-1500
30 minute turnover After Shift:
At 1930, the RO was called at home to answer other questions relating to the investigation.
The call lasted 15 minutes.

10/2/1 1 0630-1900

30 minute turnover 1

s t

Forced CT to cover half of Peakshift 10/3/1 1 0630-1500
30 minute turnover 10/4/11 0630-2300
30 minute turnover
Forced CT to cover Peakshift 10/5/11 0630-1500
30 minute turnover.

10/6/1 1 0630-1500

30 minute turnover
Voluntary CT to cover Dayshift 10/7/11 0630-1500
30 minute turnover
Voluntary CT to cover Dayshift 2011 NRC Exam RO & SRO JPM-A.1 .b NUREG 1021 Rev 9 Appendix C

Appendix C I Page II of II I Form ES-C-I REACTOR OPERATOR #2 Date Hours Applicant Notes Notes Worked 9/27/Il OFF 9/28/11 OFF 9/29/11 OFF 9/30/1 1 0630-1500

30 minute turnover 10/1/11 0230-1 530
30 minute turnover

                                                  . Forced CT to cover Midshift
                                                  . Relief showed up 30 minutes late After Shift:
                                                  . Between 1600 and 2030, received 2 phone call related to an event investigation.
                                                  . The phone calls were 15 minutes and 10 minutes in duration.

10/2/11 0630-1900

30 minute turnover
Forced CT to cover first half of Peakshift 10/3/1 1 0630-1900
30 minute turnover

                                                  . Forced CT to cover first half of Peakshift 10/4/1 1  0630-1900

30 minute turnover
Forced CT to cover first half of Peakshift 10/5/11 CFF 10/6/11 0630-1900
30 minute turnover
Voluntary CT to cover Dayshift and first half of Peakshift 10/7/1 1 0630-1900
30 minute turnover
Voluntary CT to cover Dayshift and first half of Peakshift 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. 2011 NRC Exam RO & SRO JPM-A.1.b NUREG 1021 Rev 9 Appendix C

Appendix C Page 8 of II Form ES-C-I JPM BRIEFING SHEET I 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:

Units 3 and 4 are both at 100%.
Itis 10/05/11 at 0530.
The Field Supervisor is filling vacancies on shift and is evaluating the overtime requirements for two Reactor Operators.
Both Reactor Operators had THREE (3) days off prior to 10/02/11.
Their normal shift is 8 hours day shift.
Average previous rolling work is 8.00 hours/shift.
EmpCenter is unavailable.

Initiating Cues:

Refer to the attached proposed work schedules.
Given the proposed work schedules for Reactor Operator #1 and Reactor Operator #2, answer the questions below.
Prior to these proposed schedules, assume these covered workers have maintained status as Operations covered workers and have maintained minimum days off.
No waivers are permitted.

2011 NRC Exam RO & SRO JPM-A.1.b NUREG 1021 Rev 9 Appendix C

Appendix C Page 9 of II I Form ES-C-I 1 Question 1: Based on the work hours provided, identify the work.-hour limitations violated, if any by RO #1 between 9/30/11 through 10/05/11? The work\hour limitation violated, if any, is:

No qore than 16 work hours in any 24 hour period.
No me than 26 work hours in any 48 ho r period.
No moithan 72 work hours in any 7 d (168 hour) period.
At least a\t0 hour break between SUC9 ssive work periods, or an 8 hour break when a break of les\than 10 hours is neces,%ary to accommodate a crews schedu led transition between wor1chedules or shifts./
A34hourbrealsnanY216ho/eriod.

                                                                          /    I,s Question 2:

Based on the work hours provk tify the work hour limitations violated, if any, for RO#2 between 10/06/11 and 1 0/07/1/1? ( The work hour limitation vjlated, if any,

No more than 16/york hours in any 2\1our period.
No more than work hours in any 48 hr period.

o No more thaV72 work hours in any 7 day 18 hour) period.

At least a 1 G hour break between successivewprk periods, or an 8 hour break when a break of les than 10 hours is necessary to acc&mrnodate a crews schedu led transition between work schedules or shifts.

e A34 hoL(r breaks in any 216 hour perid. 2011 NRC Exam RO & SRO JPM-A.1.b NUREG 1021 Rev AnnenHi (

Appendix C Page 10 of 11 Form ES-C-I REACTOR OPERATOR #1 Daté Hours AppIicantNotes ; Nótes Worked 9/27/11 OFF 9/28/1 1 OFF 9/29/11 OFF 9/30/1 1 0630-1900

30 minute turnover 1

s t

Forced CT to cover half of Peakshift 10/1/11 0630-1500
30 minute turnover AfterShift:
At 1930, the RO was called at home to answer other questions relating to the investigation.

                                          . The call lasted 15 minutes.

10/2/11 0630-1900

30 minute turnover jst
Forced CT to cover half of Peakshift 10/3/1 1 0630-1500
30 minute turnover 10/4/1 1 0630-2300
30 minute turnover
Forced CT to cover Peakshift 10/5/1 1 0630-1500
30 minute turnover.

10/6/11 0630-1500

30 minute turnover
Voluntary CT to cover Dayshift 10/7/11 0630-1500
30 minute turnover
Voluntary CT to cover Dayshift 2011 NRC Exam RO & SRO JPM-A.1.b NUREG 1021 Rev 9 Appendix C

Appendix C Page II of II Form ES-C-I REACTOR OPERATOR #2 Date Hours 1 ApplicantNó tóS , Notes (

    -       Worked                   .                                                  I 9/27/11   OFF 9/28/11   OFF 9/29/11   OFF 9/30/11   0630-1 500

30 minute turnover 10/1/1 1 0230-1530
30 minute turnover
Forced CT to cover Midshift
Relief showed up 30 minutes late After Shift:
Between 1600 and 2030, received 2 phone call related to an event investigation.
The phone calls were 15 minutes and 10 minutes in duration.

10/2/1 1 0630-1 900

30 minute turnover
Forced CT to cover first half of Peakshift 10/3/11 0630-1900
30 minute turnover
Forced CT to cover first half of Peakshift 10/4/1 1 0630-1900
30 minute turnover
Forced CT to cover first half of Peakshift 10/5/11 CFF 10/6/1 1 0630-1900
30 minute turnover
Voluntary CT to cover Dayshift and first half of Peakshift 10/7/1 1 0630-1900
30 minute turnover
Voluntary CT to cover Dayshift and first half of Peakshift 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. 2011 NRC Exam RO & SRO JPM-A.1.b NUREG 1021 Rev 9 Appendix C

REACTOROPERATO-R#1 Date Schedule Notes Comments 9/30/1 1 0630-1900

30 minute turnover 12.0 hours st 1
Forced CT to cover half of 30 minute turnover does not count.

Peakshift (AD-AA-1 01-1004, Step 4.1.2.1) 12 hours in the last 24. 10/1/11 0630-1500

30 minute turnover 9.0 hours 30 minute turnover does not count.

After Shift: 1 hour holdover counts Phone call does not count since it

                   . At 1930, the RC was called at      was less than 30 minutes. (AD-AA home to answer other questions    101-1004, Step 4.1.2.4) relating to the investigation. 13 hours in last 24 (1500-1 500)
                   . The call lasted 15 minutes.        21 hours in last 48 10/2/11  0630-1 900

30 minute turnover 12.0 hours st 1

                   . Forced CT to cover         half of 30 minute turnover does not count.

Peakshift 12 hours in last 24 (1 900-1 900) 21 hours in last 48 10/3/11 0630-1 500

30 minute turnover 8.0 hours 30 minute turnover does not count.

13 hours in last 24 (1500-1500) 20 hours in last 48 10/4/1 1 0630-2300

30 minute turnover 16.0 hours.

                   . Forced CT to cover Peakshift      30 minute turnover does not count.

16 hours in the 24 24 hours in last 48

                                                         <10 hour break between 10I4 @

2300 and 10/5 c 0630. Must either be relieved at 2030 on 1014 or come in no earlier than 0900 on 10I5, or process a Waiver. 10/5/11 0630-1500

30 minute turnover. 6.0 hours 30 minute turnover does not count.

If RC comes in at 0900 on 10/5: 0900-1 500 = 6 hours 14 hours in last 24 22 hours in the last 48 63 in the last 7 days (9/29 was an off day) 10/6/1 1 0630-1500

30 minute turnover
Voluntary CT to cover Dayshift 10/7/1 1 0630-1500
30 minute turnover 8.0 hours
Voluntary CT to cover Dayshift 30 minute turnover does not count.

8 hours in the last 24 8 hours in last 48 56 in the last 7 days

REACTOR OPERATOR #2 Date Schedule Notes Comments 9/30/11 0630-1 500

30 minute turnover 8.0 hours 30 minute turnover does not count.

8 hours in last 24 (1 500-1 500) 10/1/11 0230-1530

30 minute turnover 12.5 hours
Forced CT to cover Midshift Late relief counts
Relief showed up 30 minutes 30 minute turnover does not count.

late Phones calls for event investigation do not count, since they totaled less than After Shift: 30 minutes. Total 25 minutes. 12.5 hours in last 24 (1 530-1 530)

Between 1600 and 2030, 21.5 in last 48 received 2 phone call related to an event investigation.
The phone calls were 15 minutes and 10 minutes in duration.

10/2/11 0630-1900

30 minute turnover 12.0 hours
Forced CT to cover first half of 30 minute turnover does not count.

Peakshift 12.0 hours in last 24 (1 900-1 900) 24.5 hours in last 48. 10/3/11 0630-1900

30 minute turnover 12.0 hours
Forced CT to cover first half of 30 minute turnover does not count.

Peakshift 12.0 hours in last 24 (1 900-1 900) 24.5 hours in last 48 10/4/11 0630-1900

30 minute turnover 12.0 hours
Forced CT to cover first half of 30 minute turnover does not count.

Peakshift 12.0 hours in last 24 (1900-1 900) 24.0 hours in last 48 10/5/11 CFF 10/6/11 0630-1 900

30 minute turnover 12.0 hours
Voluntary CT to cover Dayshift 30 minute turnover does not count.

and first half of Peakshift 12.0 hours in last 24 (1900-1900) 12.0 hours in last 48 68.5 hours in last 7 days. 10/7/11 0630-1900

30 minute turnover 12.0 hours
Voluntary CT to cover Dayshift 30 minute turnover does not count.

and first half of Peakshift 12 hours in last 24 (1900-1 900) 24 in the last48 725 hours in last 7 days. Must arrive no earlier than 0800 or must leave no later than 1730. AD-AA-1O1-1004, Step 4.3.1:

NOTE The periods of 24 hours, 48 hours and 72 hours are considered rolling time periods. Rolling means the period is not re-zeroed or reset following a day off or after obtaining authorization to exceed 10 CFR 26 overtime limits. The 24 hours, 48 hours, 7 days (168 hours), and 216 hours do not restart after a day off; the period continues to roll.

No more than 16 work hours in any 24 hour period.
No more than 26 work hours in any 48 hour period.
No more than 72 work hours in any 7 day (168 hour) period.
At least a 10 hour break between successive work periods, or an 8 hour break when a break of less than 10 hours is necessary to accommodate a crews scheduled transition between work schedules or shifts.
A 34 hour break in any 216 hour period.

Minimum Days Off: Since both of the operators are on 8-hour shifts, Table 1, Online Minimum Days Off (Step 4.3.2) requires a minimum of I day off per week.

Procedure No. NUCLEAR FLEET ADAAI 01-1004 NEXTera ENERQ. PROCEDURE Revision No. NON-SAFETY RELATED 7 INFORMATION_USE

Title:

WORK HOUR CONTROLS Responsible Department: LICENSING Special Considerations: FOR IN FORMATION ONLY Before use, verify revision and change documentation (if applicable) with a controlled index or document. DATE VERIFIED________ INITIAL________ Revision Approved By Approval Date UNIT # DATE DOCT PROCEDURE 0 Pete Wells 1/22/09 DOCN AD-AA-1 01-1 004 SYS STATUS COMPLETED 7 James Peschel 05/11/11 REV 7

                                                                           # OF PGS

EVTSfON NO.: PRCEbLiFE iitLE - PAGE: WORK HOUR CONTROLS 2 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET REVISION

SUMMARY

Rev. No. Description 7 Revises Steps 4.1.1.3/.4 associated with holdover time and early arrivals to align with 10 CFR 26.205(b)(1) Work Hours. (AR01645435 M. Dryden) 6 Corrected references. 5 This revision incorporates editorial changes, lessons learned, and operating experience for clarification of 10 CFR 26 Subpart I requirements. 4 This revision incorporates lessons learned from the Fatigue Rule Pilot program for clarification of 10 CFR 26 Subpart I requirements. 3 Editorial to add NOTE regarding Pilot Waiver statement in section 4.4. Placed on HOLD during Pilot Program. 2 This revision is a complete rewrite of procedure to comply with 10 CFR 26 Subpart I. No revision bars used according to AD-AA-1 00-1 003 (rewrite) 1 Editorial to delete reference to St. Lucie procedure ADM-15.04, Fitness For Duty Call Out And For Cause Testing, in section 6.4 and add reference to FFD-12, For Cause Drug And Alcohol Testing, and FFD-14, Call In Testing to section 6.4. This is necessary due to cancellation of ADM-15.04 0 Initial Issuance.

REV1SOf NO.: PRCEDURE TITLE: -

                                                        -        PAGE:

WORK HOUR CONTROLS 3 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET TABLE OF CONTENTS SECTION PAGE 1.0 PURPOSE 4 2.0 TERMS AND DEFINITIONS 6 3.0 RESPONSIBILITIES 11 4.0 INSTRUCTIONS 15 4.1 Calculating Work Hours 15 4.1.1 Time to be Included in Work Hour Calculation 15 4.1.2 Time to be Excluded in Work Hour Calculation 18 4.2 Transitioning to Covered Work OR between Covered Groups 19 4.3 Work Hour Limits 21 4.3.1 Work Hour Limits Regardless of Unit Status 21 4.3.2 Online Minimum Days Off 21 4.3.3 Outage Minimum Days Off 22 4.4 Request to Deviate from Work Hour Limits 23 4.5 Annual Review 26 5.0 REPORTING 28 6.0 RECORDS REQUIRED 29

7.0 REFERENCES

AND COMMITMENTS 30 ATTACHMENTS ATTACHMENT I GUIDELINES FOR COVERED WORK 33 ATTACHMENT 2 INCIDENTAL DUTIES RECORD 36 ATTACHMENT 3 WAIVER REQUEST 37 ATTACHMENT 4 EXAMPLE WORK HOUR RECORD 39 ATTACHMENT 5 WORK HOUR RECORD 40

PVISIO N0.: - ROEOUE iTL: - - PAGE: WORK HOUR CONTROLS 4 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET 1.0 PURPOSE 1.1 General

1. This procedure implements the requirements of 10 CFR 26 Subpart I for controlling work hours to prevent situations in which fatigue could reduce the mental alertness or decision-making capability of personnel.

2. This procedure does not apply during declared emergencies as defined in any FPL I NextEra Energy emergency plan. FPL I NextEra Energy will hereafter be referred to as NextEra.

3. Work hour requirements can be suspended when informed in writing by the NRC that these requirements, or any subset of, are waived for security personnel in order to assure the common defense and security, for the duration of the period defined by the NRC.

REVISION NO.: PROCEDURE TITLE: PAGE: WORK HOUR CONTROLS 5 of 40 PROCEDURE NO.: AD-AA-1O1-1 004 NUCLEAR FLEET 1.2 Scope NOTE For workers who normally perform the following duties, all work hours will be calculated as time worked. Workers will not typically move in or out of a Covered Worker status except for extended work assignments such as shared resources during outages. Work Hour Controls shall apply to workers who perform the following duties: (Attachment 1 provides additional guidance on determination of this population):

1. Operating or on-site directing of the operation of structures, systems or components (SSC) determined to be of high safety significance. The determination of the safety significance of an SSC shall be determined using the Maintenance Rule risk assessment process.

2. Radiation Protection or Chemistry duties required as a member of the on-site emergency response organization minimum shift complement.

3. Directing or performing maintenance of structures, systems or components (SSC) determined to be of high safety significance. The determination of the safety significance of an SSC shall be determined using the Maintenance Rule risk assessment process described in each sites procedures. The personnel who perform these duties may include contractors with unescorted access, radiation protection, and Chemistry personnel.

4. Fire Brigade member responsible for understanding the effects of fire and fire suppressants on safe shutdown capability (Fire Brigade Leader).

5. Armed security force officer, alarm station operator, response team leader or watchperson (i.e. Security Personnel).

REV1S1OsS NO.: OCb1JE 11tLE: PAGE: WORK HOUR CONTROLS 6 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET 2.0 TERMS AND DEFINITIONS

1. Acute fatigue: Fatigue from causes (e.g., restricted sleep, sustained wakefulness, task demands) occurring within the past 24 hours.

2. Conditions Adverse to Safety or Security: Unforeseen conditions which, in the informed opinion of the duty Shift Manager, could jeopardize the safety of the public, station, personnel, or environment. Waivers are considered appropriate if required to mitigate conditions adverse to safety. If rule compliance would result in the following type conditions, it would be appropriate to consider using the waiver process:

Compliance with the work hour requirement would violate other NRC requirements such as minimum on-site staffing.
Compliance with the work hour requirement would delay recovery from any situation that has placed the unit in an orange or red risk classification as determined by the 10CFR5O.65 program..

o Compliance with the work hour requirement would cause a forced Reactor shutdown, power reduction, or similar action as a result of exceeding a time limit for a Technical Specifications Limiting Condition for Operation.

Compliance with the work hour requirement would cause or prevent mitigation of an environmental permit violation.

o Compliance with the work hour requirement would cause delay in recovering from actual or potential loss of reactor core cooling capability during outages.

Compliance with the work hour requirement would compromise the industrial or radiological safety of the public or plant personnel.
Compliance with the work hour requirement would compromise the ability to maintain the site secure from the actions of malicious groups or persons.
Compliance with the work hour requirement would force undue risk to on-site or off-site station personnel as a consequence of an external event (e.g., security, fire, severe weather).

3. Alertness: The ability to remain awake and sustain attention.

4. Break: An interval of time that falls between successive work periods, during which no duties are performed for NextEra other than one period of shift turnover at either the beginning or end of a shift but not both.

REV11ON NO.: PROCEDURE 11TLE: PAGE WORK HOUR CONTROLS 7 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET 2.0 TERMS AND DEFINITIONS (continued)

5. Business Travel: Travel required by the company to a work location other than the workers normal work location.

6. Call-in: Returning to the nuclear plant site when not normally scheduled for work.

7. Circadian variation in alertness and performance: The increases and decreases in alertness and cognitive I motor functioning caused by human physiological processes (e.g., body temperature, release of hormones) that vary on an approximately 24-hour cycle.

8. Contractor I vendor (CN): Any company, or any individual not an employee of NextEra, who is providing work or services to NextEra, either by contract, purchase order, oral agreement, or other arrangement.

9. Covered Work:

Operating or on-site directing of the operation of structures, systems or components (SSC) determined to be of high safety significance. The determination of the safety significance of an SSC shall be determined using the Maintenance Rule risk assessment process.
Radiation Protection or Chemistry duties required as a member of the on-site emergency response organization minimum shift complement.
Maintenance or on-site directing of maintenance of structures, systems or components (SSC) determined to be of high safety significance. The determination of the safety significance of an SSC shall be determined using the Maintenance Rule risk assessment process described in each sites procedures. The personnel who perform these duties may include contractor with unescorted access, Radiation Protection, and Chemistry personnel.

a Fire Brigade member responsible for understanding the effects of fire and fire suppressants on safe shutdown capability (Fire Brigade Leader).

Armed security force officer, alarm station operator, response team leader or watchperson (i.e. Security Personnel).

10. Covered Worker: Any worker granted unescorted access to a nuclear power plant protected areas performing Covered Work.

11. Cumulative Fatigue: The increase in fatigue over consecutive sleep-wake periods resulting from inadequate rest.

REVISION NO.: POCEUkE titLE: - PAGE: WORK HOUR CONTROLS 8 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET 2.0 TERMS AND DEFINITIONS (continued)

12. Day-off: A calendar day in which an individual does not start a work shift.

13. Deviation: A departure from the requirements specified in 10CFR26 Subpart I.

14. Directing: The exercise of control over an operations or maintenance work activity by an individual who is directly involved in the execution of the work activity, and either makes technical decisions for that activity without subsequent technical review, or is ultimately responsible for the correct performance of that work activity. Directing only applies when the work being performed is covered work, this then makes the directing covered work as well.

15. Eight (8) -hour shift schedule: A schedule that averages not more than 9 hours per workday over the entire shift cycle.

16. Fatigue Management software: Software used as a tool for scheduling and tracking time worked for covered workers.

17. Fatigue: The degradation in an individuals cognitive and motor functioning resulting from reasons such as bodily or mental exertion or inadequate rest.

18. Incidental duties: Unscheduled work activities required by NextEra performed off-site. Activities include phone calls and teleconferences supporting outages, emergent issues, and performance of emergent analysis performed while off-site. After hours study time is not included as an incidental duty.

19. Increased threat condition: An increase in protective measure level, relative to the lowest protective measure level applicable to the site during the previous 60 days, as promulgated by an NRC advisory.

20. Intervening Hours: Time between the end of a scheduled work shift and beginning of a call-in period or the hours between the end of a call-in period and beginning of a scheduled work shift.

21. Maintenance: On-site maintenance activities including modification, surveillance, post-maintenance testing, corrective and preventive maintenance.

22. Maintenance Rule: The maintenance rule process represents the integration and coordination of a broad range of equipment reliability activities into one process for plant personnel to : evaluate important station equipment, monitor equipment performance and condition; provide direct input for the implementation of long-term equipment health plans, and make continuing adjustments to preventive maintenance tasks and frequencies based on trend data and equipment operating experience.

RVTSION sSO.: OCEDURE tItL: - . PAGE: WORK HOUR CONTROLS 9 of 40 PROCEDURE NO.: AD-AA-101-.1 004 NUCLEAR FLEET 2.0 TERMS AND DEFINITIONS (continued)

23. Nominal: The limited flexibility that is permitted in meeting a scheduled due date for completing a recurrent activity that is required under 10 CFR 26, such as the nominal 12-month frequency required for FFD refresher training.

Completing a recurrent activity at a nominal frequency means that the activity may be completed within a period that is 25 percent longer or shorter than the period required in 10 CFR 26. The next scheduled due date would be no later than the current scheduled due date plus the required frequency for completing the activity.

24. Online: Status of the plant when connected to the electrical grid.

25. Outage: Status of the plant when disconnected from the electrical grid.

26. On-site: Within the owner controlled area of the nuclear power plant.

27. Off-site: Any area not considered on-site.

28. Protected area: The area inside the security fence line. Access to this area requires a badge allowing access that is issued by security.

29. Security personnel: Armed security force officer, alarm station operator, response team leader, or watchperson.

30. Security System Outage: The loss of sufficient components and operatiohal capabilities of the security system that adversely affects securitys ability to provide resources required for compensatory measures to comply with physical security and safeguards contingency plans. These planned or unplanhed outages could be the result of equipment degradation I failure, adverse weather conditions, loss of power, or structural damage to the security system.

31. Shift cycle: A series of consecutive work shifts and days off that is planned to repeat regularly, thereby constituting a continuous shift schedule. A shift cycle cannot exceed 6 weeks for the purposes of calculating days off.

32. Shift turnover: Only those activities that are necessary to safely transfer information and responsibilities between two or more individuals between shifts.

Shift turnover activities may include, but are not limited to, discussions of the status of plant equipment, the status of ongoing activities, such as extended tests of safety systems and components and arming I disarming for security officers. A shift turnover shall not exceed 1 hour.

33. Tactical exercise: A force-on-force simulation used to evaluate and demonstrate the capability to defend target sets against selected attributes and characteristics of an adversary.

REV1S1ONNO.: PROCEDURET1TLE: AE: 3 I WORK HOUR CONTROLS 10 of 40 PROCEDURE NO.: AD-Ak-101-1 004 NUCLEAR FLEET 2.0 TERMS AND DEFINITIONS (continued)

34. Ten (10)-hour shift schedule: A schedule that averages more than 9 hours, but not more than 11 hours, per workday over the entire shift cycle.

35. Twelve (12)-hour shift schedule: A schedule that averages more than 11 hours per workday over the entire shift cycle.

36. Unplanned Outage: Shutdown that is initiated less than 72 hours following the discovery of an off-normal condition. Unplanned shutdowns include those conducted in response to equipment failures or personnel errors and those conducted to perform maintenance.

37. Waiver: An approved request to deviate from work hour limits of Section 4.3.

38. Work Hours: The amount of time a worker performs duties for NextEra.

Activities included and excluded from this time are outlined in Section 4.1.

39. Work Hour Controls: The regulatory requirements specified in 10 CFR 26.205.

40. Work Period: The scheduled or unscheduled amount of continuous work hours from when an individual starts to perform duties for NextEra until when they stop. A work period can also be referred to as a shift period or work shift. (e.g.

A scheduled work time from 06:00 to 18:00 including turnovers, breaks, and lunches is a work period.)

VIONNO.: - PROCEDURE TITLE: PAGE: WORKHOURCONTROLS 11 of 40 PROCEDURE NO.: AD-AA-1 01-1 004 NUCLEAR FLEET 3.0 RESPONSIBILITIES

1. The Plant General Manager or a site senior level manager with requisite signature authority is responsible for:

A. Determining that a waiver is necessary to mitigate or prevent a condition adverse to safety. B. Evaluating staffing levels to ensure individual work hours can be managed with the objective of preventing impairment from fatigue due to the duration, frequency, or sequencing of successive shifts. C. Communicating the requirements of this procedure to appropriate personnel. D. Ensuring a review is performed at least once per year, in accordance with Section 4.5.

2. The Security Manager or a site senior level manager with requisite signature authority is responsible for:

A. Determining that a waiver is necessary to maintain site security. B. Evaluating staffing levels to ensure individual work hours can be managed with the objective of preventing impairment from fatigue due to the duration, frequency, or sequencing of successive shifts.

3. All Managers and Supervisors are responsible for:

A. Designating covered or non-covered status for new employees, transferred employees, or shared resources. For those to be designated as a covered worker, the designation must be made prior the worker performing any covered work. B. Ensuring workers covered status, plant site, department, and supervisor is accurately documented in the Fatigue Management software, as applicable, prior to the worker performing any covered work.

4. Licensing Managers are responsible for:

A. Providing oversight for rule implementation and procedure interpretation and determination of adequacy of associated software, including future changes.

REVISiOiJ NO. - OCEDU TITLE: - - PAGE: WORK HOUR CONTROLS 12 of 40 PROCEDURE NO.: AD-AA-1 01-1 004 NUCLEAR FLEET 3.0 RESPONSIBILITIES (continued)

5. Information Management is responsible for:

A. Implementing and maintaining the configured software to meet the business requirements including coordinating the testing of the software with the business and the vendor.

6. Manager or Supervisor of Covered Workers is responsible for:

A. Ensuring workers status (i.e. covered status, plant site, department, and supervisor) and schedules are accurately updated in Fatigue Management software prior to beginning any covered work. B. Ensuring Fatigue Management software is updated for schedule changes such as personnel sickness, call-ins, vacation, or overtime prior to the hours being taken off or worked. C. Initiating a waiver as necessary for workers deviating from work hour limits and ensuring the waiver is completed and approved before the individual performs work.

0. Evaluating a persons fitness to deviate from work hour limits by performing a face-to-face assessment per Attachment 1.

E. Evaluating the employees performance and continued fitness-for-duty while working under a waiver. F. Attaching approved waivers in Fatigue Management software when software is utilized for tracking time. G. Ensuring approved waivers are captured in the applicable condition reporting system. H. Communicating the requirements of this procedure to appropriate personnel within his/her department. I. Scheduling the work hours of covered workers consistent with the objective of preventing impairment from fatigue due to the duration, frequency, or sequencing of successive shifts.

EVIION NO.: OOEDURE TITLE: - - - - PAGE: WORK HOUR CONTROLS 13 of 40 PROCEDURE NO.: AD-M-101-1 004 NUCLEAR FLEET 3.0 RESPONSIBILITIES (continued)

6. (continued)

J. Documenting covered worker shift schedules and actual work hours, that are not being tracked and stored in the sites Fatigue Management software, in a Routine Work Tracking item in the applicable corrective action program or submitting the required records to Records Management in accordance with site requirements on an annual basis. For covered workers where the sites Fatigue Management software is utilized to track and store the schedules and work hours, a Routine Work Tracking item is not required. K. Evaluating staffing levels to determine if they are adequate to ensure work hours can be managed with the objective of preventing impairment from fatigue due to the duration, frequency, or sequencing of successive shifts. L. Documenting any evaluation of projects or tasks for the purpose of determining if the work is considered covered or not in a condition report (CR) or other retrievable format. M. Tracking work related telephone calls in accordance with Attachment 2 and incorporating data in Fatigue Management software when software is utilized for tracking time. N. Generating a Condition Report to document each deviation. (Section 7.2 Commitment I and 2)

7. Site Technical Representatives (or associated Contract Coordinator) are responsible for:

A. Designating covered or non-covered status of contract workers. B. Informing contractors of Fatigue Management and work hour control requirements. C. Ensuring work hour limits are followed and initiating a waiver if required. Also ensuring that waiver is approved prior to individual performing work.

0. Ensuring proper documentation of contractor work hours including, at a minimum, all information listed on Attachment 4. Attachment 5 may be used, as applicable.

E. Documenting any evaluation of projects or tasks for the purpose of determining if the work is considered covered or not in a condition report (CR) or other retrievable format.

ViSiON JO.: - OEbURE TITLE: PAGE: WORK HOUR CONTROLS 14 of 40 PROCEDURE NO.: AD-AA-1O1-1 004 NUCLEAR FLEET 3.0 RESPONSIBILITIES (continued)

7. (continued)

F. Documenting contractor covered worker schedules and actual work hours, that are not being tracked and stored in the sites Fatigue Management software, in a Routine Work Tracking item in the applicable corrective action program or submitting the required records to Records Management in accordance with site requirements within 60 days of the contractors termination of unescorted access or annually, which ever comes first. For covered contractor workers where the sites Fatigue Management software is utilized to track and store the schedules and work hours, a Routine Work Tracking item is not required.

8. Each employee (NextEra or contractor) is responsible for:

A. Understanding fatigue rule status (i.e. covered worker) and responsibilities associated with this categorization B. Evaluating his/her personal fitness to work based on impairment from fatigue and managing his/her work hours consistent with the objective of preventing impairment from fatigue. C. Making a self-declaration of fatigue in accordance with SY-AA-1 00-1011, Fatigue Management, and discussing his/her concerns with supervision or management in cases when he/she feels his/her performance may be impaired. D. Monitoring and reporting concerns related to other individuals fitness to work based on impairment from fatigue (i.e. behavioral observation program).

9. Covered workers (NextEra or contractor) are responsible for:

A. Being aware of his/her total hours worked in the previous 14 days and notifying management if work hour limits will be exceeded if asked to work additional hours. B. Ensuring Fatigue Management software is updated, as applicable, for schedule changes such as personal sick leave, call-ins, vacation, or scheduled overtime prior to the hours being taken off or worked.

10. Each sites access authorization supervisor is responsible for A. Including the Section 5 reporting requirements in the annual FFD report and for periodically transmitting required records to records management department

EVIION NO.: PROCEDURE TITLE: PAGE:

WORK HOUR CONTROLS 15 of 40 PROCEDURE NO.: AD-A-1O1-1 004 NUCLEAR FLEET 4.0 INSTRUCTIONS 4.1 Calculating Work Hours 4.1.1 Time to be Included in Work Hour Calculation

1. Any break time during the work period including lunch time.

2. Business Travel time. The cumulative travel time for the most direct route shall be utilized and can be estimated by flight times, Google maps, Mapquest, etc.

Personal travel breaks for sight seeing, visits, etc. are not to be included in the cumulative travel time. A. Overnight stays travel time from the workers home to the hotel and travel time from the hotel back to the workers home. B. Single day travel time to and from the temporary work location from the workers starting location (home, usual work location, other temporary work location, etc.).

3. Shift holdovers to cover for late arrivals of incoming shift members; early arrivals of individuals for meetings, training, or pre-shift briefings for special evolutions; and holdovers for interviews needed for event investigations.

NOTE

A 10 hour break between the end of the previous work period and the start of the incidental duty period is not required.

o A 10 hour break between the end of the incidental duty period and the start of the next work period where covered work will be performed is required.

4. Incidental duties totaling greater than 30 minutes between each work period (e.g. 3-20 minute phone calls) count toward work time and work periods. The cognizant supervisor shall complete Attachment 2.

Example 1: An individual performs covered work for 10 hours (0700 - 1700) and goes home. At 2200 he/she receives a call from work and talks for 1 hour until 2300 pm.

A 10 hour break prior to receiving the phone call is not required.
Intervening hours are not applicable with incidental duty time. The hours from 1700 through 2200 do not count with respect to calculating hours worked.

EVISION iiO.: - OOOURE TITLE: PAGE: WORK HOUR CONTROLS 16 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET 4.1.1 Time to be Included in Work Hour Calculation (continued)

4. (continued)

The individual worked a total of 11 hours with the work period ending at 2300.
The individual cannot return to work at 0700 the next day; he/she would not meet the 10-hour break requirement. The individual could begin work at 0900 the next day.

Example 2: An individual is on a day off and is required to talk with licensee personnel at the plant on 3 occasions, with each call lasting 20 minutes, totaling 1 hour.

The total time spent on the phone (1 hour) shall be counted since it exceeds a nominal 30 minutes during a single break period.
The day is considered a work day.
The individual can return to work following a 10 hour break after the end of the last phone call.

5. Intervening hours between end of shift and start of call in work or between call-in work and beginning of next shift if no Waiver is processed for insufficient break. See Section 4.1.1 Step 6.

6. Call-ins A. All call-ins will be performed in accordance with SY-AA-1 00-1013, Call-in Testing.

B. A call-in is considered an addition to the normal work schedule. The work hours can be accounted for using three different methods depending on timing and circumstances of the call-in work period. (1) The call-in hours can be considered a separate work period. Using this method, only the hours worked for NextEra will be counted. The method requires a 10 hour break before the call-in period and after the call-in period. (2) The call-in hours can be considered an extension to the preceding or succeeding work period. Using this method, the intervening hours between the regular work period and the extended work period must be counted.

REVISION NO.: PROCEDURE TITLE: PAGE: WORK HOUR CONTROLS 17 of 40 PROCEDURE NO.: AD-A-1O1-1 004 NUCLEAR FLEET 4.1.1 Time to be Included in Work Hour Calculation (continued)

6. B. (continued)

(3) A Waiver can be processed for the required 10 hour break between successive work periods. If a Waiver is approved for the 10 hour break, the intervening hours need not be counted. Example 1: An individuals normal schedule is from 0700 to 1530 (8 hour day) and the individual is called back to work at 1900 and he/she works until 2100.

The separate work period method cannot be used as a 10 hour break is not available prior to the call-in period.
The call-in is considered an extension of the previous work period, 0700 to 1530. The hours counted for this work period would be 14. A ten hour break is required prior to the individual starting an additional work period; therefore, the individual could return at the normal start of their work period at 0700 the next day.

or

A waiver to the 10 hour break between successive work periods could be requested. The hours counted for the work day would be 10.5. The individual could return at the normal start of their work period at 0700 the next day.

Example 2: An individuals normal schedule is from 0700 to 1530 (8 hour day), and the individual is called back to work from 0200 to 0400 the next day.

The call-in period is considered a separate work period. The 2 hours worked for the licensee is counted. The individual had a 10 hour break prior to the start of the work period and must be given a 10 hour break following the end of the work period.

or

The call-in is considered an extension of the succeeding work period, 0700 to 1530. The hours counted for this work period would be 13.5.

REVISION NO.: PROCEDURE TITLE: PAGE: WORK HOUR CONTROLS 18 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET 4.1.2 Time to be Excluded in Work Hour Calculation

1. All shift turnover time, not to exceed one hour for any particular turnover, may be excluded from the total hours worked.

2. Normal commute to and from a work location. This includes commutes from hotels and other temporary living quarters to an alternate work location during a Business Travel period.

3. Personal time before and after work when not performing duties for NextEra.

4. Off-site incidental duties performed less than a cumulative 30 minutes.

5. Hours worked above the normal scheduled work hours for the purpose of participating in the conduct of an unannounced emergency preparedness exercise or drill. If an individual is on a day off, it is still considered a day off.

6. Paid hours during which the individual is not expected to perform work (e.g.,

vacation time, sick days, personal leave)

7. The one additional hour time shift from daylight savings time to standard time.

8. For security personnel, during the conduct of a Force on Force tactical exercise evaluated by the NRC if they are required to work on a scheduled day off, this may be counted as a day off.

REVISION NO.: - PROCEDURE ]1TLE: PAGE: WORK HOUR CONTROLS 19 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET 4.2 Transitioning to Covered Work OR between Covered GrouDs NOTE The following transition rules from Non-Covered to Covered status apply at all times; even during transitioning from outage to online unit status. (i.e. If a unit transition from outage to online status has just occurred and it is desired to transition a worker from Non-Covered to Covered status, a look back into the outage hours worked must be performed to satisfy the transition from Non-Covered to Covered status.) If a worker begins or resumes performing covered work, consider all hours worked for NextEra, including hours worked performing duties that are not considered covered work. Before beginning or resuming covered work, the following requirements shall be met:

1. Except as permitted by waivers, ensure the individuals work hours have not exceeded the following limits:

16 hours in previous 24 hour period
26 hours in previous 48 hour period
72 hours in previous 7 day (168 hour) period

2. Except as permitted by waivers, ensure the individual has had the following breaks and Minimum Days Off

A 10 hour break before beginning covered work period
A 34 hour break in the previous 216 hour period
A minimum of I day off in the preceding 7-day period is acceptable for individuals who have been working an 8-hour shift schedule, as either day or shift workers, to begin covered work.

Ensure the work hours and days off of the 7-day period are documented in Fatigue Management software, as applicable.

REVISION NO.: PROCEDURE TITLE: PAGE: WORK HOUR CONTROLS 20 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET 4.2 Transitioning to Covered Work OR between Covered Groups (continued)

2. (continued)

A minimum of 1 day off in the preceding 7-day period is acceptable for individuals who have been working an 8-hour shift schedule, as either day or shift workers, to transition from a covered group to another covered group with more stringent Minimum Days Off requirements.
Ensure the work hours and days off of the 7-day period are documented in Fatigue Management software, as applicable.
A minimum of 2 days off in the preceding 7-day period is acceptable for individuals who have been working a 10- or 12-hour shift schedule, as either day or shift workers, to begin covered work.
Ensure the work hours and days off of the 7-day period are documented in Fatigue Management software, as applicable.
A minimum of 2 days off in the preceding 7-day period is acceptable for individuals who have been working a 10- or 12-hour shift schedule, as either day or shift workers, to transition from a covered group to another covered group with more stringent Minimum Days Off requirements.

o Ensure the work hours and days off of the 7-day period are documented in Fatigue Management software, as applicable. o A minimum of 2 days off in the preceding 7-day period is acceptable for operators who have been working outage hours on 10- or 12-hour shifts before they transition to the non-outage unit as one of the two required operators working non-outage Minimum Days Off.

Ensure the work hours and days off of the 7 day period are documented in Fatigue Management software, as applicable.

IEVIION NO.: PROCEDURE TITLE: PAGE: WORK HOUR CONTROLS 21 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET 4.3 Work Hour Limits 4.3.1 Work Hour Limits Regardless of Unit Status NOTE The periods of 24 hours, 48 hours and 72 hours are considered rolling time periods. Rolling means the period is not re-zeroed or reset following a day off or after obtaining authorization to exceed 10 CFR 26 overtime limits. The 24 hours, 48 hours, 7 days (168 hours), and 216 hours do not restart after a day off; the period continues to roll.

No more than 16 work hours in any 24 hour period.
No more than 26 work hours in any 48 hour period.
No more than 72 work hours in any 7 day (168 hour) period.
At least a 10 hour break between successive work periods, or an 8 hour break when a break of less than 10 hours is necessary to accommodate a crews scheduled transition between work schedules or shifts.
A 34 hour break in any 216 hour period.

4.3.2 Online Minimum Days Off When the plant status is on line, workers shall average the Minimum Days Off listed in Table 1. Each worker is subject to the Minimum Days Off that correlate with the plant status at the beginning of their shift.

These Minimum Days Off may be averaged over the shift cycle.
For the purposes of calculating an average number of days off, the duration of the shift cycle shall not exceed six weeks.
In the event of an unplanned outage, the work hours for covered workers shall be considered to be in compliance with the requirements of this section if the schedule for the shift cycle would have provided for the required Minimum Days Off required during on line periods.

REVISION NO.: - PROCEDURE TITLE: PAGE: WORK HOUR CONTROLS 22 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET 4.3.2 Online Minimum Days Off (continued) Table 1 - Online Minimum Days Off Group 8 hour shift 10 hour shift 12 hour shift Maintenance I day off/week 2 days off/week 2 days off/week Operations, Radiation 1 day off/week 2 days off/week 2.5 days off/week Protection, Chemistry, Fire Brigade Leader / Advisor Security I day off/week 2 days off/week 3 days off/week 4.3.3 Outage Minimum Days Off When the plant status is in an outage, workers shall have the Minimum Days Off listed in Table 2. Workers are subject to the Minimum Days Off that correlate with the plant status at the beginning of their shift.

These Minimum Days Off are required over successive days as listed in Table 2.

o At a multi unit site, Table 2 may apply to all covered workers performing outage activities except for 2 Reactor Operators (ROs) and 2 Senior Reactor Operators (SROs) per shift who shall adhere to Section 4.3.2, Online Minimum Days Off required online. The reactor operator at the reactor controls and his supervisor for the online unit must work within the limits of the online hours requirements. Two additional operators, one RO and one SRO (per shift), must also work online hours. This is so that they are available to relieve the operator at the controls or his supervisor, if needed. For a dual unit site with 12 hour shift coverage, this could take as many as 12 operators adhering to the Online Minimum Days Off requirement. These additional operators may work on the outage unit. o The required Minimum Days Off for covered workers subject to outage hours are only applicable to the first 60 days of an outage. After the first 60 days, average Minimum Days Off for on line operations are required.

The 60 day outage period may be extended in 7-day increments for each non overlapping 7 day (168 hours) period in which the person has not worked more than 48 hours during the unit or security system outage or increased threat condition.

RESION NO.: PROCEDURE TITLE: PAGE: WORK HOUR CONTROLS 23 of 40 PROCEDURE NO.: AD-AA-1O1-1 004 NUCLEAR FLEET 4.3.3 Outage Minimum Days Off (continued) Eligibility for Outage Minimum Days Off (MDOs), should be established on an individual or group basis. Eligibility should be evaluated every 15 days during the outage period, beginning at day 0. Covered workers that perform any outage related activity during the outage period are eligible for outage MDOs. Covered Workers not performing outage related activities during the outage period shall adhere to Section 4.3.2, Online Minimum Days Off. Days off may be scheduled throughout the week or 15 day period without restraint during periods of Outage (i.e. not required to be one day off every 5 days). Table 2 Outage Minimum Days Off Group 8 hour shift 10 hour shift 12 hour shift Maintenance I day off/week 1 day off/week 1 day off/week Operations, Radiation 3 days off! 3 days off/ 3 days off! Protection, Chemistry, successive (i.e. successive (i.e. successive (i.e. Fire Brigade Leader! non-rolling) 15 non-rolling) 15 non-rolling) 15 Advisor day period day period day period Security (Not 4 days off! 4 days off! 4 days off! applicable for successive (i.e. successive (i.e. successive (i.e. unplanned Security non-rolling) 15 non-rolling) 15 non-rolling) 15 System Outages) day period day period day period 4.4 Request to Deviate from Work Hour Limits Recognizing that very unusual and non preventable circumstances may arise requiring deviation from the Work Hour Limits in Section 4.3, such deviation shall be considered on an individual basis. Authorized deviations to the work hour limits shall be documented using Attachment 3. Deviations from work hour limits must meet the following requirements:

1. The plant general manager, operations manager, security manager, or their respective designees, determines the deviation is necessary to mitigate or prevent a condition adverse to safety or security.

REVISION NO.: PROCEDURE TITLE: PAGE: WORK HOUR CONTROLS 24 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET 4.4 Request to Deviate from Work Hour Limits (continued)

2. The cognizant supervisor(s) performs and documents a face-to-face assessment in Q4 of Attachment 3 and determines there is reasonable assurance that the individual will be able to safely and competently perform assigned duties during the additional work period for which the deviation will be granted.

A. Face to face assessments shall be performed no more than four hours before the start of the work period documented in Attachment 3. B. Face-to-face assessment shall be performed by person qualified to perform or oversee the work requiring the Waiver. The Operations Shift Manager is considered qualified to perform assessments on personnel from any department.

3. The completed Attachment 3 is approved by the Plant General Manager or designee.

4. Ensure the period of work approved on the waiver is entered into Fatigue Management software, as applicable.

5. In an emergent situation, in which the Plant General Manager or designee is unable to sign the waiver request, it is acceptable to obtain a verbal authorization from the Plant General Manager or designee prior to an individual exceeding the work hour limits and subsequently complete Attachment 3 when time allows, but no later than 24 hours after the event. The cognizant supervisor shall have completed Q4 of Attachment 3, prior to requesting the Waiver approval.

6. Generate a Condition Report to document the work hour deviation and capture the approved waiver.

(Section 7.2 Commitments and/or CAPR 1 and Section 7.2 Commitments and/or CAPR 2)

7. To the extent practical, granting of Waivers shall only address circumstances that could not have been reasonably controlled. Hours worked for activities such as vacation coverage, normal shift coverage or pre-planned projects during on line or outage periods, do not constitute unusual circumstances.

Hours worked for these types of activities should not exceed the work hour limits of Section 4.3.

RE\iSION NO.: PROCEDURE TITLE: PAGE: WORKHOURCONTROLS 25 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET 4.4 Request to Deviate from Work Hour Limits (continued)

8. If an individual is observed to be fatigued or exhibits unsatisfactory mental alertness at any time, then:

A. The individual will be removed from performing work as soon as possible, B. A Fatigue Assessment per SY-AA-1 00-1011, Fatigue Management, shall be performed on the individual.

9. If an individual is performing, or being assessed for, work under a Waiver of the requirements and declares in accordance with SY-AA-1 00-1011, Fatigue Management, that due to fatigue, he or she is unable to safely and competently perform his or her duties, a supervisor or manager shall immediately stop the individual from performing any work. If the individual is required to continue performing those duties under other requirements of the regulations, e.g., to meet minimum licensed operator staffing, then immediate action to relieve the individual as soon as possible shall be taken. Conditions and controls per SY-AA-1 00-1011 will be established to ensure the worker can continue to work safely. Following the self-declaration or relief from performing covered work, as applicable, the individual may be:

A. Reassigned to duties other than covered work, but only if the results of an extensive fatigue assessment per SY-AA-100-1011, Fatigue Management indicate that the individual is fit to safely and competently perform those other duties; Or B. Permitted to take a break of at least 10 hours before returning to perform any covered work. (1) If an individuals is sent home as a result of a self declaration fatigue assessment, the cognizant supervisor shall consider if alternate transportation is appropriate. Personnel safety should be considered in any decision to send someone home due to fatigue.

10. At the conclusion of the work performed under the waiver, the cognizant supervisor shall:

A. Complete Q6 of Attachment 3, B. Ensure Attachment 3 is attached in Fatigue Management software, as applicable.

REVISIONNO.: PROCEDURE TITLE: PAGE: WORK HOUR CONTROLS 26 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET 4.4 Request to Deviate from Work Hour Limits (continued)

11. Deviations from the requirements of the rule may occur as the result of administrative errors or unforeseen circumstances and may constitute violations of rule requirements. A person is considered reset from a deviation, whether under a Waiver or otherwise, when they have met all of the work hour limits of Section 4.3.1 and are scheduled to meet the Minimum Days Off requirement for their current shift cycle or outage window (7 days or 15 days).

The corrective action program shall be utilized to document deviations from the rule requirements. 4.5 Annual Review

1. An annual program review is required to meet the requirements of I OCFR26 Subpart I. This review should be performed in concurrence with data gathering for the annual Fitness for Duty Report which is due before March 1 of each year.

2. The plant manager shall complete this review within 30 days of the end of the review period. Responsible department managers will perform the review for their respective departments.

3. The annual review shall be completed using the quick hit self assessment process in Pl-AA-101-1 001, Quick Hit Assessments and shall contain at least the following activities:

A. Review the actual work hours and worker performance of the below individuals for consistency with the work hours scheduling requirement objective of preventing impairment from fatigue due to the duration, frequency and sequencing of hour worked.

Workers whose actual hours worked during the review period exceeded an average of 54 hours per week in any shift cycle while the work hours were subject to Online Minimum Day Off requirements.
Workers who were granted more than one Waiver during the review period.
Workers who were assessed for fatigue during the review period.

B. Review hours worked and the Waivers under which work was performed to evaluate staffing adequacy for all positions subject to Work Hour Controls.

REVIION NO.: PROCEDURE TITLE: PAGE: WORK HOUR CONTROLS 27 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET 4.5 Annual Review (continued)

3. (continued)

C. Review performance of the station in adhering to work schedules for Covered Work groups; evaluate whether or not the schedule is effectively being implemented.

Is the schedule being adhered to?
Are the changes understood and reasonably consistent with a properly managed schedule?
Does the overtime utilized support efficient utilization of resources?
Are the available resources properly aligned with the scheduled work load?
Is unplanned work or Outages indicative that other corrective actions are necessary?
Does the level and pattern of overtime support a determination that staff size is appropriate for the schedule and work?

D. Summarize fatigue assessments performed in accordance with SY-AA-1 00-1011.

Condition under which the fatigue assessment was conducted (for-cause, self declaration, post event and follow-up)
Statement of whether or not the worker was working on outage activities at the time of the self-declaration or condition resulting in the fatigue assessment.
The category of duties the individual was performing at the time of the self declaration
Management actions if any resulting from the fatigue assessment.

E. Record, trend and correct any problems identified in maintaining control of work hours consistent with the specific requirements and performance objectives of the rule in the corrective action program.

REVISION NO.: PROCEDURE TITLE: PAGE: WORK HOUR CONTROLS 28 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET 5.0 REPORTING NOTE Information on waivers may be obtained by utilizing the reporting capabilities of the Fatigue Management software, EmpCenter, as applicable. The following information shall be included in the annual FFD program performance report required under 10 CFR 26.717:

1. A summary of all instances during the previous calendar year in which a waiver was granted. The summary shall include only those waivers under which work was performed. If it was necessary to deviate from more than one work hour limit during any single extended work period, the summary of instances shall include each of the work hour limits that were waived during the period for each category of covered worker.

2. The number of approved waivers for on line work hour limits.

3. The number of approved waivers for outage work hour limits.

4. A summary that shows the distribution of waiver use among the covered workers within each category.

5. A summary of corrective actions, if any, resulting from the analyses of these data.

6. Reports related to fatigue management may be integrated into the overall FED report.

REVISION NO.: PROCEDURE TITLE: PAGE: WORK HOUR CONTROLS 29 of 40 PROCEDURE NO.: AD-AA-1O1-1 004 NUCLEAR FLEET 6.0 RECORDS REQUIRED In keeping with 10 CFR 26.417, Record Keeping and Reporting, the following business records may be stored and archived electronically so that they are available for NRC inspection purposes and for any legal proceedings resulting from the administration of Fatigue Management. These business records shall be retained for three years or until the completion of all legal proceedings, whichever is later. NOTE

If the electronic storage system being used for fatigue management is retired or converted to a newer system, ensure the old system is maintained to meet the storage time requirements or print hard copy documents and contact site Records Management for storage options.
The Fatigue Management software is an approved storage medium for shift schedules and work hours. The reporting capabilities of the software can be utilized to generate data when requested.

1. Records of work hours including start and stop times for all covered workers including contract personnel. This report may be produced by Fatigue Management software reporting or documented using Attachment 4.

2. Records of shift schedules and shift cycles for covered workers. This report may be produced by Fatigue Management software reporting.

3. The documentation of approved waivers for covered workers (Attachment 3) including the bases for granting the deviations.

4. The documentation of yearly reviews as required in Section 4.5. Yearly reviews are performed in accordance with Pl-AA-101-1001, Quick Hit Assessments. In keeping with PI-AA-101-1 001, Step 5.0, quick hit assessment reports performed in accordance with subject procedure AD-AA-101-1 004, Section 4.5, Annual Reviews, shall be retained as a business record for three years or until the completion of all legal proceedings, whichever is later in the electronic action request system.

VION NO.: PROCEDURE TITLE: PAGE: WORK HOUR CONTROLS 30 of 40 PROCEDURE NO.: AD-A-1O1-1 004 NUCLEAR FLEET

7.0 REFERENCES

AND COMMITMENTS 7.1 References 7.1.1 Common

1. 10 CFR 26 Subpart I Managing Fatigue

2. NEI 06 11, Managing Personnel Fatigue at Nuclear Power Reactor Sites

3. Regulatory Guide 5.73, Fatigue Management for Nuclear Power Plant Personnel

4. SY-AA-1 00-1011, Fatigue Management

5. PI-AA-100, Condition Assessment and Response

6. Pl-AA-10i-i 000, Focused Self-Assessment Planning, Conduct and Reporting

7. SY-AA-100-i 01 3, Call in Testing

8. SY-AA-1 00-1 000, Determination of Fitness

9. NRC Frequently Asked Questions http:Ilwww. nrc.gov/reactors/operating/ops experience/fitness-for-duty-programs/faqs/manage-fatigue. html

10. NEI Frequently Asked Questions http://atom. nei.org/Default.aspx?alias=atom.nei.org/workhourstf 7.1.2 Duane Arnold Energy Center None 7.1.3 Point Beach Nuclear Plant I. FP-PA-ARP-01, CAP Action Request Process

2. NP-i .3.1, Records Management Program 7.1.4 Plant St. Lucie

1. L-96-2i7, 10CFR2.201, Reply to Notice of Violation, NRC Inspection Report 96-09 (EA 96-263).

2. CR 96-2417, QA Audit QSL-PM-96-18

3. CR 03-1063, QA Review of ANO Violation

REVISION NO.: -. PROCEDURE TITLE PAGE: WORKHOURCONTROLS 31 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET 7.1.4 Plant St. Lucie (continued)

4. CR 2006-3915 Electronically Scan and Attach Approved Appendix A to Applicable CR 7.1.5 Seabrook Station

1. ACR 97-2791

2. NRC Inspection Report No. 50-443/92-0 7.1.6 Plant Turkey Point

1. Technical Specifications Section 6.1, Responsibility

2. Technical Specifications Section 6.2, Organization

3. Technical Specifications Section 6.8, Procedures and Programs

4. FSAR Section 12.0

5. QI 1-PTN-2, Operations Organization

6. QI 1-PTN-3, Maintenance Organization

7. QI 1-PTN-5, Engineering Technical Support Organization

8. QI 1-PTN-6, Training Organization

9. NAP-406, On-Site Review Group

10. Miscellaneous Documents (i.e. e., PC/M, Correspondence)

11. QATR, A.2, Organization

12. Appendix E, Organization Charts, Quality Assurance Topical Report

13. Condition Report, CR 96-1 047

14. Condition Report, CR 03-0647

15. Condition Report, CR 03-0989

16. Condition Report, CR 04-1155

17. Condition Report, CR 2007-37413

18. Condition Report, CR 07-40653 CA# 1

REVISION NO.: POCEbUE ThTLE: PAGE: WORK HOUR CONTROLS 32 of 40 PROCEDURE NO.: ADAA1O11 004 NUCLEAR FLEET 7.2 Commitments andlor CAPRs

1. L-97-291, Reply to Notice of Violation, NRC Inspection Report 97-1 1 (Section 4.4 Step 6)

2. PM-99-03-322, Overtime Tracking (Section 4.4 Step 6)

REVISION NO.: PROCEDURE TITLE: - - PAGE: WORK HOUR CONTROLS 33 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET ATTACHMENT I GUIDELINES FOR COVERED WORK (Page 1 of 3) Figure 1: Review of personnel for applicability of Work Hour Controls per Section 4.3 of this procedure Notes:

1) Maintenance activities include modifications, surveillances, post-maintenance testing, and corrective and preventive maintenance.

2) Deotations from this requirement require specific evaluation in accordance with risk assessment approach used for Maletenance Rule risk assessments.

3) See Figure 2 for determination of Direction applicability.

4) Chemists operating sample valves is considered operation of equipment

REVISION NO.: PRaCEDURE]1TL: PAGE: PROCEDURE NO.: WORK HOUR CONTROLS 34 of 40 AD-AA-101-1 004 NUCLEAR FLEET ATTACHMENT I GUIDELINES FOR COVERED WORK (Page 2 of 3) Directing The following guidance should be used when determining if an individual is directing an operations or maintenance activity. An affirmative answer suggests the activity may be considered directing: Is the work actMty an operations or maintenance activity? V Is the work activity on a risk significant structure, system or component? V Is the individual in question onsfie? No V Is the individual the first line foreman/leader? supervisol_ N__1Jr in Is the individual dire ctiy involved the execution of the work activity? Yes Is th iicua1 dsctssoas fot that acm:ty without subsequent tedancal revie.. ___ Is this person ultimately responsible for the correct peifomiance of the work activity? Yes Directing Not directing

REV1SFONNO.: - PROCEDURET1TLE: - - PAGE: WORK HOUR CONTROLS 35 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET ATTACHMENT I GUIDELINES FOR COVERED WORK (Page 3 of 3) The following tasks are examples generally considered NOT directing:

Engineering tasks (e.g., check valve visual inspections, snubber bench testing, Motor-Operated Valve (MOV) Valve Operator Test Evaluation System (VOTES) trace evaluations, Air-Operated Valve (AOV) flow scan evaluations, NDE, ASME repair I replacement acceptance reviews, flow accelerated corrosion evaluations, In-Vessel Visual Inspection (l\JVI) review and approval, Generic Letter 89-13 visual and work review)
Supervision in the plant of the maintenance on a non-covered SSC o Supervision at the second level of supervision Note: Position alone should not be a deciding factor and all criteria must be evaluated e.g. a Shift Manager is a second level supervisor but has the authority to direct Covered Work.
Conducting Work Execution Center (WEC) documentation activities
Writing a work procedure
Preparing a work or modification package
Review by senior management of work plans
Training of personnel during which time the trainee is not operating or performing
Providing recommendations from vendors and engineers on test performance, components and system operation, or other similar technical inputs
Review and approval of documents
Any work that is not operations or maintenance on high safety significant System, Subsystem or Component (SSC).
Technical Staff providing only advice to control room staff, including non

                   -licensed Shift Technical Advisors (STAs).

REVISION NO.: PROCEDURE TITLE: -

                                                                    -                                           PAGE:

WORK HOUR CONTROLS 36 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET ATTACHMENT 2 INCIDENTAL DUTIES RECORD (Page 1 of 1) INCIDENTAL DUTIES RECORD (Page 1 of 1) Record all incidental duty time between the specified work periods below. Cumulative incidental duty time between each work period that does not total greater than 30 minutes may be discarded. For the purpose of calculating and accounting for work hours totaling greater than 30 minutes, reference section 4.1.1 .5. Record of duties performed by: End of previous work period: / Date Time Start of next scheduled work period: Date Time Incidental Duty Performed Start CompIeton Duration in Minutes Date I Time Date I Time Total Duration The individual subject to this record shall contact the cognizant supervisor or designee to determine the time at which a retum to work is permitted. Incidental duties Start and Completion times entered into Fatigue Management software when software is utilized for tracking time. By:___________________________ Cognizant Supervisor Date! Time AD.AA-1O1.1004-FO1 Revision 2

REVISION NO.: PROCEDURE TITLE: PAGE: WORK HOUR CONTROLS 37 of 40 PROCEDURE NO.: ADAk-1O1-1 004 NUCLEAR FLEET ATTACHMENT 3 WAIVER REQUEST (Page 1 of 2) WAIVER REQUEST (Page 1 of2) WAIVER FORM Cogni2aflt Supervisor

Name of individual requlrtng Waiver 01 This doviation is required for work beginning f_ and scheduled to complete Date Time Date Time 02 This work period will deviate from the Work Hour Controls as follows:

Check all that apply (Upon approval, ensure schedule is updatedl: Greater than 18 hours in any 24 hour penod Greater than 26 hours in any 48 hour penod Greaterthan 72 hours in any 7 day 1168 hours) period A break of less than 10 hours (excluding travel time) Less than a 34 hour break in any 216 hour period Minimum required days off - Outage REQUIRED DAYS OFF days per Minimum required days off - Online REQUIRED DAYS OFF days per SCOPE OF WORK I BASIS FOR WAIVER Enter the required position this work hour deviation is necessary to fill and describe the unusual circumstances that justify the eittraordlisary action to deviate from the Work Hour Limits. 04 FITNESS TO DEViATE FROM WORK HOUR LIMITS Person performing the face to face assessment is qualified to perform or oversee the workforwhicli this Waiver is required? YES D NO Comment DAY_____________________ Record 0-Days. N-nights Shift 112cr ldhourshiits) 0-Schedsle Days. S-Swing or widrghtsS hour hft Do ed lode shdt turnover Worked the boxes for the 34Hcur days citainegthe 34 en hour break. AD-AA-1O1-1004-F02 Revisicn 2 I

REVISION NO.: PROCEDURE TITLE: PAGE: WORK HOUR CONTROLS 38 of 40 PROCEDURE NO.: AD-AA-1O1-1 004 NUCLEAR FLEET ATTACHMENT 3 WAIVER REQUEST (Page 2 of 2) WAIVER REQUEST (Page 2 of 2) Based on the above hours worked is there potential for an increase in fatigue over consecutive sleep-wake periods? (has there been adequate opportunity for rest, was sleep restricted because of shift changes, have issues outside work restricted sleep opportunities) YES C NO C Comment Based on face to face observation does this person appear to be fatigued? (appear intoxicated, yawning, tired legs, rubs face with hands often, poor corn mu nication, apathetic) YES C NO C Comment Based on responses to the above and the time of day for which this Waiver is being requested, is there reasonable assurance that the individual will be able to safely and competently perform duties during the additional work period for which the Waiver is to be granted? (Section 4.4.2) YES C NO C Reason: Are any controls andior conditions required to be established in order for this person to perform work under this Waiver? Coritrols and conditions will include, but will riot be hated to, (I) controls on the type of work to be performed (e.g. physical or rental, tedious or st.mulating, individual or group, risk-signAcant or not). (2) the required level of supervision (continuous or intermitient) arid other oversight (e.g. peer checks, independent verificatcns, quality assurance revews and operability checks), and (3) the need to implenrnntatigue countermeasures (e.g. rest breaks) YES C NO C Controls: Supervisor or designee Sign! Print Date Time Individual renuirino Waiver Sian I Print Date Time APPROVAL This Waiver is required to address conditions adverse to safety or security. Based on results of the face to face assessment this deviation from Work Hour Limits is approved. Plant General Manager or designee Sign I Print Date Time 06 SUPERVISOR CLOSEOUT Time actually worked on this Waiver beginning I and completed Date Time Date Time C Waiver riot needed? C Fatigue Management software updated with time worked WHEN software is utilized for tracking time? Individual performed satisfactorily? YES C NO C If NO, initiate a separate Condition Report. Corn merits Supervisor or designee Sign I Print Date Time AD.AA-1 Cl-I 3D4.E02 Revisicn 2 I

REVISION NO.: PROCEDURE TITLE: PAGE: WORK HOUR CONTROLS 39 of 40 PROCEDURE NO.: AD-AA-101-1 004 NUCLEAR FLEET ATTACHMENT 4 EXAMPLE WORK HOUR RECORD (Page 1 of 1) FPL I NextEra Energy Resources Contractors and Vendors 10 CFR 26.205 Work Hour Report Work Hours shall be alied as required in NextEra Procedure AD-AA-101-1 004, Work Hour Controls 10 CFR 26 Subpart I Work Category Total Fatigue Rule (Ops, Mntc, hours for work period RP, Chem, Covered Outage I in accordance with Name Sec) Work YIN Online Date Time In Date Time Out AD-AA-1 01-1004 Doe, John (example) RP Y Outage 3/12/09 0600 3/12/09 1930 13.5 14 No deviation required, work performed not Covered Doe, John (example) RP N Outage 3/13/09 0400 3/13/09 1800 Work Doe, John (example) RP N Outage 3/14/09 0600 3/14/09 1600 10 Doe, John (example) RP N Outage 3/15/09 off 3/15/09 off 0 Doe, John (example) RP Y Outage 3/16/09 1800 3/17/09 0530 11.5 Doe, John (example) RP N Outage 3/17/09 1800 3/18/09 0530 11.5 16.5- FPL I NextEra Energy approved Doe, John (example) RP Y Outaae 3/18/09 1800 3/1 9/09 1030 deviation on file non covered hours required to be tracked for 7 day period prior to Covered Work

REVISION NO.: PROCEDURE TITLE: PAGE: WORK HOUR CONTROLS 40 of 40 PROCEDURE NO.: AD-AA-101-1004 NUCLEAR FLEET ATTACHMENT 5 WORK HOUR RECORD (Page 1 of 1) FPL I NextEra Energy Resources Contractors and Vendors 10 CFR 26.205 Work Hour Report Work Hours shall be applied as required in NextEra Procedure AD-AA-101-1 004, Work Hour Controls IOCFR26 Subpart I Work Category Total Fatigue Rule (Ops, Mntc, hours for work period RP, Chem, Covered Outage I in accordance with Name Sec) Work YIN Online Date Time In Date Time Out AD-AA-1O1-1004 non covered hours required to be tracked for 7 day period prior to Covered Work

Appendix C Job Performance Measure Form ES-C-I Worksheet Facility: Turkey Point Task No: 01201013100 Prepare an ECO for 3A Component Cooling Water Task

Title:

Pump JPM No: 01201013103 K/A

Reference:

G2.2.13 RO 4.1 SRO 4.3 Examinee: NRC Examiner: Facility Evaluator: Date: Method of Testing: Classroom Simulated Actual Performance Performance X Classroom X Simulator Plant HAND JPM BRIEFING SHEET TO EXAMINEE AT THIS TIME! Read to the examinee: I 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:

The plant is in Mode 1.
The 3D 4KV Bus is aligned to the 3A 4KV Bus.

o 3A Component Cooling Water Pump has developed a bearing vibration problem. The computer is unavailable for generating ECOs.

Operations/Maintenance has requested an ECO tagout be prepared to facilitate motor and bearing replacement of the 3A Component Water Pump.

Initiating Cue:

The Shift Manager has directed you to generate a clearance (ECO) for the 3A CCW Pump to facilitate motor and bearing replacement.
Complete only the Tag Hang List for ECO.
For Tag Serial Numbers, use sequential numbers, starting with Tag No. 1.

N 2011 NRC Exam (RO) JPM-A.2 NUREG 1021 Rev 9 Appendix ç

Appendix C Page 2 of 17 Form ES-C-I Task Standard: The Tag Hang List for ECO is completed to the following criteria:

All steps marked as critical on the answer key are included on the applicants form.
The step for rackout of breaker 3AA12 precedes all other steps requiring manipulation of valves.
The correct positions of all components on critical steps are included on the Applicants form.

o At least one vent path and one drain path are properly identified and tagged. The following listed items are not critical to completion of this ECO: o The order of steps following the rack out step of 3AA12.

Equipment Description and Equipment Location wording do not have to exactly match the answer key.

Note that valves with Danger tags that are not marked critical on the answer key may be included by the Applicant to provide vent and drain paths in preparation for maintenance. Required Materials:

Plant Drawings 5613-M-3030 Sheets 1 through 5, Component Cooling Water System
Plant Drawing 561 0-T-E-1 591, Sheet 1, Operating Diagram Electric Distribution
0-ADM-21 2.1, Operations In-Plant Equipment Clearance Orders
OP-AA-101-1000,Clearance and Tagging 3-NOP-030, Component Cooling Water System
ODI-CO-004, Shift Operations Management System (eSOMS)
PTN Breaker List for Lighting Panel 34A (561 0-E-855, Sheet 44, Pages 1-6) o Blank Tag Hang List for ECO o Pencil General

References:

PTN Breaker Book
ECO 3-10-06-006 Time Critical Task: No Validation Time: 1 hour 2011 NRC Exam (RO) JPM-A.2 NUREG 1021 Rev 9 Appendix C

SIMULATOR SETUP NOT Applicable, 2011 NRC Exam (RO) JPM-A.2 NUREG 1021 Rev 9 Appendix C

Appendix C Page 4 of 17 Form ES-C-I Denote critical steps with a check mark (q) Start Time SAT STEP I Obtain required materials. UNSAT Applicant may request a copy of the following: e Plant Drawings 561 3-M-3030 Sheets I through 5, Component Cooling Water System e Plant Drawing 561 0-T-E-1 591, Sheet 1, Operating Diagram Electric Distribution

               . 0-ADM-21 2.1, Operations In-Plant Equipment Clearance Orders STANDARD             OP-AA-101-1 000, Clearance and tagging 3-NOP-030, Component Cooling Water System o    ODI-CO-004, Shift Operations Management System (eSOMS) e    PTN Breaker List e    Blank Tag Hang List For ECO Provide the Applicant with a copy of information when requested:

e Plant Drawings 5613-M-3030 Sheets 1 through 5, Component Cooling Water System o Plant Drawing 561 0-T-E-1 591, Sheet 1, Operating Diagram Electric Distribution e 0-ADM-21 2.1, Operations In-Plant Equipment Clearance Orders CUE

OP-AA-1O1-1000, Clearances and tagging o 3-NOP-030, Component Cooling Water System o ODl-CO-004, Shift Operations Management System (eSOMS) e PTN Breaker List for Lighting Panel 34A (5610-E-855, Sheet 44, Pages 1-6) c Blank Tag Hang List For ECO 2011 NRC Exam (RO) JPM-A.2 NUREG 1021 Rev 9 Appendix C

Appendix C Page 5 of 17 Form ES-C-I STEP 2 SAT q Enter 3P21 IA-CONTROL SWITCH on Tag Hang List for ECO. UNSAT

1. Enters 3P211A-CONTROL SWITCH in Equipment ID Column.

2. Enters 3A CCW PP CONTROL SWITCH VPB 3C05 in Equipment Description column.

       .       3. Enters CONTROL ROOM VERTICAL PANEL in STANDARD            Equipment Location column.

4. Enters - in Tag Serial Number column.

5. Enters INFO TAG in Tag Type column.

6. Enters a value in Place Seq. column.

7. Enters HANG INFO TAG in Place Config. Column.

CUE COMMENT EVALUATOR NOTES: Standards 2, 3, 4 and 6 are not critical to this Step. Bolded steps are critical steps. NOTE . . Entries on this line may be done in any order. The exact wording shown is not important. 2011 NRC Exam (RO) JPM-A.2 NUREG 1021 Rev 9 Appendix C

Appendix C Page 6 of 17 Form ES-C-I STEP 3 SAT Enter breaker 3AA12 on Tag Hang List for ECO. UNSAT I. Enters 3AA12 in Equipment ID Column.

2. Enters 4.16KV BKR TO CCW PUMP A (P21 1A) in Equipment Description column.

3. Enters 368 V SWITCHGEAR ROOM in Equipment STANDARD Location column.

4. Enters 1 in Tag Serial Number column.

5. Enters DANGER in Tag Type column.

6. Enters a value in Place Seq. column.

7. Enters RACKED OUT PLUS in Place Con fig. Column.

CUE COMMENT EVALUATOR NOTES: Standards 2, 3 and 4 and 7 are not critical to this Step. Standard 6 is only critical in that sequence should show breaker 3AA12 racked out before any ECO boundary valves NOTE are closed. For Standard 7, the plus is not critical to this step, as it is not required for safety. Entries on this line may be done in any order. The exact wording shown is not important. 2011 NRC Exam (RO) JPM-A.2 NUREG 1021 Rev 9 Appendix C

Appendix C Page 7 of 17 Form ES-C-I STEP 4 SAT Enter breaker LP34A-47 on Tag Hang List for ECO. UNSAT

1. Enters LP34A-47 in Equipment ID Column.

2. Enters MTR HTR- OMPONENT COOLING WATER PUMP 3A (3P211A) in Equipment Description column.

3. Enters 368 V SWITCHGEAR ROOM in Equipment STANDARD Location column.

4. Enters 2 in Tag Serial Number column.

5. Enters DANGER in Tag Type column.

6. Enters a value n Place Seq. column.

7. Enters OFF PLUS in Place Con fig. Column.

CUE COMMENT EVALUATOR NOTES: Standards 1, 2, 3, 4, 5 are critical. NOTE Entries on this line may be done in any order. The exact wording shown is not important. 2011 NRC Exam (RO)JPM-A.2 NUREG 1021 Rev 9 Appendix C

Appendix C Page 8 of 17 Form ES-C-I STEP 5 SAT

     ,         Enter valve 3-703A on Tag Hang List for ECO UNSAT I. Enters 3-703A in Equipment ID Column.

2. Enters STOP VLV FOR CCW PUMP A DISCH in Equipment Description column.

3. Enters 202 COOLING PUMP ROOM in STANDARD Equipment Location column.

4. Enters 3 in Tag Serial Number column.

5. Enters DANGER in Tag Type column.

6. Enters value in Place Seq. column.

7. Enters CLOSE PLUS in Place Config. Column.

CUE COMMENT EVALUATOR NOTES: Standards 2, 3 and 4 are not critical to this Step. For Standard 7, the plus is not critical to this step, as it is not required for safety. NOTE Entries on this line may be done in any order. The exact wording shown is not important. Standard 6 is only critical in that sequence must be after step 3 (rack out breaker) and before step 6 (open vent valve). 2011 NRC Exam (RO) JPM-A.2 NUREG 1021 Rev 9 Appendix C

Appendix C Page 9 of 17 Form ES-C-I STEP 6 SAT Enter valve 3-701A on Tag Hang List for ECO U N SAT I. Enters 3-701A in Equipment ID Column.

2. Enters ISO VLV TO CCW PUMP A IN LET in Equipment Description column.

3. Enters 202 COOLING PUMP ROOM in STANDARD Equipment Location column.

4. Enters 4 in Tag Serial Number column.

5. Enters DANGER in Tag Type column.

6. Enters value in Place Seq. column.

7. Enters CLOSE PLUS in Place Config. Column.

CUE COMMENT EVALUATOR NOTES: Standards 2, 3 and 4 are not critical to this Step. For Standard 7, the plus is not critical to this step, as it is not required for safety. NOTE Entries on this line may be done in any order. The exact wording shown is not important. Standard 6 is only critical in that sequence must be after step 3 (rack out breaker) and before step 9 (open vent valve). 2011 NRC Exam (RO) JPM-A.2 NUREG 1021 Rev 9 Appendix C

Appendix C Page 10 of 17 Form ES-C-I STEP 7 SAT Enter 3-703F-HOSE on Tag Hang List for ECO. UNSAT

1. Enters 3-703F-HOSE in Equipment ID Column.

2. Enters VENT VLV ON CCW PUMP A CASING HOSE in Equipment Description column.

3. Enters 202 COOLING PUMP ROOM in Equipment Location column.

STANDARD 4. Enters - in Tag Serial Number column.

5. Enters No Tag in Tag Type column.

6. Enters value in Place Seq. column.

7. Enters REMOVE CAP AND INSTALL HOSE in Place Config. Column. (Note: Initially route hose for collection of contaminated molybated water until vented.)

CUE COMMENT EVALUATOR NOTES: This step is not critical, as it may be included on Restoration Steps, which are not required for this JPM. For Standard 5, also accept Danger Tag. NOTE Entries on this line may be done in any order. The exact wording shown is not important. Standard 6 is only critical in that sequence must be after step 3 (rack out breaker) and before step 8 (open vent valve). Additional guidance for removing and installing hose is not critical to performance of the JPM. 2011 NRC Exam (RO) JPM-A.2 NUREG 1021 Rev 9 Appendix C

Appendix C Page II of 17 Form ES-C-I STEP 8 SAT Enter valve 3-703F Throttle on Tag Hang List for ECO. UNSAT

1. Enters 3-703F in Equipment ID Column.

2. Enters VENT VLV ON CCW PUMP A CASING HOSE in Equipment Description column.

3. Enters 202 COOLING PUMP ROOM in Equipment Location column.

STANDARD

4. Enters - in Tag Senal Number column.

5. Enters DANGER in Tag Type column.

6. Enters value in Place Seq. column.

7. Enters Throttle in Place Config. Column. (Note: Do not exceed drain system capacity. Use barrels for draining.)

CUE COMMENT EVALUATOR NOTES: Standards are not critical except noted below. For Standard 5, also accept No Tag. If No Tag is entered, this will change subsequent Tag Serial Numbers. Applicants may add a line entry for throttling this valve (to NOTE control venting process) prior to opening the valve fully. Entries on this line may be done in any order. The exact wording shown is not important. Standard 6 is only critical in that sequence must be after step 5 (discharge valve) and step 6 (inlet valve). Additional guidance in item 7 is not critical to this JPM. 2011 NRC Exam (RO) JPM-A.2 NUREG 1021 Rev 9 Appendix C

Appendix C Page 12 of 17 Form ES-C-I STEP 9 Enter valve 3-703F OPEN on Tag Hang List for ECO.

1. Enters 3-703F in Equipment ID Column.

2. Enters VENT VLV ON CCW PUMP A CASING HOSE in Equipment Description column.

3. Enters 202 COOLING PUMP ROOM in Equipment STANDARD Location column.

4. Enters - in Tag Serial Number column.

5. Enters DANGER or No Tag in Tag Type column.

6. Enters value in Place Seq. column.

7. Enters OPEN in Place Con fig. Column.

CUE COMMENT EVALUATOR NOTES: Only critical steps relates to sequencing of steps noted below. For Standard 5, also accept No Tag. If No Tag is entered, this will change subsequent Tag Serial Numbers. NOTE Applicants may add a line entry for throttling this valve (to control venting process) prior to opening the valve fully. Entries on this line may be done in any order. The exact wording shown is not important. Standard 6 is only critical in that sequence must be after step 5 (discharge valve) and step 6 (inlet valve). 2011 NRC Exam (RO) JPM-A.2 NUREG 1021 Rev 9 Appendix C

Appendix C Page 13 of 17 Form ES-C-I STEP 10 SAT Enter 3-702D-HOSE on Tag Hang List for ECO. UNSAT

1. Enters 3-702D-HOSE in Equipment ID Column.

2. Enters DRAIN VLV FOR CCW PUMP A DISCH in Equipment Description column.

3. Enters 202 COMPONENT COOLING PUMP ROOM in Equipment Location column.

STANDARD 4. Enters - in Tag Serial Number column.

5. Enters No Tag in Tag Type column.

6. Enters value in Place Seq. column.

7. Enters REMOVE CAP AND INSTALL HOSE in Place Config. Column. (Note: route hose to barrel for collection of contaminated, molybated water.)

CUE COMMENT EVALUATOR NOTES: This step is not critical, as it may be included on Restorations Steps, which are not required for this JPM. For Standard 5, also accept Danger Tag. Or No Tag If NOTE Danger Tag is entered, this will change subsequent Tag Serial Numbers. Entries on this line may be done in any order. The exact wording shown is not important. 2011 NRC Exam (RO) JPM-A.2 NUREG 1021 Rev 9 Appendix C

Appendix C Page 14 of 17 Form ES-C-I STEP 11 SAT Enter valve 3-702D-Throttle on Tag Hang List for ECO. UNSAT

1. Enters 3-702D in Equipment ID Column.

2. Enters DRAIN VLV FOR CCW PUMP A DISCH in Equipment Description column.

3. Enters 202 _COMPONENT COOLING PUMP ROOM in Equipment Location column.

STANDARD

4. Enters - in Tag Senal Number column.

5. Enters No Tag in Tag Type column.

6. Enters value in Place Seq. column.

7. Enters THROTTLE in Place Config. Column. (Note: Do not exceed system capacity. Use barrels for draining.)

CUE COMMENT EVALUATOR NOTES: No critical steps are associated for this step except the sequencing noted below. For Standard 5, also accept No Tag. If No Tag is entered, this will change Tag Serial Numbers. Applicants may add a line entry for throttling this valve (to control venting process) prior to opening the valve fully. NOTE Entries on this line may be done in any order. The exact wording shown is not important: It is critical that one vent path be danger tagged open. Either steps 9 & 10 OR 11 & 12 must be performed to establish a vent path. Standard 6 is only critical in that sequence must reflect that this step must occur after steps 2 through 8 have been completed. 2011 NRC Exam (RO) JPM-A.2 NUREG 1021 Rev9AppendixC

Appendix C Page 15 of 17 Form ES-C-I STEP 12 SAT Enter valve 3-702D-OPEN on Tag Hang List for ECO. UNSAT

1. Enters 3-702D in Equipment ID Column.

2. Enters DRAIN VLV FOR CCW PUMP A DISCH in Equipment Description column.

3. Enters 202 COMPONENT COOLING PUMP ROOM in STAN DARD Equipment Location column.

4. Enters - in Tag Serial Number column.

5. Enters No Tag in Tag Type column.

6. Enters value in Place Seq. column.

7. Enters THROTTLE in Place Con fig. Column.

CUE COMMENT EVALUATOR NOTES: No critical steps are associated for this step except the sequencing noted below. For Standard 5, also accept No Tag. If No Tag is entered, this will change Tag Serial Numbers. NOTE Entries on this line may be done in any order... The exact wording shown is not important. It is critical that one vent path or one drain path be tagged open. See key Attached. Stop Time 2011 NRC Exam (RO) JPM-A.2 NUREG 1021 Rev 9 Appendix C

Appendix C Page 16 of 17 Form ES-C-I Verification of Completion: Job Performance Measure No. 01201013103 Examinees Name: Examiners Name: Date Performed: Facility Evaluator: Number of Attempts: Time to Complete: Question Documentation: Question:

Response

Resu It: Satisfactory/Unsatisfactory Examiners signature and date: 2011 NRC Exam (RO) JPM-A.2 NUREG 1021 Rev 9 Appendix C

JPM BRIEFING SHEET I will explain the inftial 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:

The plant is in Mode 1.

o The 3D 4KV Bus is aligned to the 3A 4KV Bus.

3A Component Cooling Water Pump has developed a bearing vibration problem.
The computer is unavailable for generating ECOs.
Operations/Maintenance has requested an ECO tagout be prepared to facilitate motor and bearing replacement of the 3A Component Water Pump.

Initiating Cue:

The Shift Manager has directed you to generate a clearance (ECO) for the 3A CCW Pump to facilitate motor and bearing replacement.
Complete only the Tag Hang List for ECO.
For Tag Serial Numbers, use sequential numbers, starting with Tag No. 1.

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. 2011 NRC Exam (RO) JPM-A.2 NUREG 1021 Rev 9 Appendix C

JPM BRIEFING SHEET I 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:

The plant is in Mode 1.
The 3D 4KV Bus is aligned to the 3A 4KV Bus.

3A Component Cooling Water Pump has developed a bearing vibration problem.

The computer is unavailable for generating ECO5.
Operations/Maintenance has requested an ECO tagout be prepared to facilitate motor and bearing replacement of the 3A Component Water Pump.

Initiating Cue: o The Shift Manager has directed you to generate a clearance (ECO) for the 3A CCW Pump to facilitate motor and bearing replacement.

Complete only the Tag Hang List for ECO.
For Tag Serial Numbers, use sequential numbers, starting with Tag No. 1.

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. 2011 NRC Exam (RO)JPM-A.2 NUREG 1021 Rev 9 Appendix C

ECO FORM - ANSWER KEY - 2011 PTN NRC Exam (RO) A2 TAG HANG LIST FOR ECO Tag Equipment Tag Place Place nd 2 Equipment ID Equipment Location Serial Notes Description Type Seq Config Number 3P21 IA-3A CCW PP CONTROL CONTROL ROOM Critical step and CONTROL INFO TAG I HANG INFO TAG SWITCH VPB 3C05 VERTICAL PANEL sequence SWITCH 368_4160V 4.16KV BKR TO CCW Critical Step and 3AA12 SWITCHGEAR I DANGER 2 RACKED OUT PLUS PUMP A (P2IIA) sequence ROOM MTRHTR 368 V COMPONENT Critical Step and LP34A-47 SWITCH GEAR 2 DANGER 3 OFF PLUS COOLING WATER sequence ROOM PUMP 3A (3P211A) 202 COMPONENT STOP VLV FOR CCW Critical step and 3-703A COOLING PUMP 3 DANGER 4 CLOSE PLUS PUMP A DISCH sequence ROOM 202 COMPONENT ISO VLV TO CCW Critical step and 3-701A COOLING PUMP 4 DANGER 5 CLOSE PLUS PUMP A INLET sequence ROOM REMOVE CAP AND ONLY CRITICAL INSTALL HOSE That one drain or 202 COMPONENT Initially route hose for VENT VLV ON CCW No Tag vent path is 3-703F-HOSE COOLING PUMP 6 collection of contaminated PUMP A CASING HOSE installed. ROOM molybated water until Sequence is not vented. critical Throffle 202 Do Not Exceed drain 3-703F- VENT VLV ON CCW No Tag THROTTLE PUMP A CASING HOSE COOLING PUMP system capacity, Use ROOM Barrels for draining. 202 COMPONENT DANGER VENT VLV ON CCW - 3-703F COOLING PUMP Or 8 OPEN PUMPACASING No Tag ROOM

Tag Equipment Tag Place Place st 1 nd 2 Equipment ID Equipment Location Serial Notes Description Type Seq Config Number REMOVE CAP AND INSTALL HOSE 202 COMPONENT Route hose to barrel for No Tag 3-702D-HOSE DRAIN VLV FOR CCW 9 collection of PUMP A DISCH COOLING PUMP ROOM contaminated,, molybated water THROTTLE 202 COMPONENT 3-702D- DRAIN VLV FOR CCW Do not exceed system COOLING PUMP No Tag 10 THROTTLE PUMP A DISCH capacity. Use barrels for ROOM draining. 202 COMPONENT DANGER DRAIN VLV FOR CCW 3-702D COOLINGPUMP Or 11 OPEN PUMPADISCH No Tag ROOM

(***) (***)

At least one vent path or one drain path must be properly identified. Any vent or drain path is allowable and is critical.

Florida Power & Light Company Turkey Point Nuclear Plant cj 11

Title:

Operations In-Plant Equipment Clearance Orders (Information Use) Responsible Department: Operations/Safety Revision Number: 2A Issue Date: 4/25/11 Revision Approval Date: 2/25/11 ARs 1613425, 1618785, 1611997 PCRs 08-4655, 09-1340, 09-1604, 09-0202, 09-3933, 10-0865, 10-1331, 10-1418, 10-1003 W97:JE/nw/nw/cls

LIST OF EFFECTIVE PAGES (Rev. 2A) Revision Revision Revision Date Date Date 1 02/25/11 25 05/05/09 49 02/05/11 2 02/25/11 26 11/24/08 50 02/05/11 3 02/05/11 27 02/05/11 51 02/05/11 4 02/05/11 28 11/24/08 52 02/05/11 5 05/29/09 29 04/09/10 53 02/05/11 6 11/24/08 30 02/05/11 54 02/05/11 7 11/24/08 31 02/05/11 55 02/05/11 8 02/25/11 32 02/05/11 56 02/05/11 9 11/24/08 33 02/05/11 57 02/05/11 10 04/28/10 34 02/17/11 58 02/05/11 11 02/25/11 35 02/05/11 59 02/05/11 12 02/05/11 36 02/05/11 60 02/05/11 13 02/05/11 37 02/05/11 61 02/05/11 14 02/05/11 38 02/05/11 62 02/05/11 15 02/05/11 39 02/05/11 63 02/05/11 16 02/05/11 40 02/05/11 64 02/05/11 17 11/24/08 41 02/05/11 65 02/05/11 18 04/09/10 42 02/05/11 66 02/05/11 19 04/09/10 43 02/05/11 67 02/05/11 20 02/05/11 44 02/05/11 68 02/05/11 21 11/24/08 45 02/05/11 69 02/05/11 22 11/24/08 46 02/05/11 70 02/05/11 23 02/05/11 47 02/05/11 71 02/05/11 24 11/24/08 48 02/05/11 72 02/05/11 W97:JE/nw/nw/cls

TABLE OF CONTENTS Section jg 1.0 PURPOSE 5

2.0 REFERENCES

/RECORDS REQUIRED/COMMITMENT DOCUMENTS 5 3.0 RESPONSIBILITIES 8 4.0 DEFINITIONS 13 5.0 PROCEDURE 17 5.1 Standard ECO Practices 17 5.2 Tags Plus 20 5.3 Valve Practices 23 5.4 Electrical Practices 27 5.5 Tank and Piping System Practices 29 5.6 ECO Log 30 5.7 Operating Permit Tags 30 5.8 ECO Research and Preparation 34 5.9 ECO Review and Approval (refer to Attachment 7, ECO Checklist for additional guidance) 37 5.10 ECO Execution (refer to Attachment 7, ECO Checklist for additional guidance) 40 5.11 ECORelease 43 5.12 ECO Tag Removal and Equipment Restoration 45 5.13 ECO Boundary Modification 47 5.14 ECO Revision 49 5.15 Bus Outages (Bus Clearances) 50 5.16 Review of ECOs 52 5.17 ECO Computer Failure 54 Wq7.Ip/nw/nw/rIs

Procedure No.: Procedure

Title:

Page: 4 Approval Date: O-ADM-2 12.1 Operations In-Plant Equipment Clearance Orders 2/5/11 TABLE OF CONTENTS (Contd) Section ATTACHMENTS Attachment 1 ECU Form 55 Attachment 2 ECU In Effect Longer Than 30 Days 59 Attachment 3 ECU In Effect Longer Than 60 Days 60 Attachment 4 Breaker/Valve Alignment Sheet 61 Attachment 5 Local Joint Advisory Safety Committee (LJASC) & Nuclear Joint Safety Committee (NJSC) Review Form 62 Attachment 6 Starter Main Contacts and Fuse Removal Form 63 Attachment 7 ECU Checklist 64 Wt7. IP/nw/nw/ric

1.0 PURPOSE 1.1 This procedure provides guidance in the use of Equipment Clearance Orders (ECO) for the isolation of equipment to protect personnel from energy sources, for the use of other controls when isolation is NOT possible and for administrative control of equipment. I 10 Compliance with this procedure provides a safe working environment for personnel and equipment. Changes to this procedure shall be reviewed by the Nuclear Division Joint Safety Committee (NJSC). I _ = = = = = _ = = = =

2.0 REFERENCES

/RECORDS REOUIRED/COMMITMENT DOCUMENTS 2.1 References 2.1.1 Quality Instructions/Plant Procedures

1. QI 3-PTN-l, Design Control

2. QI 14-PTN-1, Inspection, Test and Operating Status

3. 0-ADM-0 16.3, Fire Protection Impairments

4. 0-ADM031, Independent Verification

5. 0-ADM-033, PTN Industrial Safety Program

6. 0-ADM-200, Conduct of Operations

7. 0-ADM-205, Administrative Control of Valves, Locks and Switches

8. 0-ADM-212, In-Plant Equipment Clearance Orders

9. 0-ADM-213, Tech Spec Related Equipment Out-of-Service Logbook

10. 0-ADM-217, Conduct of Infrequently Performed Tests and Evolutions

11. 0-ADM-70 1, Control of Plant Work Activities

12. 0-GME-005.1, 4.16KV Equipment Grounding and Testing

13. 0-PME-005.6, 4160V A and B Bus Inspection and Cleaning

14. 0-PME-090.1, Power Generator Grounding

15. 0-OSP-200.1, Schedule of Plant Checks and Surveillances

16. ADM-09.08, ST. Lucie Plant Operations In Plant Clearance Orders VIçi7*. IF/nw/nwk1

2.1.2 Regulatory Guidelines

1. INPO Good Practice 87-002, Tagging Procedures for the Protection of Personnel, Components, and Systems

2. NTJREG 0737

3. 10 CFR 50 Appendix B, Criterion XIV, Inspection, Test, and Operating Status

4. OSHA Standard 29 CFR 19 10.269, Electrical Power Generation 2.1.3 Miscellaneous Documents (i.e., PC/M, Correspondence)

1. FPL Safe Work Practices Book

2. CR-96-1106, Control of Excess Material Inside Containment (PTN-ENG-SENS-96-077)

3. PNSC 96-217, 10 CFR 50.59, Safety Screening Format

4. CR-00-0910, Human Error Related Events 2.2 Records Required 2.2.1 Completed copies of the below listed items constitute Quality Assurance records and shall be transmitted to QA Records for retention in accordance with Quality Assurance Record Program requirements:

1. None 2.2.2 Completed copies of the Nuclear Joint Safety Committee (NJSC) Review Form should be routed to Safety Department for record keeping.

WQ7. IF/nw/nw/iIq

2.3 Commitment Documents 2.3.1 NIR 88-07, Failure to Maintain Clearance on Non- Seismic Gauges 2.3.2 PTN-PMN-88-313, CAR 88-016 Dated June 21, 1988, Temporary Lifts Being Abused 2.3.3 PTN-PMN-88-361, CAR 88-025 Dated July 21, 1988 2.3.4 FOP 92-039, Both Shutdown Cooling Relief Valves Found Disabled, PSL Problem Report (PRIIHE-92-O1O) 2.3.5 NIR 89-45 C/A 4, C: Administrative Controls for Hose Connections Upon Closure of Associated Clearance, CTRAC 89-1552-34 2.3.6 NIR 94-0 1, USNRC Resident Inspectors Monthly Report 2.3.7 QAO-PTN-94-008, Inadequate Equipment Administrative Control for Work on Flux Mapper Guide Tube RCS Non-Isolable Integrity Breach 2.3.8 OSHA STANDARD 29 CFR 1910.269, Electric Power Generation, Transmission and Distribution; Electrical Protective Equipment; Final Rule 2.3.9 PTN-ENG-SEMS-96-070, Biocide Treatment of Closed Cooling Water Systems 2.3.10 LER 2003-005-00, Disabling Both Auxiliary Feedwater Trains Inadvertently During Mode 3 W7. IP/nw/nw/nI

3.0 RESPONSIBILITIES 3.1 Operations Manager 3.1.1 Approves the hanging of ECO tags in the containment during Modes 1 and 2. [Commitment Step 2.3.31 3.2 Assistant Operations Manager 3.2.1 Acts on the results of the periodic ECU review. 3.3 Senior Reactor Operator (SRO 3.3.1 Verifies the adequacy of ECU boundaries. 3.3.2 Approves review of all ECOs. 3.3.3 Authorizes all ECOs. 3.3.4 Approves ECO boundary modifications. 3.3.5 Ensures adherence to Technical Specification requirements for equipment operability, limiting conditions for operation, equipment redundancy, surveillance testing, and containment integrity. 3.3.6 Approves ECU revisions and verifies boundary modification is not required. NOTE I The System Engineer may be consulted to determine if execution of an ECO will result in the plant being operated in a condition other than described in the UFSAR. I 1_. = = = = = I 3.3.7 Determines if a 10 CFR 50.59 evaluation is needed in accordance with ECO in Effect Longer Than 60 Days (similar to Attachment 3). 3.3.8 When issuing or releasing an ECU, ensures applicable valves, locks, and switches under administrative control are properly denoted on the order (i.e., designated LOCKED OPEN or LOCKED CLOSED) in accordance with 0-ADM-205, Administrative Control of Valves, Locks and Switches. 3.3.9 Directs Reactor operator or qualified operator to prepare and execute ECOs. 3.3.10 Resolves ECU discrepancies in the field. 3.3.11 Ensures the person issued an ECU is on the authorized list. 3.3.12 Directs operators to execute ECOs. 3.3.13 Verifies ECU boundary is adequate for attached work orders and prior to attaching new work orders or executing boundary mods / revisions. WQ7. FIr,wInwIr

3.3.14 Directs the writing of ECOs. 3.3.15 Supports the Plan of the Day (POD) ECO List. 3.3.16 Authorizes and reviews the realignment of ECOs that have been released. 3.3.17 Ensures that operators are briefed on the purpose of the ECO and conditions that should be established inside the boundary for safe performance of work. 3.4 Shift Manager (SM) 3.4.1 Performs all duties under Senior Reactor Operators (SRO). 3.4.2 Notifies the Unit Supervisor and Reactor Operator of ECOs affecting Technical Specification, safety related, risk significant or in-service systems during an outage. 3.4.3 Reviews all ECOs active for greater than 30 days. 3.5 Unit Supervisor (US) 3.5.1 Performs all duties under Senior Reactor Operator (SRO). 3.5.2 Reviews Temporary System Alterations (TSA) for affect on ECO boundaries. 3.5.3 When an ECO is executed or released, updates the Equipment Out-of-Service Log (EOOS). 3.5.4 If a conflict is identified between computerized clearance system and the hard copy of the ECO, directs an investigation. CAUTION The TPCW System, CCW System, EDO Cooling Water Systems, and the Chilled Water Systems for the 4160/480 Switchgear Rooms, Vital Electrical Equipment Room, Computer Room, and Cable Spreading Room may contain biocides that present a personnel safety or chemical release hazard. (Commitment Step 2.3.9J 3.5.5 Obtains verification from Chemistry that NO biocide hazard exists prior to issuing an ECO on the TPCW System, CCW System, EDG Cooling Water Systems, or one of the Chilled Water Systems for the 4160/480 Switchgear Rooms, Vital Electrical Equipment Room, Computer Room, or Cable Spreading Room that require the draining of liquid from the system. [Commitment Step 2.3.9} AIQ7 IP!n,,/n,,,frI,

3.6 Work Control Center Supervisor (WCCS) 3.6.1 Performs all duties under Senior Reactor Operators (SRO). Performs all duties under Unit Supervisor. 3.6.3 Reviews ECOs. 3.7 Nuclear Watch Engineer/Field Supervisor 3.7.1 Coordinates ECO activities outside the Control Room. 3.7.2 Performs ECO activities delegated by the SMIUS. 3.8 Reactor Onerator (RO or AT]thnri7eH ()ner2tor 3.8.1 Ensures the person issued an ECO is on the authorized list. 3.8.2 Researches ECO boundaries. 3.8.3 Writes Master ECOs. 3.8.4 Writes ECOs, also includes the restoration position of the components using documents such as prints, procedures, and attachments. 3.8.5 Directs operators to execute ECOs. 3.8.6 Executes ECOs for equipment they are qualified to operate. 3.8.7 Briefs operators on the following:

1. The purpose of an ECO to be executed.

2. The conditions that should be established within the ECO boundary for safe performance of work (non-outage).

3.8.8 Reviews the ECO to verify proper alignment of all components within the ECO boundary upon release. 3.8.9 Ensures computerized database is updated for all ECO status changes and step manipulations via boundary modifications. 3.8.10 When issuing or releasing an ECO, ensures applicable valves, locks, and switches under administrative control are properly denoted on the order (i.e., designated LOCKED OPEN or LOCKED CLOSED) in accordance with 0-ADM-205, Administrative Control of Valves, Locks, and Switches. Wq7. lI/nw/nwkI

3.9 qualified Operator 3.9.1 Executes ECOs as written and in the sequence detailed. 3.9.2 Performs ECO activities delegated by the SMIUS/WCCS/NWE/FS/SRO. 3.10 Shift Technical Advisor 3.10.1 Assists SMIUS/WCCS in determining if a 10 CFR 50.59 Applicability DeterminationlScreening/Evaluation is needed prior to authorizing an ECO. 3.10.2 If an ECO has been in effect for more than 60 days AND a 10 CFR 50.59 Applicability Determination / Screening has NOT been previously performed, ensures a 10 CFR 50.59, Applicability Determination / Screening review of the ECOs is performed in accordance with 0-ADM104, 10 CFR 50.59 Applicability / Screening Reviews. 3.10.3 If the Applicability Determination / Screening review identifies a 10 CFR 50.59 evaluation is required, a Condition Report should be generated to address the condition. 3.11 Safety Supervisor 3.11.1 Ensure that an annual evaluation is conducted and documented to verify plant personnel that use this procedure are trained in the purpose and use of this procedure. 3.11.2 Results of the annual evaluations shall be provided to the Training Manager for incorporation into the annual training of the ECO process. 3.12 Training Manager 3.12.1 Provides initial training on this procedure for all employees who write, execute, or release ECOs. 3.12.2 Provides pre4mplementation training on this procedure whenever there is a change in the procedure which affects safety. 3.12.3 Provides annual training on this procedure. WQ7. lP/nw/nw/nlc

3.13 Chemistry Department Supervisor NOTE The determination that biocides are NOT present in the system may be determined by the system histoiy (no biocides have been added), previously obtained acceptable sample results (no biocides have been added since last acceptable sample), or by determining current samples do NOT contain biocides above acceptable levels (biocides have been added to the system and a previous sample has shown acceptable concentrations of biocides needed for personnel safety or liquid releases). [Commitment Step 2.3.9] 3.13.1 Upon request from the US or WCCS, determines if a biocide personnel safety or release hazard exists prior to the authorization of an ECO. 3.13.2 Notifies the US or WCCS of the results of the biocide determination and whether or not the system is safe for draining. [Commitment Step 2.3.9] 3.14 Operations Outage Shift Director 3.14.1 Approves the attachment of Outage work to existing ECOs and the hanging of outage ECOs after the start of the outage. The Owner of the Work Order shall be notified of the addition. 3.14.2 Directs outage ECOs under the direction of the SM. 3.14.3 Notifies the SM of all ECOs affecting Tech Spec, Safety Related, Risk Significant, or in-service system. [Commitment Step 2.3.9] 3.15 Nuclear Joint Safety Committee (NJSCO 3.15.1 The Nuclear Joint Safety Committee is responsible for reviewing and approving exceptions to the guidance of this procedure on a case-by-case basis, prior to implementation. WQ7. T/nw/nw/rI

3.16 Lead Maintenance Discipline (LMD) Reviewer 3.16.1 Responsible for reviewing the ECO for a work order assigned to their group. If possible the LMD reviewer should be the individual who will be the ECO Owner. 3.16.2 The LIVID reviewer shall:

1. Provide an independent review of the Clearance.

2. Verify that a safe work boundary has been prepared, using available references and/or walkdowns.

3. Specifying any unique requirements (i.e., Component prepositioning, etc.)

needed in the ECO to place the work in a safe condition.

4. Verify the Work Order Task(s) is assigned to the Clearance.

5. Review the information provided in the Clearance Detail tab for descriptions, purpose, hazards, and sequencing instructions.

6. Document approval for their assigned Work Orders / Tasks by signing as 2nd verifier under the Work Order Task tab.

4.0 DEFI[%ITIONS 4.1 Authorized Operator An operator authorized to perform tasks associated with ECOs. This person shall be authorized by the Assistant Operations Manager or designee and shall have completed required ECO training. 4.2 Bus Outage Tag A device or method that allows the Bus Outage Clearance ECO jurisdiction over the individual ECO isolation tags at breakers. Information is provided at the individual breakers to inform holders that the electrical isolation for individual clearances is provided by the Bus Clearance. 4.3 Concurrent Verification (CV) Concurrent Verification is the verification of operations, testing, and maintenance activities that is performed concurrent with the activity by a second individual. CV is a preferred alternative to an Independent Verification where an IV is impractical or where immediate potential adverse affects to the plant would occur if the component were incorrectly positioned. CV incorporates and depends upon good three-way communication and peer checking. Instances where CV would be preferred to an IV include but are not limited to, throttling a valve and testing, calibrations, or lineups that are done utilizing the procedure in the reader/doer mode. 4.4 ECO Boundary Modification A change that expands or reduces an existing clearance boundary to facilitate maintenance or testing. 4.5 ECO Boundary Modification Form A form used to list the proposed boundary changes and to document the approval to perform these changes. 4.6 ECO Control Form A form signed (electronically) by the ECO Owner and holders to document verification of the adequacy of the ECO boundary. 4.7 ECO Information Tag A tag hung on or near component switches or display gauges to indicate its associated equipment is located within or affected by an ECO boundary. Wfl7. IP/nw/nwkls

4.8 ECO Preparer The Reactor Operator or authorized operator who writes an ECO or ECO Boundary modification. 4.9 ECO Release Occurs when all ECO holders/owner release their right to work and their right to protection within the ECO boundary by signing in the ECO Release section of all applicable ECO Owner/holder Forms. 4.10 ECO Revision A modification to an existing ECO that does not alter the existing ECO ISOLATION boundary but could enhance the ECO boundary in the conservative direction to increase worker safety. 4.11 ECO Holder An individual who is authorized and qualified to work or support work within an ECO boundary. In order for an individual to be considered qualified, they shall have attended and successfully completed an approved training course on the ECO process. 4.12 ECO Tag A tag hung on all boundary points that isolate equipment from sources of energy to permit work to be performed safely. Tagout devices, including their means of attachment, shall be substantial enough to prevent inadvertent or accidental removal. Tagout device attachment means shall be of a non-reusable type, attachable by hand, self-locking and non-releasable, with a minimum unlocking strength of no less than 50 pounds and shall have the general design and basic characteristics of being equivalent to a 1 piece, all environment tolerant nylon cable tie. 4.13 Equipment Clearance Order (ECO) A formal order for administrative control on plant components and/or systems, delineating the method for configuring plant equipment where isolation is possible, or for control of system parameters (i.e., level, pressure) where isolation is not possible, which permits safe entry for construction, testing, maintenance, or inspection. Each ECO must be comprehensive in nature to establish an adequate boundary. The ECO cannot rely on plant conditions that are not identified and controlled on the equipment clearance order, boundaries established by other ECOs, or system configurations outside an ECO boundary to provide personnel and equipment protection. 4.14 Lead Maintenance Discipline (LIVID) Reviewer A supervisor / GML or responsible individual in the department assigned to perform work for a particular Work Order and who is assigned to review the ECO for that work order. 4.15 Letter Designation In some instances there will be a letter designation at the end of an ECO number. This designation is optional and will indicate the general type or purpose of the ECO. The letter options used will be as follows: 4.15.1 7 Administrative A 4.15.2 C Caution Tag 4.15.3 H-Hydro 4.15.4 I Integrity 4.15.5 L-LLRT 4.15.6 R Outage Related W97:JE/nw/nw/cls

4.15 (Contd) 4.15.7 T-Test 4.15.8 M Management 4.15.9 S - Short Notice Outage (SNO) 4.16 Master ECU A previously researched ECU boundary stored in computer database. 4.17 Operating Permit Tag A tag that gives the personnel holding the clearance authority to manipulate tagged components in order to facilitate Maintenance Department testing or minor repairs. This tag requires permission to operate from an SRO. Operating Permit tags are under the direct control of a single owner and provide a visual warning marking the isolation boundary for equipment or systems in order to prevent personnel injury or equipment damage. 4.18 Outane Owner/ECU Coordinator An individual may be appointed when the number of personnel and/or clearances are above normal. This Coordinator shall be qualified in In-Plant Clearances Requirements. The Coordinator will assume the responsibilities of an Owner for all work assigned to an outage zone clearance and act as a liaison between Operations and the individual department Owners and Holders. Licensed operators meet this qualification criteria. 4.19 Qualified 10 CFR 50.59 Reviewer Any person that meets the 10 CFR 50.59 Screening training requirements, possesses the requisite experience to competently analyze the proposed change/activity and is on the qualified reviewers list. 4.20 Qualified Operator - Operators who have successfully completed all requirements necessary to operate the equipment on which the ECU is to be executed. 4.21 10 CFR 50.59 Applicability Determination/Screening Review Performed to determine if an ECU requires an evaluation under 10 CFR 50.59(c)(2) criteria. 4.22 Safety Related Any system, subsystem, display, or instrumentation that is required for the safe shutdown of the plant or is used to minimize the release of radiation to the public. 4.23 Tags Plus Physical actions or measures, such as two tagged valves in series, one tagged with a device that prevents operation, or other physical barriers that are needed to protect workers performing work on a tagged circuit or system from the re-energizing of that circuit or refill/repressurization of the system resulting from a single human error or mistake. 4.24 Tag Sharing The process in which the computerized database assigns a specific tag number to an ECO section to create a clearance boundary that may be common to other sections. W97:JE/nw/nw/c!s

4.25 Tag Type Hierarchy Tags associated with equipment clearance orders have a specific hierarchy that must be adhered to. It is possible that more than one tag type may be assigned to a plant component at the same time. The position of the component is controlled by the tag type in the following order: 4.25.1 Danger Tag This tag controls the position of any component. The position of the component may not be altered in any way with the exception of those danger tags properly controlled under a bus outage tag. 4.25.2 Bus Outage Tag This tag, when properly authorized, may transfer jurisdiction of a component under a danger tag to the established boundaries of a bus outage clearance. 4.25.3 Operating Permit Tag - This tag gives the personnel holding the clearance authority to manipulate the tagged component, provided permission has been obtained by an SRO prior to manipulation. 4.25.4 Caution Tag This tag is used to identify conditions that are unusual, potentially hazardous, or to provide cautionary information for operating equipment. Equipment governed by a caution tag can be manipulated with SRO approval. Because caution tags can be manipulated, required positions should not be used for personnel protection. If a required position is needed, then a danger tag should be used. (Caution tag clearances for maintaining configuration control are excluded from this requirement.) 4.25.5 Information Tag- This tag provides information only and does not control the position of the component. 4.26 Tech Spec Related Components, equipment, or systems whose operability is addressed by Technical Specifications. AIQ7. IInwInwkI,

5.0 PROCEDURE _i.t1 ES

              . ECO tags are warning devices affixed to energy isolating equipment and do NOT in themselves, provide a physical restraint.

I

Personnel NOT trained on this procedure, shall NOT perform ECOs. I D I o When tagged components are shared with multiple ECOs, caution should be used when restoring systems to ensure configuration control. Tag sharing warnings should be addressed, and the proper releasing order of sections that shared tags should be verified by the SRO.
A Caution tag is used to identify conditions that are unusua potentially hazardous, or I to provide cautionaiy information for operatmg equipment. Equipment governed by a caution tag can be manipulated with SRO approval. Because caution tags can be manipulated, required positions should not be used for personnel protection. If a i position is needed, then a danger tag should be used. (Caution tag clearances required for maintaining configuration control are excluded from this requirement.)

I 5.1 Standard ECU Practices 5.1.1 Equipment, on which an ECO has been granted, shall NOT be considered safe until tests have been made using approved methods to verify that the equipment is de-energized, grounded, drained andlor depressurized as required. 5.1.2 ECU tags shall be conspicuously posted so that the component can NOT be operated without the tag being seen. 5.1.3 An ECU shall NOT be utilized as a means of bypassing procedural requirements. 5.1.4 When any special instruction can be verified with an action, it should be written as a step in the ECU; otherwise, it should be included as a note in the Instruction block. 5.1.5 When hanging ECU tags, electrical switching should be performed first. 5.1.6 When removing ECO tags, electrical switching should be performed last. 5.1.7 ECU tags hung on control panels shall be secured in a manner that allows accessibility to controls without obscuring plant status indicators, controls, switches, and labels. 5.1.8 Controlled documents, such as prints, procedures, and attachments, shall be consulted to determine ECU boundaries.

1. When controlled documents are NOT available, additional measures shall be taken to ensure an adequate boundary is established, and the ECU holders shall be advised.

5.1.9 Prior to approving an ECU, it shall be DETERMiNED the impact on equipment availability as required to meet Technical Specification. Wq7. IP/nw/nw/rI

5.1.10 The ECO Tag Hang List shall be IN HAND USED as a guide during execution. 5.1.11 When ECOs are executed in contaminated areas, outdoors during inclement weather, or for large ECOs:

1. An exact copy of the ECO may be used.

2. Information recorded on the exact copy shall be transferred to the original as soon as possible upon completion.

5.1.12 An ECO information tag should be placed on or near component switches or display gauges to indicate the associated equipment is within or affected by an ECO boundary.

1. Independent verification of ECO information tags is not required.

2. ECO information tags shall not be used on ECO boundary components in lieu of an ECO tag.

3. An ECO Order step shall be written to control each ECO information tag.

4. Manipulation of a component or switch with an Information Only Tag is permitted.

5.1.13 If an ECO tag is removed from a component for any reason, the tag will be ACCOUNTED for and DOCUMENTED on the ECO.

1. At NO time shall an ECO tag be REMOVED and subsequently RE-HUNG, bypassed or ignored.

2. The Bus Outage Tag (which are placed over Danger Tags) may transfer jurisdiction of a danger tag to the isolation boundaries associated with a bus clearance in accordance with provisions of this procedure.

3. IF the original ECO tag is removed, lost or destroyed, the ECO boundary must be re-established, THEN a new ECO tag shall be issued.

5.1.14 During the Independent Verification/Concurrent Verification of the ECO, the ECO Form shall be initialed after the IV/CV for that step has been completed. 5.1.15 Tag placement shall only be DONE after the component is manipulated to its required position per the ECO. 5.1.16 In cases where isolation boundaries can NOT be established for work affecting the pressure boundary (e.g., work on the Reactor Vessel head, pressurizer or steam generator primary or secondary sides), an ECO which is controlled by Operations, as well as other departments performing said work, shall be generated.

1. This ECO shall list all such work.

2. This ECO shall place ECO Tags, with the ECO number, on in-service level, temperature or pressure instruments which would be used to control fill and vent operations.

W7. IT/nw/nw/.Ic

5.1.16 (Contd)

3. A vent path shall be established as determined by Operations.

4. Caution tags should be placed on Control Room valve/component switches that if manipulated could affect the clearance boundary and/or plant parameters that are being controlled during an un-isolable configuration.

These Caution tags shall warn that manipulation of these components could jeopardize the safety of personnel working under this ECO. 5 This ECO shall also include the following statement in the Instruction section of the ECO Form: This is an ECO for an un-isolable system. Parameters are being maintained by the Operations shift for control of protective conditions. 5.1.17 Tags shall be legible, understandable, and capable of withstanding environmental conditions. 5.1.18 Tags should be securely attached to energy isolating devices so that they can not be inadvertently or accidentally detached during use. 5.1 .19 Where a tag can NOT be affixed directly to the energy isolating device, the tag shall be located as close as safely possible to the device, in a position that will be immediately obvious to anyone attempting to operate the device. 5.1.20 For configuration control, the Operations Department may use the Breaker/Valve Alignment Sheet, a form similar to Attachment 4 of this procedure. This sheet SHALL NOT be used in place of an ECO or in place of a Caution Tag ECO.

1. The SM or SRO designee shall approve the Breaker/Valve Alignment Sheet after performing the following:

a. Verify that the specified steps satisfy the requirements of the activity being performed.

b. Verify that plant conditions (TSAs, current alignment, active ECOs, testing, etc.) will support the manipulation of the component(s) listed.

c. Verify that Containment Integrity is maintained, as required.

d. Verify compliance with Technical Specifications.

e. Determine which steps require use of CV, and annotate those steps on the Sheet.

f. Verify that the sequence of steps is correct.

2. If doubt exists as to whether the execution of the Breaker/Valve Alignment Sheet will result in the plant being operated in a condition that adversely affects an TJFSAR described design function, the SMISRO shall refer to the questions listed on the 10 CFR 50.59 Applicability Determination/Screening to determine if a 10 CFR 50.59 Evaluation is needed.

Wq7 IP/nw/nwIrc

Procedure No.: Procedure

Title:

Page: 20 Approval Date: 0-ADM-212.1 Operations In-Plant Equipment Clearance Orders 2/5/11 5.1.21 If an ECO will require a 120V Vital AC or 125V Vital DC Breaker to be opened that has not been authorized in accordance with an approved plant procedure, the Engineering department SHALL sign the Engineering Review block to indicate that an independent review has been completed. (Reference CR 03-0406) 5.1.22 For clearance tags issued on a bistable located in the Control Room, the tags should be secured to the rack door in clear view of anyone entering the protection or control rack. 5.1.23 Operating Permit tags must be hung in a manner that allows Maintenance personnel to manipulate a component without removing the tag. 5.1.24 Site and Division clearance boundaries should not overlap. Prior to issuing a Site clearance to be hung, ensure Site Area Operations (SAO) has shifted their clearance boundaries to not conflict with the Site clearance. Example: Transfer ofjurisdiction for the main generator to the Site from Division. 5.2 Tags Plus Tags Plus is intended to keep a worker safe in case a person makes a single or inadvertent error or mistake, involving one or more tagged devices, that could adversely affect the control of energy within a tagging clearance. Tags Plus applies only to DANGER and OPERATTNG PERMIT tagged components. 1 Tags Plus is indicated by Plus in the ECO component position field on the ECO and on the Danger Tag component position. I I__Is a a I 5.2.1 Tags Plus is a physical action or measure, NOT a behavior, culture, or administrative procedure. 5.2.2 Operation means manual and remote manipulation of an isolating device to the extent that it affects a change in the state of the energy it controls, or activation of a device or system by a human-error induced contact, whether by a person or by material or equipment operated, set in motion, carried, or handled by a person. 5.2.3 Tags Plus, like lockout / tagout in general, is intended to guard against human error, NOT equipment malfunction. 5.2.4 Tags Plus is NOT intended to prevent an action or event that is consciously intended to overcome or defeat the tagged isolation. Wç7. ll/nw/nw/ric

Procedure No. Procedure

Title:

Page: U Approval Date: 0-ADM-212.1 Operations In-Plant Equipment Clearance Orders 11/24/08 5.2.5 Examples of Tags Plus:

Two tagged valves in series, such that operation of only one would NOT reenergize the system.

o One tagged valve with a device preventing the valve from being operated. o On a device capable of being locked out, the tags attachment means (tie wrap) being placed through the fittings intended for a lock such that the attachment means would prevent the device from being operated.

Grounding of an electrical circuit, if the grounding practices would protect the worker if a tagged isolating device were operated.
Isolation by inaccessible location if the device can be accessed only by the use of extraordinary means (e.g., 15 portable ladder or scissors lift that is NOT already in position).

o Removal of a valve handle on a tagged valve.

Secure placement of a barrier or blocking device adequate to physically prevent a tagged control switch from being operated.

o Removal of a fuse and tagging the fuse box, or racking out, and tagging a breaker, in the circuit of a tagged component. 5.2.6 Examples of actions that are NOT Tags Plus

Testing for potential, because this merely verifies that the tagged electrical isolating device is in the proper position and the circuit is NOT energized.

The inadvertent operation of that device would still energize the circuit.

Placing two tags on the same device, because this would NOT prevent the inadvertent operation of that device.

o Verbal warnings, instructions, or training NOT to touch a tagged device because these would NOT prevent inadvertent operation of the device. o Isolation by accessible location including but NOT limited to restricted areas and rooms, infrequently-visited sites, devices accessible by the use of ordinary means (e.g., step ladder or shotgun stick), and areas with installed means of access (e.g., fixed ladders). If the device is or should be tagged, the presumption is made that a Tags Plus measure can be applied to it. o Dual, peer, or independent verification of tagging because such verification is NOT a physical measure. \A!07

Procedure No.: Procedure

Title:

Page: 22 Approval Date: 0-ADM-2 12.1 Operations In-Plant Equipment Clearance Orders 11/24/08 5.2.7 Devices NOT Capable of Being Locked Out In the rare circumstance in which it is physically impossible to apply a Tags Plus measure to a circuit or system that can be energized only by the operation of a single isolating device, and is NOT capable of being locked out, additional actions are still necessary to minimize opportunities for inadvertent operation of the device or re-energizing the system. Examples of these actions include: o Erecting barricades or installing barrier tape with signs to restrict access to the workspace around the device

Installing shields, placing warning signs to supplement the tags (which are warning labels themselves)
Posting a guard, or
Taking other engineering or administrative actions appropriate to the situation.

5.2.8 Examples of Components Locked out under Tags Plus

1. Valves:

Two valves tagged closed in series.
One valve locked and tagged in required position.

o One valve with the operator removed.

                                °     Valve blocked and tagged in required position.

2. Breakers:

o Power panel breakers locked open and tagged.

MCCs, Unit Substations breakers locked open or racked out with locking device and tagged.
4.16 KV and 6.9 KV breakers locked off bus (NOT in connected position) or removed with blocking device installed and tagged.
Local disconnects locked open and tagged.

3. Fuses:

Fuse removed and blocking device installed when possible.

4. Lifting Leads:

Lifting leads and taping the end of the leads.

W97:JE/nw/nw/cls

Procedure No.: Procedure

Title:

Page: Approval Date: O-ADM-212.1 Operations In-Plant Equipment Clearance Orders 2/5/11 [h1 NOTES

Other components used for isolation will be evaluated by an SRO for the method of isolation to comply with Tags Plus.

a Vent and drain valves are LQ..required to be locked.

                          =                                                                     I 5.3     Valve Practices 5.3.1      Establishing an ECO Boundary around a Motor Operated Valve (MOV)

1. To perform maintenance on the valve portion of the MOV, the breaker shall be Danger tagged open and the isolation valves shall be Danger tagged closed, including inner disc relief isolation valves if the MOV is a double disc valve.

2. To perform maintenance on the motor actuator or gear box portion of the MOV, the breaker shall be tagged with an Operating Permit Tag attached to the breaker in the OFF position, and NO tag on handwheel.

3. If the stem nut locknut or the upper bearing housing is to be removed:

a. The isolation valve(s) shall be tagged closed, and a means to vent and drain the piping is provided, OR

b. A stem locking device shall be provided and tagged DO NOT REMOVE.

OR

c. Static conditions limited to a maximum of 50 psig will be provided by the ECO boundary. Components or valves will be tagged to ensure the static conditions are maintained for the duration of the MOVATs testing or actuator overhaul. Pressure at the valve will be verifiable by observation of system pressure or system vented to atmospheric pressure (ie., Vent valve tagged open, head removed, or safety removed and tagged). The MOV under MOVATs will be initially in the open position on the hang of the ECO.

4. When MOVATS is to be performed:

a. Ensure the system/component is isolated prior to stroking the valve OR

b. Ensure that any stroke will NOT affect/cause system flow.

W97:JE/nw/nw/cls

Procedure No.: Procedure

Title:

Page: 24 Approval Date: 0-ADM-212.1 Operations In-Plant Equipment Clearance Orders 11/24/08 CAUTION MOV declutching may result in the shearing of the torque switch roll pin, and further torquing of the valve after it is declutched could result in serious valve damage. 5.3.2 MOVs may be used as isolation points of an ECO boundary provided the breaker is tagged open and the handwheel is tagged DO NOT OPERATE, or the MOV is blocked with a mechanical blocking device which is tagged DO NOT REMOVE. 5.3.3 A pneumatically operated valve may be used as an isolation point of an ECO boundary provided:

1. A fail closed valve shall:

a. Be visually verified to be closed locally or by the use of light indications remotely, and

b. Have its gas supply isolated and tagged, or

c. Have its control power fuses removed and tagged, and

d. For valves which have handwheels, the handwheel is tagged appropriately, (i.e., locked in up position, neutral, etc.), depending on the type of valve.

e. Valves without handwheels shall be tagged on the valve body Valve Must Remain Closed.

2. A fail open valve shall be closed with jacking, or gagging device installed which is tagged DO NOT REMOVE or ON IIAN])JACK.

5.3.4 The following applies to installed system pressure operated valves or relief valves:

1. Installation of any physical restraint, jacking device, or gagging device shall be CONTROLLED by an In-Plant Equipment Clearance Order and tagged appropriately.

2. System pressure operated valves or relief valves shall NOT be USED as an isolation point of an ECO boundary unless:

a. Downstream pressure is at atmospheric pressure and not capable of being pressurized (i.e., manway removed and tagged, tank by designed is maintained at atmospheric pressure etc. .

OR

b. The valve is physically restrained in the required position through the use of an installed jacking or gagging device which is tagged DO NOT REMOVE. If the valves can NOT be gagged or jacked, the Safety Department shall be NOTIFIED to approve actions to safely work on the system.

W97:JE/nw/nw/cls

5.3.4 (Contdl

3. Physical restraints, jacking devices, or gagging devices shall NOT be APPLIED to a valve in an operable system without a 10 CFR 50.59 evaluation which is reviewed by the PNSC and approved by the Plant General Manager, Vice President Turkey Point Nuclear Plant and Chief Nuclear Officer.

5.3.5 Valves required to be operated or repaired during the performance of the work order shall NOT be tagged except for:

1. When re-packing a valve on the backseat, the valve shall be tagged in the BACKSEATED position and additional ECO boundaries shall be established (as necessary) to ensure the valve is subject only to pressure from a static elevation head of water or a system pressure less than 50 psig.

5.3.6 Vents and drains that are being repaired shall have a step in the ECO for positioning the valve when the ECO is released. 5.3.7 MSIVs shall be controlled as follows: (not applicable in Mode 5, Mode 6, or Defueled)

1. Tag MSIV control switches in CLOSE for administrative control of switches.

2. Pull and tag fuses for 1 train of solenoids for each MSIV.

3. If loss of instrument air or power to the remaining train of MSIV solenoids occurs, refer to check valve requirements.

CAUTION Draining systems, which contain environmentally hazardous chemicals such as oil or hydrazine, shall be conducted in accordance with O-ADM-015. 1, Chemical Control Program. 5.3.8 Drain valves used for draining a fluid within the ECO boundaries shall be throttled and the Drain System into which it is draining shall be monitored to ensure that this Drain System can accept the flow rate from the drain without over flowing.

1. This shall be designated as a step in the ECO prior to the step to tag the drain valve. This step should state throttle the drain valve, (Valve Number), to the flow rate of Drain System.

2. When opening a drain or vent valve on a filled or pressurized system, and fluid or gas does NOT flow from the valve, notify the SRO to request that Mechanical Maintenance try and unplug the drain. If the drain can NOT be cleared, add a caution statement to the ECO delineating the clogged valve and the potential for the system to still be pressurized.

W97:JE/nw!nw/cls

5.3.9 If the need arises to add vents or drains to an existing ECU, the US shall grant permission to modify the ECO as required. A boundary modification is NOT required solely to add vents or drains. 5.3.10 When a blocking device is installed on a valve, that valve/component shall be declared out of service, unless a 10 CFR 50.59 evaluation is written to address the stem block.

1. When determining which component will be out of service, assume the stem block fails, and the valve travels to the worst case position.

5.3.1 1 The valve operator used to manipulate floor valves shall be locked in its storage location when NOT in use. 5.3.12 A solenoid valve should NOT be used as a pressure boundary isolation if a manual isolation valve is readily available.

1. When a solenoid operated valve is used for an ECU boundary and the failure mode is NOT clear, request assistance from Engineering or Instrument and Control Departments to determine the correct failure mode.

2. When a solenoid operated valve is used and it does NOT fail in the required position, it shall be blocked or gagged in the required position, and an ECU tag shall be attached to the blocking device.

5.3.13 If NO other means of isolation exists, check valves may be used as an isolation point of an ECO boundary, provided prior PNSC review, Nuclear Joint Safety Committee (NJSC), and Plant General Manager approval is obtained. The following additional measures shall be taken:

1. The check valve shall be verified to be holding pressure prior to commencement of work.

2. A drain, open flanges, or other means of draining shall be continuously monitored for the duration of the work to ensure the check valve is NOT back leaking.

3. If the job is not being actively worked, constant MONITORING may be relaxed to a periodicity designated by Operations.

4. Place a note in the Instructions block of the ECU Form explaining that a check valve is part of the ECU boundary.

5. ECU holders shall be notified that a check valve is part of the boundary.

6. Nuclear Joint Safety Committee (NJSC) Review Form shall be used.

7. During outages, Risk Assessment Team review is required for issues that involve RCS inventory.

W7. IP/nw/nw/rk

5.3.14 Operation of Components Within an ECO Boundary

1. With the permission of the SMIUS/WCCS/NWE/FS/SRO, Maintenance personnel may MANIPULATE the component that is under repair or test only to the extent necessary to facilitate repairs or job completion.

2. All other component manipulations during the course of the repair shall be PERFORMED by qualified operators.

3. Instrument and Control personnel are ALLOWED to manipulate valves downstream of the main instrument root valves (five-valve manifold, internal isolations, etc.) for the performance of maintenance and calibrations.

Instruments with single root isolations may be MANIPULATED by I&C personnel provided IV provisions of the NPWO are followed.

4. Components within an ECO boundary may be manipulated by maintenance with approval from the SRO provided a restoration step is included on the ECO.

5.4 Electrical Practices 5.4.1 A component hand switch should NOT be used as an isolation point for establishing an ECO boundary for maintenance activities.

1. Hand switches/control switches may be used for isolation only for purpose of administrative control.

I NOTES I a Only a manually operated switch, visible air break, or a switch that can be locked or blocked in the open position will be regarded as clearing a circuit. I

      !     0  In 4.16kv switchgear and 480 volt load centers, breakers shall be racked-out.

I. 4.16kv DC control power fuses are not tagged unless specifically required when maintenance is performed on control circuit. I. In 480 volt Motor Control Centers, molded case breakers shall be opened. I I* Following notification to all applicable owners, a racked out and tagged 4.16kv I switchgear; 480 volt load center breaker; or a reactor trip circuit breaker may be placed in the test position if required. I 5.4.2 To de-energize components from 4160 volt power, the appropriate 4160 volt switchgear breakers shall be racked out and the breaker cubicle door tagged. 5.4.3 To de-energize a component powered from a 480 volt load center, its breaker shall be opened and racked out and tagged on the breaker cubicle door. jjIQ7.

5.4.4 To de-energize a component powered from a 480 volt Motor Control Center (MCC).

1. Normal method:

a. The appropriate molded case breaker shall be placed in OFF and tagged on the attached lug.

b. A Ty-wrap shall be placed on the locking device.

2. Alternate Method used when the breaker needs to be cycled for testing without the equipment operating (i.e., Safeguards, CCW System Flow Balance).

a. The appropriate molded case breaker shall be placed in OFF.

b. The line starter contacts for all three phases shall be removed and tagged.

c. Control power fuses for any related fan dampers shall be removed and tagged.

d. The line starter contacts (and fuses, if applicable) shall be placed in a transparent bag and affixed with the related ECO tag(s) to the attached lug.

e. The molded case breaker should be placed in ON.

f. Completed form similar to Attachment 6 shall be affixed to breaker.

5.4.5 A local knife switch will be verified as open and be tagged OPEN. 5.4.6 To remove component DC control power, the appropriate fuses shall be removed, and the fuse holder shall be tagged or the DC control power breaker shall be tagged OFF. 5.4.7 Motor Heater Breakers

1. Motor space heaters shall NOT be included in an ECO order if the motor is being used for an ECO boundary only.

2. Motor space heaters shall only be included in an ECO if the motor is being removed or if requested.

5.4.8 Electrical grounds shall not be installed unless they are delineated as a restoration step with no tag on the equipment clearance order. W97:JE/nwinw/cls

5.4.9 Fuses

1. ECO tags shall NOT be placed on fuses.

2. ECO tags associated with fuses shall be posted on or as close to the fuse holder as practical and in a location where they would be obvious to anyone intending to replace the fuses.

3. Usage of the fuse holder tagging devices is recommended to prevent electrical shock.

ENOTES

Leads may only be lifted on a component which was previously declared Out of Service.

Lifted leads should NOT normally be used as an ECO boundary. There are times when this is the most appropriate method for assuring personnel safety. Maintaining related equipment in a particular configuration may also be a consideration (e.g., multiple annunciator inputs or same power supply to different components). I I

Maintenance personnel will be granted access as necessary to sign for verification as required by the SRO.

a a a a I I 5.4.10 Lifted Leads

1. If lifted leads are determined to be an ECO boundary, appropriate discipline (I&C or EM) shall provide input as to lead designations, location, and potential related consequences.

2. If the qualified operator is NOT clear as to the exact lead on which to hang the ECO tag, the appropriate discipline (I&C or EM) Journeyman shall identify the lead for the operator to hang and perform concurrent verification.

5.5 Tank and Piping System Practices 5.5.1 If necessary for the performance of work; systems, portions of systems, and components that normally operate at temperatures or pressures above ambient shall be vented and drained before work is authorized. 5.5.2 An atmospheric drain or vent between the equipment to be worked and sources of pressure to the equipment should be verified in the open position to depressurize the equipment and to accommodate thermal expansion or contraction. W97:JE/nw/nw/cls

5.5.3 If a normal depressurization path can NOT be provided within the ECO boundary, other definitive measures shall be taken to verify the system or component is adequately depressurized and drained.

1. These measures may include:

a. Breaking of flanged connections

b. Loosening of valve bonnets

c. Removal of instrument tubing 5.5.4 When placing an ECO on equipment, the high-pressure side (pump discharge) should be ISOLATED prior to low-pressure side (pump suction) to prevent over pressurizing the low-pressure piping. For the same reason, un-isolate the suction (low-pressure) side of the pump first when releasing a clearance.

5.5.5 Hoses placed on vent/drain valves shall be listed/designated on the ECO as a step with NO tag. [Commitment Step 2.3.5] 5.6 ECO Log 5.6.1 Three ECO files shall be maintained:

1. Unit 3

2. Unit 4

3. Common 5.6.2 Each ECO file should contain executed ECOs filed by system or zone number.

5.7 Operating Permit Tags NOTES I

Only Operations personnel will issue Operating Permit Tags o Holders SHALL have the final decision if an Operating Permit tag will be used as part of the ECO

                 =            =     a            =      a      a     =       =     a     I 5.7.1    Operating Permit Tags are used to isolate energy to a component during performance of minor maintenance, minor repairs, and/Or testing when periodic re-energization/manipulation is required.

5.7.2 If conditions change or additional scope is identified, then the use of the Operating Permit Tag shall be re-evaluated by the Holder, Owner and SRO. W7. IIZ/nw/nw/rLc

Procedure No.: Procedure

Title:

Page: 31 Approval Date: O-ADM-2 12.1 Operations In-Plant Equipment Clearance Orders 2/5/11 5.7.3 Maintenance on components with Operating Permit Tags may be performed under the following conditions:

SRO approval to do the work
During periods when personnel or equipment protection is required and Operating Permit Tags are used, then the ECO Owner shall apply a lock(s) on the component to prohibit operation
When Holder(s) require the protection of an isolation device, the Owner shall place a lock on the device and place the key for this lock in a Group Lock Box o The Holder(s) shall place their individual locks on this Group Lock Box /

Locking Hasp while protection is required

When any of the following conditions are met, then Holder(s) individual lock(s) can be removed from the Group Lock Box / Locking Hasp:

1. Protection from isolation device is no longer required.

2. Work is completed.

3. Shifi is complete or turnover to another holder.

The lock(s) shall remain in place until a safe condition is established for its removal
If lock(s) are required, then lock(s) shall remain in place during turn over NOTE I Operating Permit Tags are under the direct control of a single Owner.

o During turnover the on-coming ECO Owner shall sign on the ECO, and the current ECO Owner shall sign off. The lock remain in place during turnover, if required. 5.7.4 Operating Permit Tags have the following restrictions:

1. Only one Operating Permit Tag may be on a single component at any time.

2. Operating Permit ECOs may have Danger Tags that make up the total ECO boundary combined with Operating Permit Tags for components allowed to be manipulated, (Example: MCC breaker for an MOV tagged with an Operating Permit Tag and the downstream isolation on the fluid system tagged with a Danger Tag to prevent movement of water).

5.7.5 All work assigned to Operating Permit Tagged components shall be owned by a single ECO Owner. The ECO Holder(s) is responsible for control and the proper use of locks. W07. IP/nw/nw/rI

5.7.6 Each Operating Permit Tag shall be designated with the respective work group owning the clearance during the preparation of the ECO. This work group designation will be placed in the Tag Note field by stating which LMD owns the Operating Permit Tags. 5.7.7 The ECO Owner and Holder(s) shall verify their Operating Permit tagged components are in the expected or desired position by performing a physical walkdown prior to starting work. 5.7.8 Designated ECO Owner shall get concurrence from all ECO Holder(s) prior to operation of or energizing Operating Permit tagged equipment to assure personnel and equipment safety. The method of concurrence and Owner designated to manipulate the Operating Permit Tag shall be determined during the tailboard briefing. 5.7.9 The ECO Owner designated shall contact a SRO for authorization prior to manipulating any Operating Permit Tag component. The ECO Owner designated may position or direct the positioning of the components (Unit Supervisor / SRO will determine the frequency of the notification). 5.7.10 Operating Permit Tags can be hung on components in the energized position (e.g. breaker closed, valve open). 5.7.11 Once a component is placed to the energy isolation position for personnel safety, the ECO Owner shall attach or direct the attachment of a lock prior to starting work. 5.7.12 Prior to manipulating an Operating Permit tagged component. The ECO Owner as a minimum shall review the following:

1. Status of the work (to include lifted leads, temporary configurations, etc.).

2. List of components to be manipulated.

3. The hazards / dangers to be aware of prior to adding energy to the ECO boundary.

5.7.13 Operating Permit tagged control switches are used to identify equipment under Operating Permit Tag control and are NOT required to have Tags Plus Protection. 5.7.14 Where a tag can NOT be affixed directly to the energy isolating device, the tag shall be located as close as safely possible to the device, in a position that will be immediately obvious to anyone attempting to operate the device. \AIQ7 IPInwInwIrIc

a a a a a NOTES o The Nuclear Joint Safety Committee SHALL be contacted for activities NOT on the list o Installation / removal of 480 VAC leads and installation / removal of stem nuts SHALL have a Danger Tag ECO a a a a a a I 5.7.15 Operating Permit Tags could be used for the following activities:

1. MOV Maintenance (VOTES / VIPER)

a. Limit switch and torque switch adjustments

b. Installation and removal of test equipment

c. Stem greasing and linkage adjustments

d. Installation / removal or lifting leads of 120 VAC or 125 VDC Leads

e. Installation / removal of kill switches f Installation / removal of limit or torque switches

g. Installation / removal of spring packs

2. Installation / removal of test equipment

3. Valve linkage and stem lubrication

4. Installation / removal of kill switches

5. Installation / removal of leads or jumpers 120 VAC or 125 VDC

6. Consolidation of valve packing (Manual / MOV / AOV)

7. Traveling screen work (PMs)

8. Breaker PMs

9. Battery Charger and Inverter PMs tests and troubleshooting (must be used with an ECO Danger Tag to disconnect equipment from the Bus)

10. Cranes (Polar, Gantry, Intake, etc.) Local Disconnects

11. Fan or AJC PMs (480 VAC or less)

12. Air Conditioning repair work

13. Remove / Install Pressure Indicators, D/P Gauges, Flow Transmitters and Indicators AICY7.

Procedure No.: Procedure

Title:

Page: Approval Date: O-ADM-212.1 Operations In-Plant Equipment Clearance Orders 2/17/11 5.7.15 (Contd)

14. Power Panels and Lighting Panels for repair of lighting and minor equipment repairs (NOT to be used for replacing motors)

15. Valve repack on the back seat per valve practices section of this procedure.

16. Transformer deluge testing.

17. Install and remove Stop Logs

18. Turbine Turning Gear (generator balancing, Exciter swing checks, Thrust bearing adjustments, Main Oil Pump extension shaft torquing, rolling rotor for coupling work) 5.8 ECO Research and Preparation 5.8.1 The US/WCCS/SRO designee should direct the Reactor Operator or Authorized Operator:

1. To research and write the ECO, OR

2. Associate the new Work Order with an existing ECO that has an adequate boundary.

a. IF the ECO is already reviewed or Authorized / Hung (green or red flagged). THEN the addition of the Work Order shall be performed as follows:

(1) The SM / US / WCCS / SRO shall: (a) With a peer check from another Authorized Operator, verify the isolation is adequate and add the Work Order Task to the Clearance Work Orders. (b) Sign-on as 1 st verifier for the Work Order task and contact the appropriate LMD Reviewer/Clearance Owner to perform the LMD review. (2) The LMD Reviewer / Clearance Owner shall: (a) Verify the isolation is adequate and sign as 2 verifier for the Work Order task. (b) If the ECO is NOT reviewed, then the addition of the Work Order can proceed using the standard process for developing an ECO (preparer, reviewer, LMD review, and authorizer). W97:JE/nw/nw/cls

5.8.1 (Contd)

3. If a new Work Order is generated during an outage, the ECO Coordinator responsible for the work order must obtain approval from the Operations Outage Shift Director PRIOR to issuing the new ECO or attaching the new Work Order to an existing ECO.

4. During outages, only the responsible ECO Coordinator can add work orders to a new or existing ECO after obtaining the Operations Outage Shift Directors approval.

5.8.2 The RO or Authorized Operator should: (refer to Attachment 7, ECO Checklist for additional guidance)

1. Review approved Master ECOs for possible use.

2. Evaluate the impact to the plant by considering Tech Specs and Risk Significance:

a. Consider the effects of turning off power.

(1) When a vital 125 Volt DC or 120 Volt AC breaker will be used as part of a boundary, verif,i Engineering reviews the impact.

b. Consider the affects of alignment changes.

c. Consider mode applicability.

d. Add appropriate limitations AND conditions as required for ECO.

[Commitment PTN Step 2.3.10]

3. Verify ECO boundaries are adequate for work to be performed using controlled documents (i.e., prints, procedures, and attachments) and, as necessary, the assistance of the requesting discipline.

4. Prepare the new ECO in the computer database as follows:

a. Placement steps shall be sequentially executed, unless approved by the US/WCCS/SRO designee and denoted on the ECO Form.

b. Include steps with no tag for procedure performance, Caution, or Information tag placement, and steps for information only.

W97:JElnwInw/cls

5.8.2.4 (Contd) No In some situations, checking all components within the ECO bounda,y may be redundant (i.e., during outages when a system alignment will be performed prior to system startup, etc.). In these cases, checking components within the ECO boundary may be waived by the Shift Manager. I

        =        =                              = =   a            = =

c. Include restoration steps to verify proper alignment of all components within the ECO boundary. This includes the removal of drain hoses, unless the hose is controlled by a TSA or Temporary Procedure.

[Commitment PTN Step 2.3.5]

d. When electrical grounds are to be installed, include steps with no tag to verify removal of those grounds prior to energizing the equipment.

e. Include restoration steps to verify the position of handwheels on control valves within the ECO boundary, when applicable.

5. Attach appropriate work orders to the new or existing ECO.

6. IF Clearance associated holds do not Auto-Release, THEN release Clearance associated holds in NAMS Asset Suite as follows:

a. Asset Suite applies TWO holds when a Clearance Request is generated.

Holds are released by the owner, in this case Operations, when the condition is satisfied.

b. The CLR is to be released by the preparer when the ECO is prepared for the work order task.

c. The CCL is to be released when the ECO reviewer verifies the clearance order applicability to the WO task

d. To release a HOLD on the respective task status on the MlOO Panel:

(1) Right Click on STATUS, and Select <MORE DETAIL>. This takes you to the Status Tracking Panel M130 (2) Select the HOLD TRACKING family tab (Ml 31 Task Status Hold Tracking Panel) (3) Select the desired HOLD (CLR, and CCL) to release associated with the Clearance Request. (4) Enter the Release Date, and Time in the blanks and the hold is released putting your SLID in the blank. AIO7.

5.8.2.6.d Contd) (5) When the CLR HOLD is released, go to the M105 Requirements Panel, and perform the following in Section 2 to enter the Clearance information: (a) Enter facility PTN. (b) Enter Permit Type CO (c) Select <APPLY>. This opens the Permit Number Grid (d) Enter the ESOMS clearance number into this Grid

7. Notify the US/WCCS/SRO designee that the new ECO or attached work order is ready for review.

a. Submit copies of controlled documents used (to be retained in the ECO package).

b. A hard copy of the unapproved ECO may be printed to aid in the review process.

5.9 ECO Review and Approval (refer to Attachment 7, ECO Checklist for additional guidance) 5.9.1 The US/WCCS/SRO designee shall independently review the ECO or attached work order to:

1. Verify that the specified ECO boundary satisfies the requirements of the activity to be performed.

2. Verify that no active Temporary System Alterations (TSAs) will affect the ECO boundary.

3. Verify that the necessary Fire Protection Impairments (FPIs) have been requested, as required.

4. Verify that Containment Integrity is maintained, as required.

5. Verify that plant conditions (current alignment, other active ECOs, surveillance testing, etc.) will support removal of equipment from service.

6. Verify compliance with Technical Specifications.

7. Determine which steps require use of CV, and annotate those steps on the ECO.

8. Verify that the sequence of steps is correct.

9. Verify that all appropriate equipment, in addition to the tagged equipment, has been specified to be checked.

10. Verify that Engineering Review has been completed, when applicable.

11. Verify that ECO lists appropriate limitations and conditions required for ECO execution. [Commitment PTN-Step 2.3.10]

W97. IP/nw/nw/cls

5.9.2 The US/WCCS/SRO designee shall determine and indicate the following on the ECO Form:

1. Tech Spec related

2. Safety related

3. Risk Significant

4. Load limiting

5. Load threatening 5.9.3 All ECOs shall be reviewed by each responsible Maintenance Discipline prior to the ECO being authorized for implementation.

1. In case of emergent OR outage work, the maintenance review may occur in parallel with OR following ECO implementation in the field 5.9.4 The US/WCCS/SRO designee shall authorize all ECOs by signing the ECO Form.

5.9.5 A second, independent review by the SMISRO shall be performed for ECOs affecting Tech Spec or Safety Related to ensure the following:

1. Adherence to Tech Spec Limiting Condition for Operations (LCOs).

2. Containment Integrity is maintained, as required.

3. No adverse impact on redundant equipment or opposite trainlunit.

4. Appropriate log entries (EOOS, Outage Risk Assessment, etc.) have been made.

5.9.6 If doubt exists as to whether execution of the ECO will result in the plant being operated in a condition that adversely affects an USFSAR described design function, the SMISRO shall refer to the questions listed on the 10 CFR 50.59 Applicability Determination/Screening to help determine if a 10 CFR 50.59 Evaluation is needed. 5.9.7 The SMJSRO shall approve all ECOs affecting Tech Spec or Safety Related equipment by signing the ECO Form.

1. The SM shall be notified when a Tech Spec or Safety Related, Risk Significant, or in-service system ECO is being sent out for execution. The notification should include scope of the ECO and equipment affected.

2. The US and RO shall be informed of the ECO execution.

Wq7. IFInw!nwkIs

5.9.8 The Operations Manager shall approve the hanging of ECO tags in the Containment during Modes 1 and 2. [Commitment PTN Step 2.3.3]

1. ECO tags in the Containment during Modes I and 2 shall be made of phenolic material.

2. Phenolic tags shall be attached using the same cable and cable crimps provided for permanent valve tags, OR stainless steel tie-wraps.

3. Phenolic tags must be filled out manually.

5.9.9 When final approval has been obtained, the ECO may be issued to the RO or Qualified Operator to be executed. W97:JE/nw/nw/cls

Procedure No. Procedure

Title:

Page: 40. Approval Date: 0-ADM-212.1 Operations In-Plant Equipment Clearance Orders 2/5/11 a a S a a The ESOMS Clearance Module component PLACEMENT and RESTORATION electronic signatures are to be used as the official verifications. Signing the computer for another operator is not allowed except for LLRT or Integrity ECOs. The use of the hard copy (paper) as component position verification and IV should only be used when the ESOMS Computer System is not available or not functioning correctly. 5.10 ECO Execution (refer to Attachment 7. ECO Checklist for additional guidance) 5.10.1 ECO alignment and tag placement shall be performed by a qualified operator who is knowledgeable of the type and magnitude of the energy, the hazards of the energy, and methods to control it. 5.10.2 The operator shall be briefed on the purpose of the ECO and the conditions that should be established within the ECO boundary for the safe performance of work. 5.10.3 The operator shall be given a copy of the ECO tag hang list form, tags, and any other materials used in the development of the ECO pertinent to the implementation of the ECO (prints, EWDs, ETC.) 5.10.4 The ECO alignment and tag placement shall be performed in a step by step manner as specified on the ECO.

1. At the discretion of the SMJSRO, large ECOs may be performed out of order (i.e., Containment Integrity, ILRT, etc.)

2. CV shall be performed for steps designated by the US/WCCS/SRO designee.

5.10.5 ECO tags shall be legible and understandable. 5.10.6 ECO tags shall be securely attached to energy isolating devices so that they can not be inadvertently or accidentally detached during use.

1. ECO tagout device attachment shall be of a non-reusable type, attachable by hand, self-locking, and non-releasable with a minimum unlocking strength of 50 pounds, AND shall have the general design and basic characteristics of being at least equivalent to a one-piece, all environment nylon cable tie.

5.10.7 The ECO execution shall be stopped and the Control Room/Work Control Center shall be notified immediately for any of the following circumstances:

1. Any step that can NOT be executed as specified.

2. The execution must be suspended.

3. A component is locked, and NO lock is referenced on the ECO.

4. A component is unlocked, and a lock is referenced on the ECO.

W97:JEJnw/nw/cls

5.10.7 (Contd)

5. A component cannot be positively identified using standard plant labeling

a. If the component is not tagged with a unique plant component tag, the following should be considered for identification:

(1) Verification of the component designations using plant drawings (2) Engineering walkdown and identification of the component (3) Independent Operations personnel agreement on the component designation

b. When these situations are identified, steps shall be taken to obtain the correct identification tags for the component.

5.10.8 The US/WCCS/SRO designee shall resolve any discrepancy and indicate by initialing on the ECO Form. 5.10.9 The first Placement block of the ECO shall be initialed on the hard copy as each step is performed and the computer records updated as soon as practical. 5.10.10 The physical result of each alignment action should be observed during the tagging operation to ensure the desired conditions are being met for safe work.

1. If undesired conditions are encountered, the tagging operation shall be stopped and the US/WCCS/NWE consulted for resolution prior to continuing.

5.10.11 Independent Verification of ECO steps shall be performed by a second qualified operator and shall be performed in accordance with 0-ADM-031, Independent Verification. Independent verification is required for systems listed in 0-ADM-03 1, Independent Verification, Enclosure 1, or as deemed necessary by the SMIUS/WCCS/SRO.

1. The second Placement block of the ECO shall be initialed on the hard copy as each IV is performed and the computer records updated as soon as practical.

2. IV steps may be performed in any order.

3. Information tags and procedure or information steps do NOT require IV.

4. CV of THROTTLED or BACKSEATED valves replaces IV. Operators performing CV of these valves shall place their initials/date/time in the 2nd Placement block of the appropriate step.

W97:JEInw/nw/cls_

5.10.11 (Contd

5. Verify ECO completion and sign for tags verified executed on the ECO Form as soon as practical.

6. Independent Verification (IV) shall be implemented for all Caution, Danger and Operating permit tags unless conditions otherwise warrant IV being waived by Shift Supervision.

Examples include:

a. ALARA

b. Task performance may have immediate consequences for safe reliable pant operation, etc.

c. Personnel safety 5.10.12 The completed ECO shall be returned to the Control Room or Work Control Center for review.

5.10.13 The US/WCCS shall:

1. Ensure that the Tech Spec related or Risk Significant equipment is placed in the EOOS Log and/or Outage Risk Assessment Notebook, as required.

2. Notify the ECO Owner that the ECO has been executed and that the Control Form may be picked up in the Work Control Center or Control Room.

3. Ensure that the ECO is filed under the appropriate system/zone number in the ECO File.

W97:JE/nw/nwIcI

Procedure No.: Procedure

Title:

Page: 43 Approval Date: O-ADM-212.1 Operations In-Plant Equipment Clearance Orders 2/5/11 5.11 ECO Release I Only original ECO Control Forms shall be used to release an ECO. These can be recognized by the colored border and unit designator; OR, if colored paper was not available, the form was stamped Original with Red ink. 5.11.1 The US/WCCS/SRO designee shall perform the following:

1. Review the ECO package AND the computer to ensure that all Holders and Owners have released the ECO.

2. Verif,i (if paper forms are used) that all original Control Forms are present and signed off.

a. If any Control Forms were NOT accepted or signed on, the responsible department shall sign on and then release, noting that no work was performed.

b. If an original Control Form was lost, a duplicate may be made. The new form shall be labeled DUPLICATE ORIGINAL LOST, and the responsible Owner shall sign on and then off after verifying all work for that discipline is complete and all holders have released the ECO.

3. When all Control Forms have been signed off and returned to Operations, the ECO may be released.

W97:.lE/nw/nwirls

5.11.2 The RU or authorized operator shall prepare the ECU Release as follows:

1. Verify all Control Forms are accounted for.

NOTES I

In some situations, checking all components within the ECO boundary may be redundant (i.e., during outages when a system alignment will be performed prior to system startup, etc). In these cases, checking components within the ECO boundary may be waived by the SM.

a For any component that will not be restored to its normal position upon release of the ECO (except components tag shared with another ECO), identify what action, method 1 or procedure will restore the component to its normal position in the Tag Removal Note for that component to ensure configuration control is maintained

2. Verify that the ECO includes restoration steps to verify the following:

a. Proper alignment of all components within the ECO boundary, using documents such as system prints, the body of the procedure, and attachments to develop the alignment. This includes the removal of drain hoses, unless the hose is controlled by a TSA or Temporary Procedure. [Commitment PTN Step 2.3.5)

b. Components worked on within an ECO boundary SHALL have positions verified through a specific restoration step during the ECU release. This verification cannot be waived by a Shift Manager.

c. Removal of any electrical grounds prior to energizing the equipment.

(1) Electrical Maintenance Supervisor or GML shall attach a completed log sheet from the Electrical Maintenance Grounds Tracking Log for the affected equipment to the ECU when releasing.

3. Using controlled documents, such as system prints, the body of the procedure and attachments, specify the component positions and releasing sequence for all ECO steps. Releasing steps shall be sequentially executed, unless approved by the US/WCCS/SRO designee and denoted on the ECO Form.

4. Sign the Release Review block on the ECO Form.

5.11.3 The US/WCCS/SRO designee shall independently verify:

1. The specified restoration positions and sequence of steps for the Release are correct.

2. In addition to the tagged components, verify that the necessary steps have been added to check all components within the ECU boundary to be properly aligned.

3. If a procedure is to be used to place the equipment in service, verify that there is a step on the Release to perform the procedure.

4. The US/WCCS/SRO designee shall determine which steps require the use of CV and annotate those steps on the ECU Form.

Wq7. IP/nw!nwIrk

5.11.3 (Contd

5. Ensure any component that will not be restored to its normal position upon release of the ECU (except components tag shared with another ECU), has a Tag Removal Note to identify what action, method, or procedure will restore the component to its normal position to maintain configuration control.

5.11.4 The US/WCCS/SRO shall determine if any tag sharing warnings were received upon release of the ECU, and verify that multiple sections that are approved for release and awaiting execution are performed in the correct order to ensure configuration control is maintained. 5.11.5 The US/WCCS/SRO designee shall authorize the removal of each tag and the repositioning of each component by signing the Release Authorized block on the ECU Form.

1. This signature denotes that all Control Forms for that ECU have been released and are accounted for.

5.12 ECU Tag Removal and Equipment Restoration

                               =          a I         =    =

I II The ESOMS Clearance Module component PLACEMENT and RESTORATION electronic signatures are to be used as the official verifications. Signing the computer for another operator is not allowed except for LLRT or Integrity ECOs. The use of the hard copy i (paper) as component position verification and IV should only be used when the ESOMS Computer System is not available or not functioning correctly. I I 5.12.1 If electrical grounds were installed, the US/WCCS/SRU designee shall contact the Electrical Department to sign for electrical ground removal verification.

1. The Electrical Department General Maintenance Leader/Supervisor shall authorize removal of the electrical grounds.

2. Electrical Department personnel shall sign the applicable step on the ECU form indicating grounds have been removed.

3. Electrical Department Supervision or GML shall independently verify that grounds have been removed and sign the applicable steps on the ECU.

5.12.2 The operator releasing the ECU shall be briefed to ensure the intent of the ECU is understood for the safe release of the ECO. 5.12.3 ECU tags shall be removed and components realigned in the sequence specified on the ECU Form.

1. If a tag from a different ECU is found on a component that conflicts with the realignment, an ECU tag is found to be missing, or an ECU tag is found on the wrong component, the operator shall immediately stop and notify the US/WCCS/SRO designee of the discrepancy.

2. The US/WCCS/SRU designee shall resolve any problems and note resolutions on the ECU Form, initialing any notes or changes.

3. The first Restoration block of the ECU shall be initialed on the hard copy as each step is performed and the computer records updated as soon as practical.

W97:JE/nw/nw/cls

Procedure No.: Procedure

Title:

Page: 46 Approval Date: O-ADM-212.1 Operations In-Plant Equipment Clearance Orders 2/5/11 5.12.3 (Contd)

4. CV shall be performed for steps designated by the US/WCCS/SRO designee.

5. After the system piping is filled and pressurized, visually check all vent and drain valves to verify that they are fully seated and NO visible leakage is observed. If leakage is noted, attempt to seat the valve. If the valve can NOT be seated, immediately notify the US/WCCS/SRO designee, and submit a PWO to repair the valve.

5.12.4 Independent Verification of releasing steps shall be performed by a second Qualified Operator in accordance with O-ADM-03 1, Independent Verification for systems listed in O-ADM-03 1, Independent Verification, Enclosure 1.

1. The IV shall include verification that the proper tag was removed by the first operator.

2. The second Restoration block on the ECO shall be initialed on the hard copy as each IV is performed and the computer records updated as soon as practical.

3. IV steps may be performed in any order.

4. CV of THROTTLED or BACKSEATED valves replace IV. Personnel performing CV of these valves shall place their initials in the second Restoration block of the appropriate step.

5.12.5 The completed ECO Release shall be returned to the Control Room or Work Control Center for review. 5.12.6 The US/WCCS/SRO designee shall:

1. Verify completion of the ECO Form.

2. Verify that FPIs issued for this ECO have been removed.

3. Update the EOOS Log and Outage Risk Assessment Notebook, as required.

4. Review 1ST and ITOP requirements prior to declaring a component Operable.

5. Ensure that the ECO is closed out.

W97:JE/nw/nwlcls

5.13 ECO Boundary Modification 5.13.1 When notified that an ECO requires a Boundary Modification, the SMJSRO designee shall determine if the Boundary Modification can be performed based upon a review of the following:

1. Current plant conditions

2. Tech Specs/EOOS entries

3. TSA log

4. Temporary procedures in effect

5. Questions listed on Attachment 3, ECO in Effect Longer Than 60 Days.

[Commitment Step 2.3.6]

6. Work in progress on current ECO section and review of additional work orders to be added after the boundary mod is completed.

5.13.2 If the Boundary Modification can be performed, the SMISRO designee shall perform the following:

1. For Work Stoppage Boundary Modification, verify that all original ECO Control Forms have been returned to Operations or all Holders have signed off the electronic form.

2. Lock the ECO section to prevent other Owners or Holders from signing on the existing ECO while the boundary mod is being executed.

3. Direct the RO or authorized operator to modify the ECO as required in accordance with the type of ECO Boundary Modification to be performed.

a. When reducing an ECO, verify by adding additional steps, that all components now outside the new boundary are in their correct position by use of prints, procedures, and attachments.

b. Add any special instructions for the Boundary Modification as informational steps on the ECO. For Boundary Modifications for Test, this should include a step on the ECO to perform the test.

c. Add steps to verify that electrical grounds have been removed, as required.

d. Verify that no other Boundary Modification is in effect on the ECO.

4. Review the Boundary Modification for accuracy and completeness.

a. The review and approval cycle shall be performed in the same manner as a new ECO; however, the second SMISRO Designee independent review is not required.

b. Sign the ECO Boundary Modification Form, authorizing performance.

W7. IPInwInwIrIc

j__. If the work stoppage boundary modification only applies to a specific discipline or activity, it should be specified by the owners on the bounda,y modification form, and work may continue on other work orders not affected by the boundary modification. I

                            =   =                    a                   a       =       I 5.13.3    For a Work Stoppage Boundary Modification, perform the following:

1. Direct a qualified operator to perform the Boundary Modification.

a. After the system is filled or pressurized, verify no leakage.

2. When the Boundary Modification is complete, notify the ECO Owners to pick up their ECO Control Form(s) and a copy of the modified ECO. Owners and Holders must signon to the Control Form for the new ECO section.

3. Verify that the computer is updated for the changes made.

5.13.4 For a Non-Work Stoppage Boundary Modification, perform the following:

1. Direct a qualified operator to perform the Boundary Modification.

a. After the system is filled or pressurized, verify NO leakage.

2. When the Boundary Modification is complete, notify the ECO Owners to pick up a copy of the modified ECO.

3. Verify that the computer is updated for the changes made.

a a a a Within 5 days of execution of an ECO Boundary Modification for the purpose of testing, the boundaries should be restored or the ECO should be released. 5.13.5 For a Boundary Modification for the purpose of testing, perform the following:

1. Direct a Qualified Operator to perform the Boundary Modification.

a. After the system is filled or pressurized, verify NO leakage.

2. Notify the test owner that the test may be performed.

3. Restore the ECO Boundary as necessary when requested by the test owner.

4. When the boundary has been restored, notify the ECO Owners to pick up their ECO Control Form(s) and a copy of the modified ECO. Owners and Holders must sign on to the new ECO section.

5. Verify that the computer is updated for the changes made.

Wq7 IP/nw/nw/rI

5.14 ECO Revision 5.14.1 ECO Revision is a modification to an existing ECO that does not alter the ECO ISOLATION boundary. US/SRO approval is required although it is not necessary to route boundary modification forms. Revisions may be used:

1. For the addition of restoration steps after execution of the ECO section.

2. For the addition or removal of tags that do not require work stoppage, affect the boundary or conflict with work orders assigned to the original ECO section.

3. To remove tags that were incorrectly issued or issued on the wrong equipment during the ECO execution and before acceptance of the ECO.

4. To add steps to include information tags or update annunciator panels.

5. To correct errors of a clerical nature, such as typographical errors in valve nomenclature or component location.

5.14.2 When performing a revision, the following method shall be used:

1. SRO approval prior to implementation of the revision.

2. The preparer shall verifv the Original ECO section is locked to prevent owners and holders from signing on during the revision process.

3. The preparer of the ECO revision shall notifi all Owners and get their concurrence prior to implementation.

4. The Owners shall notify all Holders of the Revision.

5. The ECO Owner/Coordinator for each discipline shall obtain a copy of the revised ECO. If The ECO Holder form is used, it shall be updated by the Owner of that discipline.

Wq7. IF/nw/nw/rk

5.15 Bus Outages (Bus Clearances) I This procedure section refers ONLY to Electrical Isolation Controls for 4KV Switchgear components. I a a = a a a = I 5.15.1 All 4KV sources of power to affected 4KV bus shall be isolated by the following methods or combination of methods:

1. 4KV breaker racked out on Bus Clearance (Breaker may or may not be on affected bus)

2. EDG disabled on Bus Clearance

3. Switching order to OPS personnel and referenced by a step in the Bus Clearance

4. 480V LC bkrs racked out on Bus Clearance

5. Some other acceptable means (i.e., power leads determined and tagged on Bus Clearance)

CAUTION In the event As Found meggering of the 4KV bus is necessary, the department performing the meggering is required to verify a visible air gap on all breakers on that bus, and to station a person whose sole responsibility will be to maintain that air gap. 5.15.2 If Bus Outage Tags are to be used, a Bus Outage Caution clearance shall be generated to hang the Bus Outage Tags on the individual Danger tags. The Bus Outage Tags shall be removed prior to the release of the Bus Clearance tags. 5.15.3 For ECOs which require the 4KV breaker as isolation which are approved after the bus outage commences and had not been previously tagged, a step shall be added to the Bus Outage Caution Clearance so that the Danger Tag can be hung with a Bus Outage Tag (Sleeve)

1. The Owner for the new ECO shall become an active holder of the Bus Clearance on his departments control form.

OR

2. For ECOs which are releasing the danger tag from the breaker currently on a Bus clearance, the Bus Outage Caution Clearance shall be revised to remove the Bus Outage Tag (sleeve) prior to removing the danger tag.

WQ7. IP/nw/nw/rI

Procedure No.: Procedure

Title:

Page: 51 Approval Date: O-ADM-212.1 Operations In-Plant Equipment Clearance Orders 2/5/11 5.15.4 The Bus Outage Caution Clearance will be a separate section that is approved and executed after the Bus Clearance has been executed. This clearance will issue Bus Outage Tags (sleeves) for all 41 60V breakers in the Bus Clearance that are not providing Bus isolation and currently are danger tagged. These sleeves will be hung over the danger tags and do not require independent verification.

1. If a Danger tag is removed, a Bus Outage Tag shall be used to alert maintenance personnel that electrical isolation for that breaker is provided by the Bus Clearance.

2. Upon restoration of the Bus Clearance, the individual breakers will be verified in its original position (normally Racked Out) and the Bus Outage Tags shall be removed.

a. Any Caution Tags or Bus Outage Tags hung in reference to the Bus Clearance shall be removed prior to releasing the Bus Clearance.

5.15.5 The Owner of the Bus Clearance shall be the SM and one individual from each department affected by that ECO.

1. Each department head shall designate the Owner for that department.

2. That individual must have supervisory jurisdiction over all of the affected holders.

3. All Owners of the Bus Clearance shall accept the Bus Clearance as the electrical isolation for their individual ECOs before Bus Outage Tags are hung superseding the individual ECO Tags.

4. The Owners signature on his Bus Clearance Control Form signifies his permission to hang Bus Outage Tags.

5.15.6 Each craft performing work on the 4KV bus shall have a Supervisor become a Owner on the Bus Clearance prior to commencing any work related to the bus outage.

1. This shall be done by attaching the new WO to the Bus Clearance.

5.15.7 No Boundary Modification for the purpose of testing shall be performed on the Bus Clearance unless all other affected ECOs have had their original boundaries restored.

1. The one exception is a Boundary Modification for testing of the affected sequencer under the condition that all 4KV breakers on the affected 4KV bus are racked out with test umbilicals disconnected prior to sequencer testing.

2. During the sequencer Boundary Modification for the purpose of testing, all individual Bus Clearance Control Forms are accounted for and no work is authorized on the affected 4KV bus.

W07. IP/nw/nw/rI

5.16 Review ofECOs 5.16.1 The Shift Manager or designee shall perform a monthly review of all ECOs active for greater than 30 days. ECOs written for the long-term administrative control of equipment, which is to be abandoned or will require more than 30 days to repair; are not subject to the 30-day duration limit, and do not need an evaluation eveiy 30 days per the ECO in Effect Longer than 30 Days Sheet, provided there has been a condition report generated with an action item to release the administrative ECO once the condition has been corrected. They are still subject to the audit and to the 10 CFR 50.59 Applicability Determination/Screening Review per the ECO Evaluation Sheet after 60 days in accordance with ECO in Effect Longer Than 60 Days (similar to Attachment 3).

1. An inspection of the ECO tags shall be performed. If a unit is in Mode 4, 5, or 6, the inspection should be a spot check only.

2. Damaged or missing tags shall be replaced.

3. Copies of each outstanding ECO shall be routed by transmittal to the respective Owners for their review and feedback on the clearance status.

4. Copies of all ECOs active for greater than 60 days at the time of the review shall have an Attachment 3 completed by the Operations Support Supervisor/Designee (not applicable if a 10 CFR 50.59 evaluation is attached to the clearance).

5. ECOs greater than 60 days at the time of the review shall be checked to ensure previous required reviews have been completed and are attached to the ECO. If the reviews are not attached to the ECO, the responsible department manager shall be notified to resolve the discrepancy.

6. ECOs active for greater than 90 days at the time of the review shall be routed for review by appropriate plant management with the purpose of expediting their release.

7. The SM shall document this review by initialing 0-OSP-200.1, Schedule of Plant Checks and Surveillances, when the review has been completed.

\AIQ7. IIInwInwIrIc

5.16.2 The ECO Owners shall review each ECO provided by the Shift Manager and: I

1. Request release, or

2. Document the reason the ECO can NOT be released within 30 days, and provide the estimated release date the ECO in Effect Longer than 30 Days Form.

3. Return the completed forms to the Shift Manager.

5.16.3 The ECO Owner review shall be documented by attaching the ECO in Effect Longer than 30 Days Form to the ECO. 5.16.4 ECOs requiring release or corrective action shall be reported to the Assistant Operations Manager. 5.16.5 The Operations Support Supervisor/designee shall perform a review of 10 CFR 50.59 Applicability Determination/Screening of all ECOs not released within 60 days when requested by the SM, or scheduled by 0..OSP-200.1, Schedule of Plant Checks and Surveillances.

1. The Shift Manager shall provide the Operations Support Supervisor/designee with copies of ECOs requiring review.

2. The review (if not previously performed and attached to the ECO) shall be documented on a form similar to Attachment 3, ECO in Effect Longer Than 60 Days.

3. ECOs requiring release or corrective action shall be reported to the Assistant Operations Manager.

4. Return the completed safety review to the Shift Manager.

5.16.6 The safety review shall be documented by attaching the ECO in Effect Longer Than 60 Days Form to the ECO. 5.16.7 The Operations Support Supervisor/designee shall document this review (per Attachment 3, ECO in Effect Longer Than 60 Days) by initialing 0-OSP-200.1, Schedule of Plant Checks and Surveillances, when the review has been completed. W97:JE/nw/nw/cls

5.17 ECO Computer Failure 5.17.1 When the ESOMS ECO Computer System is not available immediately, call the help desk to get NIS assistance or the ESOMS Operations Administrator. If NIS cannot restore the ESOMS ECO System in a timely manner, continue with this procedure section. 5.17.2 If an ECO is required to be issued during this failure, fill out forms similar to Attachment 1 of this procedure and Attachments 2 and 3 of 0-ADM-212, In-Plant Equipment Clearance Orders. Use the same guidance as Subsections 5.7 through 5.9 without the computer verification requirements. 5.17.3 If an active ECO is required to be released during this failure, fill out forms similar to Attachment 1 of this procedure and Attachments 2 and 3 of 0-ADM-2 12, In-Plant Equipment Clearance Orders. Use the same guidance as Subsections 5.10 and 5.11 without the computer verification requirements. CAUTION The Shift Manager shall ensure all Owners and Holders have signed the hard copies (paper) of the ECO Owner and Holder Forms similar to Attachments 2 and 3 of 0-ADM-212, In-Plant Equipment Clearance Orders, when preparing boundary modifications and/or revisions with the ESOMS System out of service. 5.17.4 If a boundary modification or revision is required during this failure, fill out forms similar to Attachment 4 of 0-ADM-212, In-Plant Equipment Clearance Orders, and follow the guidance of Subsections 5.12 and 5.13 of this procedure without the computer verification requirements. END OF TEXT W97:JE/nw/nw/cls

z.t CC

ATTACHMENT 1 (Page 2 of 4) ECO FORM ECO FORrvI ECO SECTION COVER SHEET Unit Nurrber Equipment Clearance Order Number: 2 3 J..Syntem Ntimber, Equipment Clearance Order Section: 4EqUimenustemtobaTugged: I S Reason for Equipment CIearancq Sand8 - 7 Prepared By: - - Dept OoeerAccepted Date/Time Owner Release Date/Time US Rexiewed By cl/PS SM Reviewed By tIECH Verified Executed ELECT Wcrtc Complete PROJ Equip I/S Bour,daryCkd --ENG Grounds Removed Verif RELAY Release Review By I/C HP -- - Release Autherized By Tags Veef Removed By OThER OTHER OThER 9 Safety Review: Prepared By: N None US Reviewed By No SM Reviewed By Na Verified Executed No Work Carnipi etc No Equip I/S Boundary Ckd No 10 Hazards: 11 Special Instructions: F-392/2:4 Rcv. 2(215/H - ADM-2121) W97:JEInw/nw/CIS

ATTACHMENT 1 (Page 3 of 4) ECO FORM ECO FORM TAG HANG LIST FOR ECO Page of Equipment Tag Place Place fld 2 Equipment ID I Euipment Location Notes

                   -..              Description                                   Type    Seq  Confag Number F-39213:4 Rev. 2(2/5/I I - ADM-212.l)

W97:JEInw/nw/cls

ATTACHMENT 1 (Page 4 of 4) ECO FORM ECO FORM TAG REMOVAL LIST FOR ECO Page of Equipment Equipment Tag Rest. Rest. a 1 na - Tag E q UI p ment-1P Notes

                                     -*   Description  Location       Type       Seq   Config              Serial F-392144 Rev. 2 (2/5/11 - ADM-212.1)

W97:JE/nw/nw/cls

ATTACHMENT 2 (Page 1 of 1) ECO IN EFFECT LONGER THAN 30 DAYS

1. TO: Shift Manager

2. FROM: Operations Engineering QC Electrical Mechanical I&C Other Spec

3. Date: CL. No.:

Equip: SysNo.: Unit: Released:

4. Estimated Date of Release:

5. Reason for Extension:

Need Parts Shutdown Item Equipment Removed Administrative Control Other Specfy

6. Remarks:

7. Supervisor/Leader:

Signature Date: WQ7. IP/nw/nw/cls

ATTACHMENT 3 (Page 1 of 1) ECO IN EFFECT LONGER THAN 60 DAYS

1. Requested By Shift Manager or Designee:

a. ECU No.:

b Date Approved:

c. System:

d. Affected Equip:

(Description and No.)

2. Reviewed By Operations Support Supervisor or Designee:

a. How does this ECU affect the running units?

b. How does this ECO affect the Technical Specification?

c. Reasons for being out of service:

3. 10 CFR 50.59 Applicability Determination/Screening Review:

A. Perform and attach a 10 CFR 50.59 Applicability Determination/Screening review per 0-ADM- 104. YES NO B. Is a 10 CFR 50.59 evaluation required? LI LI

4. If Item 3B above is a Yes, route this form to the Engineering Department for a 10 CFR 50.59 evaluation prior to return to the Shift Manager.

REMARKS:

5. If the answer to item 3B is No, sign form and return to Shift Manager.

Operations Support Supervisor/Designee Date:

6. Update 0-OSP-200.I, Schedule of Plant Checks and Surveillances, when this review has been completed.

NO7

Procedure No.: I Procedure

Title:

Page: 61 Approval Date: 0-ADM-212.1 Operations In-Plant Equipment Clearance Orders 2/5/11 ATTACHMENT 4 (Page 1 of 1) BREAKER/VALVE ALIGNMENT SHEET

1. If this form is being used to correct a mispositioned breaker/valve, a 50.59 screening is NOT required.

2. If this form is being used as the work control document to track component manipulations, a 50.59 screening SHALL be performed.

10 CFR 50.59 Screen Questions (See Subsection 5.3 of 0-ADM-104) START TASK:

1. Does the proposed activity require a change to the Technical Specifications? LI NO LI YES SRO review Technical Specifications Reviewed Date If YES, request and receive a License A mendment prior to implementation of the activity.

2. Does the proposed activity involve a change to an SSC that adversely affects an UFSAR described design LI NO LI YES SM Approval function? Date

3. Does the proposed activity involve a change to a procedure that adversely affects how UFSAR described LI NO LI YES SSC design functions are performed or controlled?

4. Does the proposed activity involve revising or replacing an UFSAR described evaluation methodology LI NO LI YES RESTORATION that is used in_establishing_the_design_bases or used in the_safety_analysis? COMPLETE:

SRO review

5. Does the proposed activity involve a test or experiment not described in the UFSAR, where an SSC is LI NO LI YES utilized or controlled in a manner that is outside the reference bounds of that design for the SSC or is Date inconsistent_with_analyses_or_descriptions_in_the_UFSAR?

UFSAR Chapters Reviewed If questions 2, 3, 4, or 5 are answered YES, a 10CFR5O.59 Evaluation shall be performed. Prepared by Date FS/US/SM BKR/ Normal Positioned Positioned Restored To Verified DESCRIPTION To To Normal By STEP Permission VALVE Position ( Location, System, Train, etc.) (Open/Closed) (Open/Closed) (lnitial/Date) (Initial/Date) (Initial/Date) (Initial/Date) ID W97:JEInw/nw/cls

Procedure No.: Procedure

Title:

Page: 62 Approval Date: O-ADM-212.l Operations In-Plant Equipment Clearance Orders 2/5/11 ATTACHMENT 5 (Page 1 of 1) LOCAL JOINT ADVISORY SAFETY COMMITTEE (LJASC) & NUCLEAR JOINT SAFETY COMMITTEE (NJSC) REVIEW FORM

Subject:

Date: Description of condition, including proposed resolution*

Provide drawing details and other supporting documents.

LOCAL JOINT ADVISORY SAFETY COMMITTEE (LJASC) RECOMMENDED D REJECTED D COMMENTS AfACHED I / Signature Union Committeeman Print Date I / Signature Company Committeeman Print Date LJASC may require approval of the NJSC Members NUCLEAR JOINT SAFETY COMMITTEE (NJSC) RECOMMENDED D REJECTED COMMENTS ATTACHED I / System Council Safety Chairman Print Date I / ChiefNuclear Officer Print Date I / Signature Union Committeeman PTN Print Date I / Signature Company Committeeman PTN Print Date I / Signature Union CommitteemanPSL Print Date I I Signature Company Committeeman PSL Print Date NJSC Action Item #:_________________________ AIO7. II,!.,1-k

ATTACHMENT 6 (Page 1 of 1) STARTER MA1I1 CONTACTS AND FUSE REMOVAL FORM ECO#:___________ BREAKER# STARTER MAIN CONTACTS ON ALL 3 PHASES HAVE BEEN REMOVED FUSES HAVE BEEN REMOVED: OPERATIONS: Signature Print Date EM JOURNEYMAN: Signature Print Date EM GML: Signature Print Date AFFIX THIS SHEET TO BREAKER PANEL REMOVE AFTER RESTORATION W97:JE/nw/nw/cls

ATTACHMENT 7 (Page 1 of 9) ECO CHECKLIST This ECO Checklist is a tool to aid in the preparation and approval of ECOs. It provides guidance for materials that should be included in an ECO package and is for informational purposes. ECO Preparer Checklist #1 ECO# (/ as appropriate) ECO Package Contents Y N N/A

1. LILILI Copy of the EGO (cover sheet, tag list).

2. LILILI Drawings (P& IDs, EWDs, breaker list, etc) marked up to show boundary.

3. LI LI LI Any other materials needed or used in the preparation of EGO.

The individual preparing the ECO will review the PWO(s) to identify:

1. LI LI LI Principle Equipment.

2. LI LI LI Scope of Work.

3. LI LI LI Recommended isolation points (For EGO purpose, the PWO is not a controlled document).

4. LI LI LI Notes, emails, etc. to identify communications or corrective actions taken against discrepancies found during the preparation of the EGO.

ECO Reviewer

1. LI LI LI EGO boundary provides proper isolation for described work (verify all components of EGO package checklist).

\N07. IF/nw/nw/cI

ATTACHMENT 7 (Page 2 of 9) ECO CHECKLIST The individual preparing the ECO ackae will consider the following: Y N N/A Reviewer

1. LI LI LI LI Principle Equipment identified in Reason for ECO.

2. LI LI LI LI Work assigned to the ECO, when PWO is at Status of 31 or greater &

scheduled.

3. LI LI LI LI Procedures (OP Attachment 1, Startup & Shutdown sections, BKR racking)

4. LI LI LI LI Tech Spec, ODCM, 0rADM-016 if applicable & note in special instructions

5. LI LI LI LI Isolation Boundaries (Use two controlled documents. If two are not available, must have two SROs review ECO for proper isolation).

6. LI LI LI LI Proposed vent & drain paths, if applicable.

7. LI LI LI LI Proper grounding step and a Restoration step (EM procedurally required).

Instructions to leave cubicle unlocked if receiving grounds.

8. LI LI LI LI Proper use of Danger Tags for the isolation points needed for personnel protection.

9. LI LI LI LI Proper step sequencing, i.e. Sequencing shall be such that all boundary isolations are closed prior to opening any valves to vent, drain, or which would allow process flow. Breakers before Valves, System Isolation before Vent &

Drain. Locations considered for efficiency of no backtracking.

10. LI LI LI LI Proper use of Caution, Info, MOVATS! operating permit tags and No-tag steps, Zero Voltage checks, if applicable. Position of HANG TAG should be considered with Notes.

11. LI LI LI LI IV is for Configuration Control; refer to 0-ADM-031 for applicable systems. IV all danger tags including restoration.

12. LI LI LI LI Special Instructions. Restoration steps for 4KV grounds if installed?

13. LI LI LI LI Any procedural requirements with respect to the ECO.

14. LI LI LI LI Expected plant conditions, system and alarm responses. This includes the designated unit, and the impacts associated with shared systems, and the opposite unit

15. LI LI LI LI Unit & Train matches the equipment identified in the PWO(s) attached.

16. LI LI LI LI Conflict Check, AND Conflict Check Un-issued.

17. LI LI LI LI Any needed Label corrections or changes to the Labeling or Total Equip Databases?

18. LI LI LI LI CR(s), needed to revise drawings, written?

19. LI LI LI LI Guarded Equipment Signs Required (OP-AA-1 02-1 003)?

W97:JE/nw/nw/cls

ATTACHMENT 7 (Page 3 of 9) ECO CHECKLIST 1st SRO Approval Checklist #2 ECO# (? as appropriate) Review for Authorization to Execute ECO (perform prior to signing Approved by Y N N/A SRO)

1. Principle Equipment to be worked identified & All Work Orders assigned to the ECO?

Hazards, Special Instructions/Comments sections reviewed? Chemistry verification that no 2

biocides are present prior to draining (TPCw, CCW, EDG Cooling, HVAC Chill Water) ri Isolation Boundaries Reviewed? (Use two controlled documents (not PWO). If two
j L_J L_J controlled documents are not available, two SROs must review for proper isolation).

4. Vent & Drain paths reviewed, if applicable?

5. Grounds reviewed, if applicable? Restoration steps for 4KV grounds if installed?

6. j Tagging lifted leads on Diesel powered equipment (Electrical Support)

7. Proper use of Caution, Info, MOVATS/ Operating permit tags and/or Non-tagged steps?

8. Proper use of Danger Tags for isolation points needed for personnel protection?

9. Proper steps sequenced & Placement Configuration identified?

(OPEN, CLOSED, ON, OFF, etc..) Sequencing shall be such that all boundary isolations are closed prior to opening any valves to vent, drain, or which would allow process flow.

10. Any Procedural requirements with respect to the ECO?

11 Plant conditions acceptable? This includes the designated unit, and the impacts associated with shared systems, and the opposite unit

12. Redundant train operability assessed?

13. Pre-ECO testing required? Performed?

14. j j Applicable procedure prerequisites satisfied? Including Checklist #4 Complete?

15. ECO Risk Potentials reviewed? Acceptable?

16. ECO Production (Generation Load Limiting) Risks considered? Acceptable?

17 Online Risk, Load Limiting, Load threatening?

18. j T.S., Safety Related, Admin requirements initiated? Requirements met? (EOOS)

19. An integrated review of PRAIPSA per WM-AA-1 000 needed / completed? (EOOS)

20. Fire Protection Impairment (FPI) actions/paperwork initiated? (Appendix R) (EOOS)

W97:.lP/nw/nwfrls

Procedure No.: Procedure

Title:

Page: 67 Approval Date: O-ADM-2 12.1 Operations In-Plant Equipment Clearance Orders 2/5/11 ATTACHMENT 7 (Page 4 of 9) ECO CHECKLIST st 1 SRO Approval Checklist #2 (Contd) ECO#___________ Containment Integrity actions/paperwork initiated? Inside Containment during Modes 1 and

21. El 2 requires OPS Manager and Phenolic tags.

22. El El El Verification type properly identified? (CV, IV, SC or NV)

23. El El El Mode/Condition Dependent actions initiated? Performed?

24. El El El For Boundary Mod or Revision, electronic LOCK Applied?

Engineering review completed, if required? Engineering review is required if Vital I2OVAC 25 El El El or DC breaker opening is NOT proceduralized. (0-ADM-212.1 5.1.21)

26. ElElEl Electronically sign Approved by SRO

27. ElElEl Independent Review by SM if Tech Spec LCO?

28. ElElEl Independent Review by SM if Containment Integrity?

29. ElElEl Independent Review by SM if Adverse impact on redundant equip or other Unit?

30. ElElEl EOOS Log entry? (Tech Spec, Risk Significance, Appendix R, IST/ISI, Maint. Rule)

31. ElElEl ECO paperwork printed? Tags printed?

32. ElElEl ECO Application/Tag Placement Pre-job Briefing performed?

NQ7 IIn,.,In,/rk

ATTACHMENT 7 (Page 5 of 9) ECO CHECKLIST nd 2 SRO ReviewlChallenge of ECO prior to Execution Checklist #3 ECO# (J as appropriate) Y N N/A Does the ECO package include the following:

1. LI LI LI Prints with highlighted isolation boundaries.

2. LI LI [1 Review copy of the ECO.

3. LI LI LI Procedures, as needed.

4. LI LI LI Any other materials needed or used in the preparation of ECO.

Review the PWO(s) to identify:

1. LI LI LI Principle Equipment

2. LI LI LI Scope of Work.

3. LI LI LI Recommended isolation points.

Perform a Challenge of the ECO and consider the following:

1. LI LI LI Principle Equipment properly identified.

2. LI LI LI Scope of Work assigned to the ECO & schedule.

3. LI LI LI Isolation Boundaries (OPEN/CLOSED, LOCKED CLOSED/LOCKED OPEN, OFF/ON, RACKED IN/RACKED OUT. PLACED IN OFF or ON being phased out. TAG SHARE.

(Two controlled documents used to verify proper isolation or two SROs have reviewed for proper isolation).

4. LI LI LI Proposed vent & drain paths, if applicable.

5. LI LI LI Proper grounding step and a Restoration step (EM procedurally required). Instructions to leave cubicle unlocked if receiving grounds.

6. LI LI LI Proper use of Danger Tags for the isolation points needed for personnel protection.

7. LI LI LI Proper step sequencing, i.e. Breakers before Valves, System Isolation before Vent &

Drain. Locations considered for efficiency of no backtracking. Sequencing shall be such that all boundary isolations are closed prior to opening any valves to vent, drain, or which would allow process flow.

8. LI LI LI Proper use of Caution, Info, MOVATS/operating permit tags and Non-tagged steps, Zero Voltage checks, if applicable. Position of HANG TAG should be considered with Notes.

WQ7. P/nw/nw/nc

ATTACHMENT 7 (Page 6 of 9) ECO CHECKLIST 2 SRO Review!Challenge of ECO prior to Execution Checklist #3 ECO# IV is for Configuration Control, refer to 0-ADM-031 for applicable systems. IV all danger 9 LI z LI tags including restoration.

10. L LI LI Special Instructions.

11. LI LI LI Any procedural requirements with respect to the ECO.

12. LI LI LI Expected plant conditions, system and alarm responses. This includes the designated unit, and the impacts associated with shared systems, and the opposite unit.

13. LI LI LI Unit & Train match the equipment identified in the PWO(s) attached.

14. LI LI LI Online Risk Monitor (OLRM) require updating?

15. LI LI LI EOOS Approved (SM)

Sign Reviewed by NPS block in NOMS, if not already signed by SM. (SM signs when 16 LI LI LI IV by Shift Manager is required see Checklist #2.)

17. LI LI LI ECO Hang/Modify Pre-job Brief performed?

Wq7. I/nw/nw/nIc

Procedure No.: Procedure

Title:

Page: 70 Approval Date: 0-ADM-212.1 Operations In-Plant Equipment Clearance Orders 2/5/11 ATTACHMENT 7 (Page 7 of 9) ECO CHECKLIST Clearance Walkdown Checklist #4 Clearance ID Unit SECTION 2 Clearance Walkdown Checklist YES NO N/A Are locks or seals properly identified? If NO*, list changes needed or what is

required.

Are there any adjacent hazards that would affect hanging the Clearance? If 2 . YES, last hazards or what is needed to safely hang the Clearance. Is the Energy Release Criteria identified, appropriate, and capable of being

   .      performed? If NO*, list recommendations and return for re-write.

4. Are hose/fittings needed for draining/venting? If YES*, list materials needed. El El El Are locations correct? Are they specific enough? If NO*, initiate an ECR

   .      (Engineering Change Request) or Condition Report as needed.

Are there any elevated Clearance points that require ladders or scaffolding 6 that is not or will not be available? If YES*, list what is required. Is an entry into High-Rad or Contamination Area required? If YES*, determine_RWP_required_and/or_HP_support_required. zi

8. Is the tag sequence proper? If NO*, list concerns and return for re-write. El El El Are procedures listed that are needed during Clearance? If NO*, update the

Clearance_to_reflect_any_required_procedure.

Will any off normal Tags Plus equipment be necessary to prevent

10. inadvertent operations of danger tagged components (Handwheel clam El El El shells,_etc.)?_If YES*,_list_what_would_be_necessary.

Are label requests required? If YES*, initiate label request and indicate 11

labels requested.

Consider including photographs to assist the implementation of the 12 Clearance. El El

13. Do sliding links or lifted lead points have adequate thread or clearance? El El El

14. Identify other tools/equipment necessary to perform Clearance. El El El COMMENTS (mandatory for any

response) WALK DOWN WAIVED El W97:JE/nw/nw/cls

ATTACHMENT 7 (Page 8 of 9) ECO CHECKLIST Authorization to Release ECO Checklist #5 ECO# (/ as appropriate) Y N N/A SRO ECO Release Authorization:

1. LILILI For Boundary Mod or Revision, has Holder Lock been applied in NOMs?

2. DDE Restoration positions and Sequence correct? (including Procedure if used use two controlled documents)

3. DD Consider open Procedures for Restoration positions (i.e., OP-201).

4. DDE Restoration positions changed from original? (If Yes, then REPRINT.)

5 DDE Non-tagged items worked on OR re-positioned while ECO in place, identified?

6. LE Verification type properly identified? (CV, IV, SC or NV)

DELI PMTs being coordinated with ECO removal?

8. DDE Instructions/Comments section reviewed?

9. DEE ECO Risk Potentials considered? Addressed? (Shared Tags?)

10. DEE ECO Production (Generation Load Limiting) Risks considered? Addressed?

11. DEE All Controllers have signed off with the Work Complete box checked?

12. DEE EOOS log book has been updated for Maintenance Complete as applicable. Exceptions can be approved by a SM or AOM.

13. DEE Walk down of job sites perlormed (no required, yet highly recommended)?

14. DEE Online Risk Monitor (OLRM) updated?

15. DEE Electronically sign Release Authorized by.

16. ED ECO Restoration Pre-job Briefing performed?

MO7.

ATTACHMENT 7 (Page 9 of 9) ECO CHECKLIST Authorization to Release ECO Checklist #5 (Contd) ECO# (/ as appropriate) Y N NIA ECO Closeout Activity:

1. DELl Completed ECO Release paperwork returned to WCC (or Control Room)?

2. EQOS Log updated? (Fire Protection Impairment, Barrier Breach, Tech Spec)

3. DDE 1ST, ISI & ITOP requirements reviewed?

4. DELl All Tags removed/accounted for (or noted if ECO Shared Tags)?

5 ELILI ECO forms completed?

6. ECO electronically closed-out?

FINAL PAGE Wg7:.E/nw/nwlris

Procedure No. TURKEY POINT UNIT 3 3-NOP-030 NORMAL OPERATING PROCEDURE Revision No. FPL SAFETY RELATED 9 CONTINUOUS USE

Title:

COMPONENT COOLING WATER SYSTEM Responsible Department: OPERATIONS Special Considerations: This is a Reactivity Management Procedure. This is an Upgraded Procedure. Initial use should include increased awareness because of potential technical and/or sequential changes to the procedure. After initial use of this procedure, provide comments back to the Procedure Upgrade Project. FOR INFORMATION ONLY Before use, verify revision and change documentation (if applicable) with a controlled index or document. DATE VERIFIED________ INITIAL_________ Revision Approved By Approval Date UNIT # UNIT 3 DATE DOCT PROCEDURE 0 Frank Wurster 08/18/08 DOCN 3-NOP-030 SYS STATUS COMPLETED 9 Grant Melin 09/23/11 REV 9

                                                                             # OF PGS

EVION tiO.: - OCEUE1ItLE: - PAGE: COMPONENT COOLING WATER SYSTEM 2 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 REVISION

SUMMARY

Rev. No. Description 9 AR 169180, 09123111, Roger Sab lone Enhance procedure by deleting a step in section 5.1 and adding a caution 5.9. This is in response to AR 1682178. 8 AR 1664721, 07I01I11, Brian Fitzgerald Added Section 5.22, Void Response. AR 1636357, 0411 0/11, Brian Fitzgerald Revised required position of CV-3-2906, 3B EMERG CONTMT COOLER OUTLET, on Attachment 2 to stem blocked OPEN per TSA 271821. Revised required position of CV-3-2903, 3B EM ERG CONTMT COOLER INLET, on Attachment 2 since the control switch for 3V30B, 3B EMERG CONTMT COOLER FAN MOTOR is in STOP while TSA 271821 is implemented. Revised required position of CV-3-2810, 3B EMERG CONTMT COOLER BYPASS, on Attachment 2 since the control switch for 3V30B, 3B EMERG CONTMT COOLER FAN MOTOR Is in STOP while TSA 271821 is implemented. 6 PCR 09-0757, 04129110, Christopher Boyd

1. Revised Section 4.2.1 Step 7 to improve wording and reduce operator burden. (CR 09-8035).

2. Added Limitation 2.2.2.2 which in combination with 2.2.2.3 incorporates the concerns of PCR 08-5876 for meeting TS 3.7.2.b. (CR 08-36312).

3. Section 5.9 Deleted Step 3 for checking only one RHR HX aligned to CCW, as this is ensured by performance of Steps 6 and 7.

PCR 09-1 261

4. Sections 5.15, 5.16, 5.17, 5.18, 5.19, and 5.20 Included steps prior to removing or restoring a CCW HX from/to service, to notify Control Room of resulting decrease or increase in Reactivity/Reactor Power.

PCR 09-2679 (CR 09-24287)

5. Attachment 2 Added NOTE for MOV-3-749A and MOV-3-749B stating that these valves may be OPEN if in Mode 4, 5, or 6 and associated RHR Loop is in operation. PCR 09-3743 (CR 09-33304)

6. Attachment 4 Aligns RCP CCW flow requirements with Vendor Manual and Design Bases Document. PCR 10-0488 (CR 09-33802)

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 3 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 TABLE OF CONTENTS SECTION PAGE 1.0 PURPOSE 5 2.0 PRECAUTIONS AND LIMITATIONS 5 3.0 PREREQUISITES 13 4.0 NORMAL OPERATIONS 14 4.1 Startup 14 4.1.1 CCW System Startup 14 4.2 Operation 21 4.2.1 Swapping CCW Pumps or Startup of Additional CCW Pump 21 4.3 Shutdown 25 4.3.1 Shutdown of One CCW Pump in Modes 1 through 4 25 5.0 INFREQUENT OPERATIONS 26 5.1 Alignment of CCW System for Split Header Operation 26 5.2 Restoration of CCW System from Split Header Operation 29 5.3 Aligning Unit 3 HHSI Pumps Cooling Water to the Unit 4 CCW System 31 5.4 Aligning Unit 3 HHSI Pumps Cooling Water to the Unit 3 CCW System 35 5.5 Chemical Addition to CCW System 38 5.6 Chemical Addition to CCW Surge Tank 40 5.7 Filling CCW Header 3A from CCW Header 3B via Chemical Pot Feeder 43 5.8 Filling CCW Header 3B from CCW Header 3A via Chemical Pot Feeder 47 5.9 Placing CCW in Single Pump Operation in Modes 5, 6, or Defueled 51 5.10 Restoring CCW from Single Pump Operation in Modes 5 or6 53 5.11 Feed and Bleed of the CCW System 55 5.12 Lowering CCW System Level 59 5.13 Draining CCW Head Tank Overflow Line 61 5.14 Maintenance Alignment for FIC-658B, Unit 3 HHSI Pumps CCW Return Flow Indicator 62 5.15 Removing 3A CCW HX from Service 68 5.16 Removing 3B CCW HX from Service 70 5.17 Removing 3C CCW HX from Service 72 5.18 Restoring 3A CCW HX to Service 74 5.19 Restoring 3B CCW HX to Service 77 5.20 Restoring 3C CCW HX to Service 80 5.21 Filling CCW Head/Surge Tank 83 5.22 Void Response 85 6.0 RECORDS 86

7.0 REFERENCES

AND COMMITMENTS 87

REVISION NO.: - PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 4 of 131 PROCEDURE NO.: 3-NO P-030 TURKEY POINT UNIT 3 TABLE OF CONTENTS (continued) SECTION PAGE ATTACHMENTS ATTACHMENT 1 Component Cooling Water Valve Alignment 91 ATTACHMENT 2 Component Cooling Water System Control Switch Alignment 121 ATTACHMENT 3 Component Cooling Water System Breaker Alignment 125 ATTACHMENT 4 Component Cooling Water Flow Rates 128

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 5 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 1.0 PURPOSE This procedure provides guidance for the Startup, Shutdown, Normal Operation, and Infrequent Operation of the Component Cooling Water (CCW) System. 2.0 PRECAUTIONS AND LIMITATIONS 2.1 Precautions

1. When the CCW headers are NOT cross-tied together, the standby pump starts on low pressure on B header only.

2. The Unit 3 and Unit 4 CCW systems can be cross-tied in two locations. One tie is in the supply and return to the High Head Safety Injection Pumps. The second is the PASS System Coolers. Caution must be taken when manipulating any of these valves to ensure both the supply and return valves are from the same unit.

3. Flow through ECC Outlet valves is maintained by actuator travel stop adjustment performed in 3-OSP-030.9, Component Cooling Water Flow Balance and should NOT be changed during normal operations.

The Shift Manager and System Engineer shall be notified prior to performing adjustment or maintenance on the ECC Outlet valves or actuators. Flow through ECC Outlet Bypass Lines is maintained in accordance with 3-OP-055, Emergency Containment Cooling and Filter Systems. Any adjustment of the ECC Outlet Bypass Isolation Valves to maintain flow within the criteria specified in 3-OP-055 does NOT require performance of 3-OSP-030.9.

4. Changing the position of a CCW throttle valve that will increase the flow rate to a component past the nominal operator rounds range may change the flow through other heat exchangers and may invalidate the emergency flow balance established by 3-OS P-030.9.

Prior to adjusting the flow past the nominal operator rounds range through any HX, with the exception of adjustments made using TCV 3-144, the System Engineer shall be consulted to determine if the adjustment may be made. When conditions require the isolation of COW to a component, the System Engineer should be notified, and care should be taken NOT to use the throttle valve unless it is the only valve available to isolate the component.

REViSION NO.: PROCEDURE TITLE: - PAGE: COMPONENT COOLING WATER SYSTEM 6 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 2.1 Precautions (continued)

5. Starting a second CCW Pump may cause MOV-3-626, RCP Thermal Barrier CCW Outlet to close due to high flow (130 GPM). To override High Flow closure of MOV-3-626, the control switch for MOV-3-626 should be manually held in OPEN position untU either MOV-3-749A or B is OPEN. IF a second CCW Pump is operating and MOV 749A or B is to be CLOSED, THEN the auto closure should be overridden until MOV-3-749A and B are CLOSED and the second CCW Pump is OFF.

6. Unless isolation is needed for emergency, CCW-supplied HXs shall NOT be isolated from their respective CCW return header unless the hot (process) side of the HX is isolated first.

2.2 Limitations 2.2.1 General

1. In MODE 1,2,3, and 4, the CCW System shall be OPERABLE with Three CCW Pumps and Two CCW HXs. Two CCW Pumps shall be aligned to independent 4160 Volt power supplies, and the third CCW Pump aligned to either of these 4160 Volt power supplies.

2. During normal operation the CCW System headers will be cross-tied at the Pumps and HXs.

3. To prevent CCW system damage from chlorides, the CCW pressure should always be greater than ICW pressure, and CCW HX flows should NOT be allowed to exceed maximum limits.

4. During normal operation CCW supply header temperature should NOT exceed 105°F.

5. Prior to venting or draining fluid from the CCW System, it is required that Chemistry is notified to determine if the fluid can be vented or drained to a floor drain, or if it needs to be collected in a suitable storage container.

6. Due to inoperability of the Boric Acid Evaporator System, the COW flow to the Boric Acid Evaporator System has been secured.

NCR-587-86 prohibits the use of the Boric Acid Evaporator.

7. Movement of heavy loads greater than 5 tons to OR from the SFP over the cask wash area will require Splitting CCW Headers per 0-ADM-717, Heavy Load Handling in accordance with Section 5.1 of this procedure.

RE\1ST0NN0.: PROCEDURETITLE: - - COMPONENT COOLING WATER SYSTEM 7 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 2.2.1 General (continued)

8. The following CCW System maximum flow rates are allowed for system startup:

Equipment Name Maximum Flow Rates SIS Pump Headers (each) 38 GPM Charging Pumps Oil Cooler Hx 171 GPM Seal Water Heat Exchanger 227 GPM Non-Regenerative Hx 800 GPM Spent Fuel Pit Hx 3080 GPM (see # below) RHR Pump Seal Water HXs (each) 30 GPM Containment Spray Pump Seal Water HXs (each) 19 GPM ECCs A Header 2000 GPM* I 3200 GPM** (see # below) ECCs B Header 4000 GPM* I 6400 GPM** (see # below) RCP Lower Bearing Oil Coolers 10 GPM RCP Upper and Lower Bearing Oil Coolers 163 GPM RCP Thermal Barrier Cooling Coils 30 GPM Excessive Letdown Hx 251 GPM Normal Containment Coolers (each) 945 GPM Rod Drive Coolers (each) 230 GPM PRZ Steam Sample Hx 42 GPM PRZ Liquid Sample Hx 42 GPM RCS Sample Hx 42 GPM Waste Gas Compressors (each) 90 GPM RHR HXs (each) 1 0,400 GPM (see # below) CCW HXs (each) 6840 GPM*** Maximum flow thru ECC bypass valve(s) Maximum flow thru ECC with outlet valve(s) open is 5000 GPM for 24 hours, then flow shall be reduced to the value indicated above. (JPN-PTN-SENP-95-026) Manufacturers maximum recommended flow limit for long term operation to minimize tube degradation in accordance with Westinghouse Letter, FPL-86-726 and FPL Letter JPE-PTPO-86-1637.

       #     Flow balance performed by 3-OSP-030.9, Component Cooling Water Flow Balance any flow adjustments must be authorized by the System Engineer.

REVISION NO.: PROCEOUTriLE: - PAGE: COMPONENT COOLING WATER SYSTEM 8 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 2.2.1 General (continued)

9. When aligning remotely operated valves (i.e., chain operated, reach rods, etc.), the position is required to be verified by local valve position. This requirement may be waived by the Shift Manager in cases of significant radiation exposure, which are those areas designated as high radiation areas, or areas deemed inaccessible by the Shift Manager.

10. Flow limitations for each ECC has been established as follows:

2000 GPM for continuous operations (Manufacturer limit for long term erosion limits.)
3200 GPM for 31 days (Post-LOCA Recirculation limit.)
3600 GPM for 7 days (Erosion limit which allows for initial post accident recovery operations.)

o 5000 GPM for 24 hours (Initial Safety Injection limit which allows for initial phases of accident response.)

5500 GPM for 1 hour (Initial Safety Injection limit which allows for initial equipment response in the event of an accident.)

11. When RHR is in operation for cooldown, the following applies:

A. IF the A RHR Loop is required to be OPERABLE, THEN the 3A or 30 CCW Pump powered from 4160 Volt Bus 3A is required to be OPERABLE to support the A RHR Loop. B. IF the B RHR Loop is required to be OPERABLE, THEN the 3B or 3C CCW Pump powered from 4160 Volt Bus 3B is required to be OPERABLE to support the B RHR Loop. C. With CCW flow isolated from an RHR HX, the RHR flow to that HX should also be isolated.

0. With normal COW service loads, one COW Pump, and two COW HXs in service, only one RHR HX should be in service.

E. During unit cooldown with RHR System in operation, CCW supply header temperature should NOT exceed 120°F.

REVISION NO.: PROCEDURE TITLE: - -

                                                                                 -     PAG:

COMPONENT COOLING WATER SYSTEM 9 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 2.2.1 General (continued)

11. (continued)

F. One of the following COW System configurations is required to valve in both RHR HXs: (1) All CCW HXs are OPERABLE AND in service. (2) IF only two COW HXs are OPERABLE, THEN both non-operating COW Pumps are in PULL-TO-LOCK, AND Technical Specification 3.7.2 entered. (3) When Unit is in MODE 5 or MODE 6, lOW flow may be isolated to one COW HX, provided that COW flow is maintained to all three COW HXs. G. IF COW is required to be isolated to a RHR HX while RHR is in service, AND ROS temperature greater than 180°F, THEN the RHR side of the HX shall be isolated first. H. IF throttling of the COW side of the RHR HX is required to limit a cooldown due to problems with FCV-3-605 or HCV-3-758, THEN the following requirements apply: (1) Only MOV-3-749A or MOV-3-749B shall be used to prevent invalidating the COW System flow balance. (2) A minimum of 1000 GPM COW flow as indicated on ultra sonic instrumentation shall be maintained for the HX with reduced COW flow. (3) COW surge tank level shall be monitored to prevent overfilling due to expansion of water in RHR HX. (4) System Engineer is aware of need to change the COW valve positions.

12. If available, both Radiation Monitors R-17A AND R-17B should be in service during COW System operation; however, R-17A AND R-17B are NOT required for COW to perform its safety related function.

When COW Headers are cross-tied, either R-17A OR R-17B can monitor both headers. When COW Headers are split, both R-17A AND R-17B is required to be in service to monitor both loops.

REVISION NO.: PROCEDURE TiTLE: - - PAGE: COMPONENT COOLING WATER SYSTEM 10 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 2.2.2 CCW Pumps

1. The minimum flow for any COW Pump during continuous operation should be greater than 3235 GPM. To meet this requirement, no more than two CCW Pumps should be operated other than during pump swapping.

2. When in MODES 1, 2, 3, and 4, two CCW Pumps from independent power supplies must be operabIe and if NOT, then restored to operable with 72 hours.

3. If COW Pump A or B is inoperable for any reason other than the performance of 3-OSP-030.1, Component Cooling Water Pump Inservice Test or 3-OSP-030.5, Component Cooling Water Pumps Low Header Pressure Start Test, its breaker is required to be OPEN and racked out and 3D 4KV bus shall be aligned to the bus that powers the inoperable pump so that 30 COW Pump will start on sequencer.

4. When NOT aligned to the sequencer, the 30 COW Pump should NOT be operated. (Except for pump swapping)

5. To prevent exceeding the maximum flowrates on the COW HXs, the number of operating COW Pumps should be one less than the number of in-service CCW HXs.

REVIS1OISf NO.: - PROCEDURE]1TLE - PAGE: COMPONENT COOLING WATER SYSTEM 11 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 2.2.3 CCW HXs

1. Three COW HXs should normally be maintained in service, since periodic testing of certain equipment, i.e., RHR Pumps or ECCs, may require operating two CCW Pumps due to additional loads placed on the system.

2. MODE changes are permissible while any one COW HX is out of service. Two COW HXs shall be verified to be OPERABLE.

3. Flow limitations for each COW HX have been established as follows:

4063 GPM for continuous operations (TEMA limit.)
6840 GPM for normal plant evolutions, such as, testing, surveillances, Hx cleaning, etc. (Manufacturer limit without vibration concerns.)

7200 GPM for 31 days (Erosion and vibration limit which allows for post accident recirculation.) 7500 GPM for initial Safety Injection (Erosion and vibration limit.)

REVISION NO.: PROCEDURE TITLE: - PAGE COMPONENT COOLING WATER SYSTEM 12 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 2.2.3 CCW HXs (continued)

4. To prevent exceeding the maximum CCW HX flowrates, the following limitations apply:

A. When in MODES 1 through 6, the number of operating COW Pumps should be one less than the number of in-service CCW HXs. B. When the reactor is Defueled, AND the following conditions are met, then the number of operating CCW Pumps may equal the number of operating CCW HXs, and ICW flow to the out of service CCW HXs isolated:

CCW flow is maintained between 3235 GPM for minimum pump flow requirements and 6840 GPM for maximum HX flow limits.

o To prevent an automatic start of a second CCW Pump, either place the control switches for the non-operating CCW Pumps in Pull-to-Lock OR rack-out the associated pump breakers.

In order to minimize long term tube-side erosion of the CCW HXs, the ICW flow rate to each COW HX should NOT exceed 10,000 GPM during normal operation.

The lOW flow rate may be increased to 12,850 GPM for each COW heat exchanger for a 72-hour period to accommodate heat exchanger or basket strainer cleanings.

5. To prevent exceeding the maximum COW HX flowrates, ONLY five of the following six loads should be attached to the CCW Header at one time: [UFSAR]

COW to/from NCC/CRDM Coolers (counts as one load.)
CCW to/from ECCs (counts as one load for each cooler.)
CCW to/from RHR HXs (counts as one load for each Hx.)

When only two CCW HXs are available and both RHR HXs are aligned to CCW, two CCW Pumps will be placed in PULL-TO-LOCK to ensure the above load restrictions are met.

6. Any reference to MAX TOTAL CCW Header flow assumes only two CCW HXs in service for accident analysis reasons.

REVIS[ON NO.: - PROCEDURE TITLE: - PAGE: COMPONENT COOLING WATER SYSTEM 13 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 2.2.4 CCW Head Tank and Surge Tank COW Head Tank level shall be greater than 10% at all times when in Mode I through 3. IF in Mode I through 3, AND CCW Head Tank level is NOT greater than 10%, THEN CCW Head Tank level should be restored to greater than 10% within 24 hours unless an extension request is submitted and approved by PNSC.

2. Operation with the CCW System level in the CCW Surge Tank will reduce the margin to the setpoint for COW Pump auto-start.

3. The following precautions apply to COW Head Tank overflow:

COW Head Tank level will rise much faster than COW Surge Tank level for a given fill rate. Extreme caution shall be exercised during filling evolutions.
Overflow of the COW Head Tank should be avoided due to potential depletion of waste processing system resins.

o A margin of approximately 40 gallons exists between the COW Head Tank high level alarm (85%) and overflow conditions.

When evolutions are to be performed that may result in COW Head Tank overflow, prior isolation of the overflow line should be considered.
A CCW Head Tank high level alarm (85%) will result in automatic closure of ROV-3-609, OOMP OLG HEAD VENT.

IF it is determined that the COW Head Tank has overflowed, THEN the control switch for ROV-3-609 is required to be maintained in the CLOSED position unt the OCW Head Tank level is restored to on-scale and the overflow line has been drained.

Operation with the COW Head Tank solid or near solid with RCV-3-609, OOMP CLG HEAD VENT, closed increases the potential for discharge of molybdated water to the WHT via lifting of RV-3-707.

4. An increase in COW Head Tank level may be caused by voiding.

3.0 PREREQUISITES N one

REVTSION NO: - PROCEDURE TITLE: -

                                                                         -         PAGE:

COMPONENT COOLING WATER SYSTEM 14 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 4.0 NORMAL OPERATIONS 4.1 Startup 4.11 CCW System Startup CHECK the foflowing: A. The following systems are available to support the COW System:

Instrument Air System
Intake Cooling Water System
Radiation Monitoring System Monitors R17A and RI7B o Demineralized Water System o Primary Water System B. The following have been completed:
Attachment 1, Component Cooling Water Valve Alignment
Attachment 2, Component Cooling Water System Control Switch Alignment
Attachment 3, Component Cooling Water System Breaker Alignment C. The following plant electrical systems are in service to support CCW System operation:
IF starting CCW PUMP A, THEN 4160 Volt Bus 3A
IF starting CCW PUMP B, THEN 4160 Volt Bus 3B
IF starting CCW PUMP C, THEN 4160 Volt Bus 3D o 48OVMCC3B o 48OVMCC3C
480V MCC 3D

REVISION NO.: PROCEDURE TITLE: - - PAGE: COMPONENT COOLING WATER SYSTEM 15 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 4.1.1 CCW System Startup (continued)

1. (continued)

D. The Alternate Shutdown Panel alignment has been verified by satisfactory completion of 3-NOP-300, Alternate Shutdown Panel, for the following equipment:

MOV-3-1418, CCW From Normal Containment Cooler
3B COW Pump
MOV-3-716B, RCP CCW Inlet
MOV-3-626, RCP Thermal Barrier CCW Outlet CAUTION To prevent exceeding maximum CCW HX flowrates, ONLY five of the following six loads should be attached to the CCW Header at one time:
COW to/from NCC/CRDM Coolers (counts as one load.)
CCW to/from ECCs (counts as one load for each cooler.)
CCW to/from RHR HXs (counts as one load for each Hx.)

IF only two CCW HXs are in-service AND both RHR HXs are aligned to COW, THEN two CCW Pumps are required to be placed in PULL-TO-LOCK to ensure the above load restrictions are met.

2. STARToneCCWPUMP:

A. IF starting 3A COW PUMP, THEN: (1) ENSURE the following are greater than 1/3 full:

Pump Inboard Bearing Oiler level
Pump Outboard Bearing Oiler level

REV1SIOr(NO.: PROCEDURETITLE: PAGE: - COMPONENT COOLING WATER SYSTEM 16 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 4.tl CCW System Startup (continued) INITIAL

2. A. (continued)

(2) ENSURE the following are OPEN:

3-1482, CCW PUMP A INBD MECH SEAL COOLANT SUPPLY ISOLVLV
3-1483, CCW PUMP A OTBD MECH SEAL COOLANT SUPPLY ISOL VLV
3-701A, COW PUMP A INLET (3) CHECK suction pressure indicated on P1-3-I 095A.

(4) CLOSE 3-703A, CCW PUMP A DISCHARGE. (5) THROTTLE 3-703A, COW PUMP A DISCHARGE to approximately 15 turns OPEN. NOTE Motor starting limits are as follows:

With motor at ambient temperature, two successive starts are allowed (the motor must coast to rest between starts).
With motor at operating temperature, one start is allowed. Subsequent starts require that the motor is allowed to cool by standing idle for one hour or running for one half hour.

(6) START 3A COW PUMP from VPB. (7) Slowly OPEN 3-703A, COW PUMP A DISCHARGE. IV

REVTSTON NO.: PROCEDURE TITLE: PAGE: - COMPONENT COOLING WATER SYSTEM 17 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 4.1.1 CCW System Startup (continued) INITIAL

2. (continued)

B. IF starting 3B COW PUMP, THEN: (1) ENSURE the following are greater than 1/3 full:

Pump Inboard Bearing Oiler level
Pump Outboard Bearing Oiler level (2) ENSURE the following CLOSED:
3-1484, CCW PUMP B INBD MECH SEAL COOLANT SUPPLY ISOL VLV
3-1485, CCW PUMP B OTBD MECH SEAL COOLANT SUPPLY ISOL VLV (3) ENSURE 3-701 B, CCW PUMP B INLET, OPEN.

(4) CHECK suction pressure indicated on P1-3-I 095B. (5) CLOSE 3-703B, COW PUMP B DISCHARGE. (6) THROTTLE 3-703B, CCW PUMP B DISCHARGE to approximately 15 turns OPEN. NOTE Motor starting limits are as follows:

With motor at ambient temperature, two successive starts are allowed (the motor must coast to rest between starts).
With motor at operating temperature, one start is allowed. Subsequent starts require that the motor is allowed to cool by standing idle for one hour or running for one half hour.

(7) START 3B COW PUMP from VPB. (8) Slowly OPEN 3-703B, CCW PUMP B DISCHARGE. IV

R!V1SIQN NO.: PROCEDURET1TLE: - - PAGE: COMPONENT COOLING WATER SYSTEM 18 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 4.1.1 CCW System Startup (continued) INITIAL

2. (continued)

CAUTION IF NOT aligned to sequencer, THEN 3C CCW Pump should NOT be operated. C. IF starting 3C CCW PUMP, THEN: (1) ENSURE the following are greater than 1/3 full:

Pump Inboard Bearing Oiler level Pump Outboard Bearing Oiler level (2) ENSURE the following are OPEN:
3-1486, COW PUMP C INBD MECH SEAL COOLANT SUPPLY ISOL VLV
3-1487, CCW PUMP C OTBD MECH SEAL COOLANT SUPPLY ISOL VLV
3-701 C, CCW PUMP C INLET (3) CHECK suction pressure indicated on P1-3-I 095C.

(4) CLOSE 3-703C, CCW PUMP C DISCHARGE. (5) THROTTLE 3-703C, CCW PUMP C DISCHARGE to approximately 15 turns OPEN. NOTE

With motor at ambient temperature, two successive starts are allowed (the motor must coast to rest between starts).
With motor at operating temperature, one start is allowed. Subsequent starts require that the motor is allowed to cool by standing idle for one hour or running for one half hour.

(6) START 3C CCW PUMP from VPB. (7) Slowly OPEN 3-703C, CCW PUMP C DISCHARGE. IV

RViS1ON NO: PROCEDURE TITLE: - - PAGE: COMPONENT COOLING WATER SYSTEM 19 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 4.1.1 CCW System Startup (continued) INITIAL

3. ADJUST CCW System flow rates equal to or just above the Minimum Normal Operating Flow Rates specified in Attachment 4, Component Cooling Water Flow Rates.

4. NOTIFY System Engineer to perform 3-OSP-030.9, Component Cooling Water Flow Balance.

5. IF only one RHR HX is aligned to CCW, THEN PLACE remaining CCW Pumps in Standby at VPB:

IF NOT started, THEN PLACE 3A CCW PUMP in AUTO.

IV

IF NOT started, THEN PLACE 3B CCW PUMP in AUTO.

IV o IF NOT started, THEN PLACE 3C CCW PUMP in AUTO. IV

6. IF only two CCW HXs are in-service, AND both RHR HXs are aligned to CCW, THEN PERFORM the following to prevent exceeding maximum CCW HX flowrates:

A. REFER TO Technical Specification 3.7.2. B. PLACE remaining CCW Pumps in PULL-TO-LOCK at VPB:

IF NOT started, THEN PLACE 3A CCW PUMP in PU LL-TO-LOCK.

IV o IF NOT started, THEN PLACE 3B CCW PUMP in PU LL-TO-LOCK. IV

IF NOT started, THEN PLACE 3C CCW PUMP in PU LL-TO-LOCK.

IV

REVISION 140.: PROCEDURETITLE: - PAGE: COMPONENT COOLING WATER SYSTEM 20 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 4.1.1 CCW System Startup (continued)

7. NOTIFY Chemistry to check that CCW System is within the required chemistry limits.

8. IF directed by Chemistry, THEN PERFORM Feed and Bleed of COW System per Section 5.11.

RE\i1SIOf NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 21 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 4.2 Operation INITIAL 4.2.1 Swapping CCW Pumps or Startup of Additional CCW Pump CAUTION o To prevent exceeding CCW HX maximum flowrates, the number of operating CCW Pumps should be one less than the number of in-service CCW HXs.

The minimum flow for any CCW Pump during continuous operation should be greater than 3235 GPM. To meet this requirement, no more than two CCW Pumps should be operated, other than during CCW Pump swaps.

IF swapping CCW PUMPS, THEN ENSURE all available CCW HXs are in-service.

2. IF starling 3A CCW PUMP, THEN:

A. ENSURE the following at 3A CCW PUMP:

Pump Inboard Bearing Oiler level greater than 1/3 full
Pump Outboard Bearing Oiler level greater than 1/3 full B. ENSURE the following are OPEN:
3-1482, CCW PUMP A INBD MECH SEAL COOLANT SUPPLY ISOLVLV
3-1483, CCW PUMP A OTBD MECH SEAL COOLANT SUPPLY ISOL VLV
3-701A, CCW PUMP A INLET
3-703A, CCW PUMP A DISCHARGE.

C. REQUEST that Chemistry determine if the fluid can be vented to a floor drain, or if it needs to be collected in a suitable storage container. D. IF 3A CCW PUMP is NOT in Standby, THEN VENT 3A CCW PUMP casing from 3-703F, CCW PUMP A CASING VENT. E. ENSURE 3-703F, CCW PUMP A CASING VENT is CLOSED. IV

RViSOi\i NO.: PROCEDURE TITLE: PAGE: - COMPONENT COOLING WATER SYSTEM 22 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 4.2.1 Swapping CCW Pumps or Startup of Additional CCW Pump INITIAL (continued)

3. IF starting 3B CCW PUMP, THEN:

A. ENSURE the following at 3B COW PUMP:

Pump Inboard Bearing Oiler level greater than 1/3 full Pump Outboard Bearing Oiler level greater than 1/3 full B. ENSURE the following CLOSED:
3-1484, CCW PUMP B INBD MECH SEAL COOLANT SUPPLY ISOL VLV
3-1485, CCW PUMP B OTBD MECH SEAL COOLANT SUPPLY ISOL VLV C. ENSURE the following OPEN:
3-701 B, CCW PUMP B INLET
3-703B, CCW PUMP B DISCHARGE

0. REQUEST that Chemistry determine if the fluid can be vented to a floor drain, or if it needs to be collected in a suitable storage container.

E. IF 3B CCW PUMP is NOT in Standby, THEN VENT 3B CCW PUMP casing from 3-703G, COW PUMP B CASING VENT. F. ENSURE 3-703G, CCW PUMP B CASING VENT is CLOSED. IV

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 23 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 4.2.1 Swapping CCW Pumps or Startup of Additional CCW Pump INITIAL (continued) CAUTION When NOT aligned to the sequencer, the 3C CCW Pump should NOT be operated. (Except for pump swaps)

4. IF starting 30 CCW PUMP, THEN:

A. ENSURE the following at 3C COW PUMP:

Pump Inboard Bearing Oiler level greater than 1/3 full
Pump Outboard Bearing Oiler level greater than 1/3 full B. ENSURE the following OPEN:
3-1486, CCW PUMP C INBD MECH SEAL COOLANT SUPPLY ISOL VLV
3-1487, COW PUMP C OTBD MECH SEAL COOLANT SUPPLY ISOL VLV
3-7010, CCW PUMP C INLET o 3-7030, COW PUMP C DISCHARGE C. REQUEST that Chemistry determine if the fluid can be vented to a floor drain, or if it needs to be collected in a suitable storage container.

0. IF 30 COW PUMP is NOT in Standby, THEN VENT 30 COW PUMP casing from 3-703H, COW PUMP C CASING VENT.

E. ENSURE 3-703H, COW PUMP C CASING VENT is CLOSED. IV

EViSiO1 NO.: OOI3URE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 24 of 131 PROCEDURE NO.: 3-NO P-030 TURKEY POINT UNIT 3 4.2.1 Swapping CCW Pumps or Startup of Additional CCW Pump (continued) NOTE Motorstarting limits are as follows:

             . With motor at ambient temperature, two successive starts are allowed (the motor must coast to rest between starts).
             . With motor at operating temperature, one start is allowed. Subsequent starts require that the motor is allowed to cool by standing idle for one hour or running for one half hour.

CAUTION Starting a second CCW Pump may cause MOV-3-626, RCP THERMAL BARRIER CCW OUTLET to close, due to high flow (130 GPM). To override High Flow closure of MOV-3-626, control switch for MOV-3-626 should be manually held in OPEN position unW either MOV-3-749A or B is OPEN. Starting a second CCW Pump may cause RV-715 to lift. IF swapping COW Pumps AND only two COW HXs are in-service, THEN the offgoing COW PUMP should be shutdown without delay.

5. START oncoming COW PUMP from VPB.

6. IF swapping COW Pumps, THEN STOP offgoing COW PUMP from VPB.

7. IF starting an additional COW PUMP, THEN ENSURE the total COW Hx flow rates is within the Maximum Normal Operating Flow Rate, as specified in Attachment 4, Component Cooling Water Flow Rates.

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 25 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 4.3 Shutdown 4.3.1 Shutdown of One CCW Pump in Modes I through 4

1. STOP offgoing COW PUMP from VPB.

2. ENSURE COW System flow rates are within the Minimum and Maximum Normal Operating Flow Rates specified in Attachment 4, Component Cooling Water Flow Rates.

REVISkDN No:: PROCEU TitL: PAGE: COMPONENT COOLING WATER SYSTEM 26 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.0 INFREQUENT OPERATIONS 5.1 Alignment of CCW System for Split Header Operation CAUTION

This procedure section only splits CCW Headers between COW PUMP A and CCW PUMP B.

o WHEN CCW Headers are split:

3A ECO and 3A RHR HX are considered inoperable.

o IF any ECC or COW Pump becomes inoperable for reasons other than splitting of the COW headers, THEN two ECCs shall be considered inoperable. o The standby COW Pump will start only upon low pressure on COW Header B. o Prior to performing this section, review 0-ADM-051, Outage Risk Assessment, for the duration of single COW pump operation to evaluate impact to outage risk. CHECK the following: o All COW Pumps are OPERABLE.

All EOCs are OPERABLE.
3A EDG is OPERABLE.
3B EDG is OPERABLE.
4A EDG is OPERABLE.
4B EDG is OPERABLE.

o COW PUMP A is operating. o COW PUMP B is operating. o Three COW HXs are in-service.

ROS temperature is greater than 350°F OR less than 180°F.
Both Radiation Monitors R-17A AND R-17B are in service.

2. ENSURE MOV-3-749A, RHR HX 3A COW OUTLET is CLOSED.

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 27 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.1 Alignment of CCW System for Split Header Operation (continued) INITIAL

3. OPEN Breaker 30721 for RHR HX COOLING WATER ISOL M OV-3-749A.

4. INITIATE an ECO to tag Breaker 30721 in OFF.

5. PLACE RCV-3-609, COMPONENT COOLING HEAD TANK VENT to CLOSE at VPB.

6. IF during the performance of the following steps, LI-3-614A, LEVEL IND FOR CCW HEAD TANK on VPB indicates 100%, THEN MAINTAIN RCV-3-609, COMPONENT COOLING HEAD TANK VENT in CLOSE until directed otherwise at the end of this section.

7. OPEN 3-835F, CCW HDR A SUPPLY TO CHARGING PUMPS, SPENT FUEL PIT HX, NON-REGEN HX, AND SEAL WATER HX.

IV

8. CLOSE 3-835E, CCW HDR B SUPPLY TO CHARGING PUMPS, SPENT FUEL PIT HX, NON-REGEN HX, AND SEAL WATER HX.

IV

9. OPEN 3-835G, CCW HDR A RETURN FROM CHARGING PUMPS, SPENT FUEL PIT HX, NON-REGEN HX, AND SEAL WATER HX.

IV

10. CLOSE 3-835H, CCW HDR B RETURN FROM CHARGING PUMPS, SPENT FUEL PIT HX, NON-REGEN HX, AND SEAL WATER HX.

IV

11. CLOSE the following:

A. 3-787 F, CCW HX OUTLET HDR SECTIONALIZING IV B. 3-787E, CCW HX OUTLET HDR SECTIONALIZING IV

EVISfON LTO.: OdEUtITL: PAGE: COMPONENT COOLING WATER SYSTEM 28 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.1 Alignment of CCW System for Split Header Operation (continued) INITIAL

11. (continued)

C. 3-7870, COW PUMP DISCHARGE SECTIONALIZING IV

0. 3-787A, CCW PUMP SUCTION HDR SECTIONALIZING IV

12. ENSURE CCW System flow rates are within Minimum and Maximum Normal Operating Flow Rates specified in Attachment 4, Component Cooling Water Flow Rates.

13. IF LI-3-614A, LEVEL IND FOR COW HEAD TANK on VPB is above 85% THEN PERFORM Section 5.12.

14. IF LI-3-614A, LEVEL IND FOR COW HEAD TANK on VPB is stable below 85%, AND COW Head Tank Overflow Line is drained, THEN PLACE RCV-3-609, COMPONENT COOLING HEAD TANK VENT in AUTO.

IV

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 29 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.2 Restoration of CCW System from Split Header Operation INITIAL IF during the performance of the following steps, Ll-3-614A, LEVEL IND FOR CCW HEAD TANK on VPB indicates 100%, THEN MAINTAIN RCV-3-609, COMPONENT COOLING HEAD TANK VENT in CLOSE untH directed otherwise at the end of this section.

2. PLACE RCV-3-609, COMPONENT COOLING HEAD TANK VENT to CLOSE.

3. OPEN the following:

A. 3-787A, CCW PUMP SUCTION HDR SECTIONALIZING IV B. 3-787C, CCW PUMP DISCHARGE SECTIONALIZING IV C. 3-787E, CCW HX OUTLET HDR SECTIONALIZING IV

0. 3-787 F, CCW HX OUTLET HDR SECTIONALIZING IV E. 3-835H, CCW HDR B RETURN TO CHARGING PUMPS, SPENT FUEL PIT HX, NON-REGEN HX, AND SEAL WATER HX IV

4. CLOSE 3-835G, CCW HDR A RETURN FROM CHARGING PUMPS, SPENT FUEL PIT HX, NON-REGEN HX, AND SEAL WATER HX.

IV

5. OPEN 3-835E, CCW HDR B SUPPLY FROM CHARGING PUMPS, SPENT FUEL PIT HX, NON-REGEN HX, AND SEAL WATER HX.

IV

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 30 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.2 Restoration of CCW System from Split Header Operation (continued) INITIAL

6. CLOSE 3-835F, CCW HDR A SUPPLY TO CHARGING PUMPS, SPENT FUEL PIT HX, NON-REGEN HX, AND SEAL WATER HX.

IV

7. IF operation of two CCW Pumps is NOT required, THEN SHUTDOWN gj CCW Pump per Section 4.3.1 or Section 5.9.

8. RELEASE related ECO to Breaker 30721 for RHR HX COOLING WATER ISOL MOV-3-749A.

9. PLACE Breaker 30721 for RHR HX COOLING WATER ISOL MOV-3-749A in ON.

10. IF RHR cooling is required AND two RHR HXs are required for operation, THEN RESTORE the RHR HX operation per 3-OP-050, Residual Heat Removal System.

11. EXIT any Technical Specification Action Statements entered due to CCW Split Header Operation.

12. ENSURE CCW System flow rates are within Minimum and Maximum Normal Operating Flow Rates specified in Attachment 4, Component Cooling Water Flow Rates.

13. IF LI-3-614A, LEVEL IND FOR CCW HEAD TANK on VPB is above 85%, THEN PERFORM Section 5.12.

14. IF LI-3-614A, LEVEL IND FOR CCW HEAD TANK on VPB is stable below 85%, AND CCW Head Tank Overflow Line is drained, THEN PLACE RCV-3-609, COMPONENT COOLING HEAD TANK VENT in AUTO.

IV

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 31 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.3 Aligning Unit 3 HHSI Pumns Cooling Water to the Unit 4 CCW System INITIAL NOTE The following steps should be performed without delay to minimize time of entry into Technical Specification Action Statements. CAUTION CCW to Unit 3 HHSI Pumps should normally be supplied from Unit 3, except when: a Unit3isinMODE5or6,AND Unit 4 is in MODE 1, 2, 3, or 4. o FIC-658B, FLOW IND CTRL FOR CCW RETURN FM SI PPS is isolated for maintenance.

General Operating Procedure or Shift Manager directs otherwise.

1. PLACE the following in PULL-TO-LOCK:

a 3A SAFETY INJECTION PUMP IV o 3B SAFETY INJECTION PUMP IV

2. ENSURE 3-708F, UNIT 3 CCW HDR B RETURN FROM SI PUMPS is LOCKED CLOSED.

IV

3. ENSURE 3-793, UNIT 3 CCW HDR B SUPPLY TO SI PUMPS is LOCKED CLOSED.

IV

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 32 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.3 Aligning Unit 3 HHSI Pumps Cooling Water to the Unit 4 CCW System INITIAL (continued)

4. IF realigning CCW to HHSI Pumps during, or in preparation for, a refueling outage, AND cycling of the following valves is required for 3-OSP-030.7, THEN:

A. OPEN then CLOSE 4-708F, UNIT 4 CCW HDR B RETURN FROM SI PUMPS. IV B. CLOSE then OPEN 838B, COW HDR B SUPPLY TO SI PUMP 3A. IV C. UNLOCK and OPEN 838D, CCW HDR A SUPPLY TO SI PUMP 3A. D. CLOSE and LOCK 838D, COW HDR A SUPPLY TO SI PUMP 3A. IV E. CLOSE then OPEN 838F, COW HDR B SUPPLY TO SI PUMP 3B. IV F. UNLOCK and OPEN 838H, COW HDR A SUPPLY TO SI PUMP 3B. G. CLOSE and LOCK 838H, CCW HDR A SUPPLY TO SI PUMP 3B. IV H. CLOSE then OPEN 838A, COW HDR B RETURN FROM SI PUMP 3A. IV I. UNLOCK and OPEN 838C, COW HDR A RETURN FROM SI PUMP 3A.

REVISION NO.: PROCEDURE TITLE: PAGE; COMPONENT COOLING WATER SYSTEM 33 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.3 Aligning Unit 3 HHSI Pumps Cooling Water to the Unit 4 CCW System INITIAL (continued)

4. (continued)

J. CLOSE and LOCK 8380, COW HDR A RETURN FROM SI PUMP 3A. lv K. CLOSE then OPEN 838E, COW HDR B RETURN FROM SI PUMP 3B. Iv L. UNLOCK and OPEN 838G, COW HDR A RETURN FROM SI PUMP 3B. M. CLOSE and LOCK 838G, COW HDR A RETURN FROM SI PUMP 3B. Iv

5. UNLOCK and OPEN 4-793, UNIT 4 COW HDR B SUPPLY TO SI PUMPS.

6. LOCK OPEN 4-793, UNIT 4 COW HDR B SUPPLY TO SI PUMPS.

IV Concurrent Verification

7. UNLOCK and THROTTLE 4-708F, UNIT 4 COW HDR B RETURN FROM SI PUMPS to maintain 20 to 30 GPM on FIC-658B.

Cv

8. LOCK 4-708F, UNIT 4 COW HDR B RETURN FROM SI PUMPS.

Iv

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 34 Of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 53 Aligning Unit 3 HHSI Pumps Cooling Water to the Unit 4 CCW System INITIAL (continued)

9. PLACE the following in Standby (mid position) at Unit 3 VPB:

3A SAFETY INJECTION PUMP IV o 3B SAFETY INJECTION PUMP IV

10. At Unit 3 VPB, ATTACH Information Tags indicating current CCW alignment on the following Control Switches:

3A SAFETY INJECTION PUMP o 3B SAFETY INJECTION PUMP

11. At Unit 4 VPB, ATTACH Information Tags indicating current CCW alignment on the following Control Switches:

3A SAFETY INJECTION PUMP
3B SAFETY INJECTION PUMP

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 35 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.4 Aligning Unit 3 HHSI Pumps Cooling Water to the Unit 3 CCW System INITIAL NOTE The following steps should be performed expeditiously to minimize time of entry into Technical Specification Action Statements. CAUTION Component Cooling Water to Unit 3 HHSI Pumps should normally be supplied from Unit 3, except when:

Unit3isin MODE5or6,AND Unit 4 is in MODE 1, 2, 3, or 4.
FIC-658B, FLOW IND CTRL FOR CCW RETURN FM SI PPS is isolated for maintenance.
General Operating Procedure or Shift Manager directs otherwise.

1. PLACE the following in PULL-TO-LOCK:

3A SAFETY INJECTION PUMP IV
3B SAFETY INJECTION PUMP IV

2. ENSURE 4-708F, UNIT 4 CCW HDR B RETURN FROM SI PUMPS is LOCKED CLOSED.

IV

3. ENSURE 4-793, UNIT 4 CCW HDR B SUPPLY TO SI PUMPS is LOCKED CLOSED.

IV

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 36 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.4 Aligning Unit 3 HHSI Pumps Cooling Water to the Unit 3 CCW System INITIAL (continued)

4. IF realigning COW to HHSI Pumps during a refueling outage AND cycling of 3-708F, UNIT 3 COW HDR B RETURN FROM SI PUMPS is required for 3-OSP-030.7, THEN:

A. OPEN 3-708F, UNIT 3 COW HDR B RETURN FROM SI PUMPS. B. CLOSE 3-708F, UNIT 3 COW HDR B RETURN FROM SI PUMPS. IV

5. ENSURE 3-793, UNIT 3 COW HDR B SUPPLY TO SI PUMPS is LOOKED OPEN.

IV Concurrent Verification

6. UNLOCK and THROTTLE 3-708F, UNIT 3 COW HDR B RETURN FROM SI PUMPS to maintain 20 to 30 GPM on FIO-658B.

CV

7. LOCK 3-708F, UNIT 3 COW HDR B RETURN FROM SI PUMPS.

IV

8. PLACE the following in Standby (mid position) at Unit 3 VPB:

o 3A SAFETY INJECTION PUMP IV o 3B SAFETY INJECTION PUMP IV

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 37 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.4 Aligning Unit 3 HHSI Pumps Cooling Water to the Unit 3 CCW System (continued)

9. At Unit 3 VPB, REMOVE Information Tags indicating previous CCW alignment on the following Control Switches:

3A SAFETY INJECTION PUMP o 3BSAFETYINJECTIONPUMP

10. At Unit 4 VPB, REMOVE Information Tags indicating previous CCW alignment on the following Control Switches:

3A SAFETY INJECTION PUMP
3B SAFETY INJECTION PUMP

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 38 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.5 Chemical Addition to CCW System INITIAL CAUTION All applicable safety precautions and PPE requirements of 0-ADM-033, PTN Industrial Safety Program is required to be complied with.

1. CHECK that Chemistry is available with the necessary chemicals to be added to the COW System.

2. ENSURE the following are CLOSED:

3-705N, CHEM POT FEEDER CCW SUPPLY
3-705G, CHEM POT FEEDER OUTLET TO CCW HDR A
3-705K, CHEM POT FEEDER OUTLET TO CCW HDR B

3. OPEN the following:

A. 3-705L, CHEM POT FEEDER DRAIN B. 3-746G, CHEM POT FEEDER CHEMICAL FILL C. 3-705M, CHEM POT FEEDER VENT

4. ENSURE Chem Pot Feeder is empty.

5. CLOSE 3-705L, CHEM POT FEEDER DRAIN.

6. OPEN CHEM POT cover.

7. DIRECT Chemistry to add chemicals to Chem Pot Feeder.

8. WHEN chemicals have been added to Chem Pot Feeder, THEN CLOSE 3-746G, CHEM POT FEEDER CHEMICAL FILL.

IV

9. CLOSE CHEM POT cover.

10. CLOSE 3-705M, CHEM POT FEEDER VENT.

11. OPEN 3-705N, CHEM POT FEEDER COW SUPPLY.

12. IF adding chemicals to Header A, THEN OPEN 3-705G, CHEM POT FEEDER OUTLET TO COW HDR A.

SlON NO: OCDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 39 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.5 Chemical Addition to CCW System (continued) INITIAL

13. IF adding chemicals to Header B, THEN OPEN 3-705K, CHEM POT FEEDER OUTLET TO COW HDR B.

14. AFTER at least 5 minutes of chemical addition, THEN ENSURE the following are CLOSED:

o 3-705G, CHEM POT FEEDER OUTLET TO COW HDR A IV

3-705K, CHEM POT FEEDER OUTLET TO COW HDR B IV

15. CLOSE 3-705N, CHEM POT FEEDER COW SUPPLY.

IV

16. IF additional chemicals are to be added, THEN REPEAT Section 5.5 Step 3 through Section 5.5 Step 15.

17. IF chemicals being added to COW System contain biocide, THEN NOTIFY Chemistry to collect the water drained out of the Ohem Pot Feeder, in the following step, into a catch container for proper disposal.

18. OPEN 3-705L, CHEM POT FEEDER DRAIN.

19. OPEN 3-705M, OHEM POT FEEDER VENT.

20. WHEN Chem Pot Feeder is completely drained, THEN CLOSE 3-705M, CHEM POT FEEDER VENT.

IV

21. CLOSE 3-705L, CHEM POT FEEDER DRAIN.

IV

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 40 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.6 Chemical Addition to CCW Surge Tank INITIAL CAUTION All applicable safety precautions and PPE requirements of 0-ADM-033, PTN Industrial Safety Program is required to be complied with.

1. CHECK that Chemistry is available with the necessary chemicals to be added to the CCW System.

2. ENSURE the following are CLOSED:

o 3-705N, CHEM POT FEEDER CCW SUPPLY

3-7050, CHEM POT FEEDER OUTLET TO CCW HDR A
3-705K, CHEM POT FEEDER OUTLET TO CCW HDR B o 3-705A, OLD CHEM POT FEEDER CCW SUPPLY

3. CLOSE 3-705J, CHEM POT FEEDER OUTLET TO CCW HDR B.

4. OPEN the following:

3-705L, CHEM POT FEEDER DRAIN
3-705M, CHEM POT FEEDER VENT o 3-746G, CHEM POT FEEDER CHEMICAL FILL

5. ENSURE Chem Pot Feeder is empty.

6. CLOSE 3-705L, CHEM POT FEEDER DRAIN.

7. OPEN CHEM POT cover.

8. DIRECT Chemistry to add chemicals to Chem Pot Feeder.

9. WHEN chemicals have been added to Chem Pot Feeder, THEN CLOSE 3-7460, CHEM POT FEEDER CHEMICAL FILL.

IV

10. CLOSE CHEM POT cover.

11. CLOSE 3-705M, CHEM POT FEEDER VENT.

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 41 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.6 Chemical Addition to CCW Surge Tank (continued) INITIAL NOTE 3-705F and 3-7050 are located in the New Fuel Room.

12. OPEN the following:

A. 3-705F, OLD CHEM POT FEEDER OUTLET TO CCW HDR B B. 3-7050, ISO VLV FOR OLD CHEM POT FEEDER TO COW SURGE TANK C. 3-705N, CHEM POT FEEDER COW SUPPLY

0. 3-705K, CHEM POT FEEDER OUTLET TO COW HDR B

13. AFTER at least 5 minutes of chemical addition, THEN CLOSE:

A. 3-705K, CHEM POT FEEDER OUTLET TO COW HDR B IV B. 3-705N, CHEM POT FEEDER COW SUPPLY Iv C. 3-705F, OLD CHEM POT FEEDER OUTLET TO COW HDR B IV

0. 3-7050, ISO VLV FOR OLD CHEM POT FEEDER TO COW SURGE TANK.

IV

14. IF chemicals being added to Surge Tank contain biocide, THEN NOTIFY Chemistry to collect the water drained out of the Chem Pot Feeder, in the following step, into a catch container for proper disposal.

15. OPEN 3-705L, CHEM POT FEEDER DRAIN.

16. OPEN 3-705M, CHEM POT FEEDER VENT.

17. ALLOW Chem Pot Feeder to completely drain.

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 42 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 56 Chemical Addition to CCW Surge Tank (continued) INITIAL

18. CLOSE 3-705M, CHEM POT FEEDER VENT.

IV

19. CLOSE 3-705L, CHEM POT FEEDER DRAIN.

IV

20. OPEN 3-705J, CHEM POT FEEDER OUTLET TO CCW HDR B.

IV

RV[StON NO.: - PROCtDURE TITLE: - PAGE: COMPONENT COOLING WATER SYSTEM 43 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.7 Filling CCW Header 3A from CCW Header 3B via Chemical Pot Feeder

1. ENSURE P1-3-612 is aligned to provide pressure indication of the operating CCW Pump.

2. INSTALL Vent Rigs on the following:

3-709A, CCW HDR A VENT
3-10-283, EMERG CONT CLR A CCW INLET VENT
3-10-748, ECC A RETURN TO COW HDR VENT VALVE
3-746E, RHR HX A SHELL SIDE VENT

3. UNLOCK and CLOSE 3-710A, COW HDRA SURGE TANK ISOL.

4. ENSURE COW Head Tank Level between 10% and 85%.

5. ENSURE the following are CLOSED:

3-705L, CHEM POT FEEDER DRAIN
3-705M, CHEM POT FEEDER VENT
3-705G, CHEM POT FEEDER OUTLET TO COW HDR A
3-705 K, CHEM POT FEEDER OUTLET TO CCW HDR B
3-705D, OLD CHEM POT FEEDER OUTLET TO COW HDR A
3-746G, CHEM POT FEEDER CHEMICAL FILL

6. ENSURE the following are OPEN:

3-705, CHEM POT FEEDER COW SUPPLY
3-705H, CHEM POT FEEDER OUTLET TO COW HDR A

7. ESTABLISH communication between the following:

Control Room
Operator at Chemical Pot Feeder
Operator venting COW Header 3A

8. OPEN 3-705N, OHEM POT FEEDER COW SUPPLY.

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 44 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.7 Filling CCW Header 3A from CCW Header 3B via Chemical Pot Feeder (continued) NOTE The following step will require coordination between the three Operators to fill and vent COW Header 3A, while maintaining CCW Head Tank Level between 10% and 85%. The following step may be repeated as required until the fill and vent is completed.

9. FILL and VENT COW Header 3A by concurrently performing the following steps:

A. MONITOR Ll-3-614A, LEVEL IND FOR COW HEAD TANK. B. THROTTLE 3-705G, CHEM POT FEEDER OUTLET TO COW HDR A as necessary to fill CCW Header 3A while maintaining COW Head Tank Level between 10% and 85%. C. MAKE UP to COW Surge Tank as necessary to maintain CCW Head Tank Level between 10% and 85% as follows: (1) ENSURE 3-711B, CCW HDR B MAKEUP WATER ISOL is OPEN. (2) ENSURE 3-710B, COW HDR B SURGE TANK ISOL is LOCKED OPEN. (3) OPEN MOV-3-832, PRIMARY WATER MAKEUP TO COW SURGE TANK. D. VENT CCW Header 3A from the following: (1) 3-709A, CCW HDR A VENT (2) 3-709B, COW HDR A-B VENT (3) 3-10-283, EMERG CONT CLR A COW INLET VENT (4) 3-10-748, ECC A RETURN TO COW HDR VENT VALVE (5) 3-746E, RHR HX A SHELL SIDE VENT and 3-765A, RHR HX A SHELL SIDE VENT

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 45 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.7 Filling CCW Header 3A from CCW Header 3B via Chemical Pot Feeder INITIAL (continued)

10. WHEN Fill and Vent is complete, THEN:

A. CLOSE 3-705G, CHEM POT FEEDER OUTLET TO COW HDR A. IV B. CLOSE 3-705N, CHEM POT FEEDER COW SUPPLY. IV C. ENSURE the following are CLOSED:

3-709A, COW HDR A VENT IV
3-709B, COW HDR A-B VENT
3-10-283, EMERG CONT CLR A COW INLET VENT IV
3-10-748, ECC A RETURN TO COW HDR VENT VALVE IV
3-746E, RHR HX A SHELL SIDE VENT IV
3-765A, RHR HX A SHELL SIDE VENT IV
MOV-3-832, PRIMARY WATER MAKEUP TO COW SURGE TANK.

IV

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 46 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.7 Filling CCW Header 3A from CCW Header 3B via Chemical Pot Feeder INITIAL (continued)

10. (continued)

D. ENSURE 3-711 B, COW HDR B MAKEUP WATER ISOL is OPEN. lv E. ENSURE the following are LOCKED OPEN:

3-710A, COW HDR A SURGE TANK ISOL.

IV

3-710B, COW HDR B SURGE TANK ISOL.

IV

REVISION NO.: PROCEDURE TITLE: PAGE: - COMPONENT COOLING WATER SYSTEM 47 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.8 Filling CCW Header 3B from CCW Header 3A via Chemical Pot Feeder

1. ENSURE P1-3-612 is aligned to provide pressure indication of the operating CCW Pump.

2. INSTALL VENT Rigs on the following:

9 3-7090, COW HDR B VENT o 3-10-284, EMERG CONT CLR C COW INLET VENT 9 3-10-282, EMERG CONT CLR B CCW INLET VENT o 3-746F, RHR HX B SHELL SIDE VENT

3-10-690, ECC B RETURN TO COW HDR VENT VALVE

3. UNLOCK and CLOSE 3-710B, COW HDR B SURGE TANK ISOL.

4. ENSURE COW Head Tank Level between 10% and 85%.

5. ENSURE the following are CLOSED:

9 3-705L, CHEM POT FEEDER DRAIN 9 3-705M, CHEM POT FEEDER VENT o 3-705G, CHEM POT FEEDER OUTLET TO COW HDR A 9 3-705K, CHEM POT FEEDER OUTLET TO COW HDR B

                 °     3-705F, OLD OHEM POT FEEDER OUTLET TO COW HDR B 9     3-746G, CHEM POT FEEDER CHEMICAL FILL

6. ENSURE the following are OPEN:

3-705, CHEM POT FEEDER COW SUPPLY 3-705J, OHEM POT FEEDER OUTLET TO COW HDR B

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 48 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.8 Filling CCW Header 3B from CCW Header 3A via Chemical Pot Feeder (continued)

7. ESTABLISH communication between the following:

Control Room o Operator at Chemical Pot Feeder o Operator venting CCW Header 3B

8. OPEN 3-705N, CHEM POT FEEDER CCW SUPPLY.

NOTE

The following step will require coordination between the three operators to fill and vent CCW Header 3B, while maintaining CCW Head Tank Level between 10% and 85%.
The following step may be repeated as required until the fill and vent is completed.

9. FILL and VENT CCW Header 3B by concurrently performing the following steps:

A. MONITOR LI-3-614A, LEVEL IND FOR CCW HEAD TANK on VPB. B. THROTTLE 3-705K, CHEM POT FEEDER OUTLET TO CCW HDR B as necessary to fill CCW Header 3B while maintaining CCW Head Tank Level between 10% and 85%. C. MAKE UP to COW Surge Tank as necessary to maintain COW Head Tank Level between 10% and 85% as follows: (1) OPEN 3-71 1A, CCW HDR A MAKEUP WATER ISOL. (2) ENSURE 3-710A, COW HDR A SURGE TANK ISOL is LOCKED OPEN. (3) OPEN MOV-3-832, PRIMARY WATER MAKEUP TO COW SURGE TANK.

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 49 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.8 Filling CCW Header 3B from CCW Header 3A via Chemical Pot Feeder INITIAL (continued)

9. (continued)

0. VENT CCW Header 3B from the following:

3-7090, 00W HDR B VENT
3-10-284, EMERG CONT CLR C COW INLET VENT o 3-10-282, EMERG CONT CLR B COW INLET VENT o 3-746F, RHR HX B SHELL SIDE VENT and 3-765B, RHR HX B SHELL SIDE VENT o 3-10-690, ECC B RETURN TO COW HDR VENT VALVE

10. WHEN Fill and Vent is complete, THEN:

A. CLOSE 3-705K, CHEM POT FEEDER OUTLET TO COW HDR B. IV B. ENSURE the following are CLOSED: o MOV-3-832, PRIMARY WATER MAKEUP TO COW SURGE TANK IV o 3-71 IA, CCW HDR A MAKEUP WATER ISOL. IV

3-7090, COW HDR B VENT IV
3-10-284, EMERG CONT CLR C COW INLET VENT IV

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 50 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.8 Filling CCW Header 3B from CCW Header 3A via Chemical Pot Feeder INITIAL (continued)

10. B. (continued)

3-10-282, EMERG CONT CLR B CCW INLET VENT IV
3-746F, RHR HX B SHELL SIDE VENT IV
3-765B, RHR HX B SHELL SIDE VENT IV
3-10-690, ECC B RETURN TO CCW HDR VENT VALVE IV C. CLOSE 3-705N, CHEM POT FEEDER CCW SUPPLY.

IV D. ENSURE the following are LOCKED OPEN: o 3-710A, CCW HDR A SURGE TANK ISOL. IV

3-710B, COW HDR B SURGE TANK ISOL.

IV

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 51 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.9 Placing CCW in Single Pump Operation in Modes 5, 6, or Defueled CAUTION Prior to performing this section, review 0-ADM-051, Outage Risk Assessment, for the duration of single CCW pump operation to evaluate impact to outage risk.

1. CHECK that Unit is in one of the following:

MODE 5 - Cold Shutdown
MODE 6 - Refueling
Defueled

2. CHECK RCS Temperature is less than 180°F.

3. ENSURE the following Fan Motors are NOT operating:

3A EMERG CNTMT COOLER
3B EMERG CNTMT COOLER
30 EMERG CNTMT COOLER

4. ENSURE the following are CLOSED:

CV-3-2908, 3A EM ERG CNTMT COOLER OUTLET
CV-3-2906, 38 EMERG CNTMT COOLER OUTLET
CV-3-2907, 3C EMERG CNTMT COOLER OUTLET

5. IF two RHR Pumps are operating, THEN STOP one RHR Pump.

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 52 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.9 Placing CCW in Single Pump Operation in Modes 5, 6, or Defueled (continued) CAUTION IF Unit is NOT Defueled, THEN opening both 3-757C and 3-757D will disable FCV-3-605 from performing its designed function.

6. IF RHR Loop A is in service, THEN:

A. ENSURE 3-7570, RHR HX B BYPASS HDR ISOLATION is LOCKED CLOSED. B. ENSURE MOV-3-749B, RHR HX 3B CCW OUTLET, is CLOSED.

7. IF RHR Loop B is in service, THEN:

A. ENSURE 3-757D, RHR HX A BYPASS HDR ISOLATION is LOCKED CLOSED. B. ENSURE MOV-3-749A, RHR HX 3A COW OUTLET, is CLOSED.

8. STOP one COW Pump.

9. IF NOT Defueled, THEN INITIATE an ECO to hang Caution tags on VPB RHR Controls indicating the current alignment of the following:

o 3-757D, RHR HX A BYPASS HDR ISOLATION 3-7570, RHR HX B BYPASS HDR ISOLATION

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 53 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.10 Restoring CCW from Single Pump Operation in Modes 5 or 6 INITIAL ENSURE all available COW HXs are in service. CAUTION To prevent exceeding COW HX maximum flowrates, the number of operating CCW Pumps should be one less than the number of in-service COW HXs. o Motor starting duty limits are as follows: o With motor at ambient temperature, two successive starts are allowed (the motor must coast to rest between starts). o With motor at operating temperature, one start is allowed. Subsequent starts require that the motor is allowed to cool by standing idle for one hour or running for one half hour. o When NOT aligned to the sequencer, the 30 CCW Pump should NOT be operated. (Except for pump swapping)

2. START gj COW Pump.

o 3ACCWPUMP

3BCCWPUMP 0 3CCCWPUMP

3. PLACE the Standby COW Pump in AUTO.

o 3A COW PUMP IV o 3B COW PUMP IV o 3000WPUMP IV

4. IF Caution Tags were used, THEN RELEASE ECO to Caution Tags on VPB RHR Controls indicating the current alignment of 3-7570 and 3-757D, RHR Hx Bypass Hdr Isolations.

REVISION NO.: PROCEDURE TITLE: - PAGE: COMPONENT COOLING WATER SYSTEM 54 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.10 Restoring CCW from Single Pump Operation in Modes 5 or 6 INITIAL (continued)

5. ENSURE the foiJowing are OPEN:

3-757D, RHR HX A BYPASS HDR ISOLATION Iv
MOV-3-749A, RHR HX 3A CCW OUTLET Iv
3-7570, RHR HX B BYPASS HDR ISOLATION IV MOV-3--749B, RHR HX 3B COW OUTLET Iv

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 55 of 131 PROCEDURE NO.: 3-NO P-030 TURKEY POINT UNIT 3 5.11 Feed and Bleed of the CCW System

1. ENSURE 3A COW Pump is operating.

2. CHECK that Maintenance has connected a hose from 3-702D, COW PUMP A DISCHARGE DRAIN, to the Molybdate Storage Tank.

3. IF Molybdate Storage Tank is greater than 1/2 full, THEN DRAIN Molybdate Storage Tank per 0-OP-061 .13.

4. NOTIFY Chemistry of commencing the COW Feed and Bleed.

5. IF in MODE 1,2, or 3, THEN:

A. REQUEST that Chemistry estimate the volume of Feed and Bleed necessary to achieve the desired chemistry change. NOTE One cycle of COW Head Tank Level between 10% and 85% is approximately 240 gallons. B. DETERMINE the number of cycles of COW Head Tank Level between 10 and 85% that are necessary to achieve the required volume of Feed and Bleed: cycles C. PLACE RCV-3-609, COW HEAD TANK VENT in CLOSE. D. FEED and BLEED COW: (1) OPEN MOV-3-832, PRIMARY WATER MAKEUP TO COW SURGE TANK. (2) WHEN LI-3-614A, LEVEL IND FOR COW HEAD TANK is between 80 and 85%, THEN CLOSE MOV-3-832, PRIMARY WATER MAKEUP TO COW SURGE TANK. (3) ESTABLISH direct communications between Control Room and the operator at 3-702D, COW PUMP A DISCHARGE DRAIN. (4) THROTTLE OPEN 3-702D, COW PUMP A DISCHARGE DRAIN.

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 56 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.11 Feed and Bleed of the CCW System (continued) INITIAL

5. D. (continued)

CAUTION WHEN in MODE 1, 2 or 3, LI-3-614A, LEVEL IND FOR CCW HEAD TANK is required to be maintained greater than 10% at all times. (5) WHEN Ll-3-614A, LEVEL IND FOR COW HEAD TANK is between 10 and 15%, THEN CLOSE 3-702D, COW PUMP A DISCHARGE DRAIN. E. REPEAT Section 5.11 Step 5.D as necessary to achieve the required volume of Feed and Bleed determined previously. F. IF LI-3-614A, LEVEL IND FOR COW HEAD TANK on VPB is stable below 85%, AND COW Head Tank Overflow Line is drained, THEN PLACE RCV-3-609, COMPONENT COOLING HEAD TANK VENT in AUTO. IV

6. IF in MODE 4, 5, 6 or Defueled, AND COW System level is being maintained in the COW Head Tank, THEN:

A. PLACE RCV-3-609, CCW HEAD TANK VENT in CLOSE. B. FEED and BLEED COW: (1) ESTABLISH direct communications between Control Room and operator at 3-702D, COW PUMP A DISCHARGE DRAIN. (2) THROTTLE OPEN 3-702D, COW PUMP A DISCHARGE DRAIN. (3) WHEN Ll-3-613A, LEVEL IND FOR COW SURGE TANK is between 50 and 55%, THEN CLOSE 3-702D, COW PUMP A DISCHARGE DRAIN. (4) OPEN MOV-3-832, PRIMARY WATER MAKEUP TO COW SURGE TANK. (5) WHEN LI-3-614A, LEVEL IND FOR COW HEAD TANK is between 50 and 85%, THEN CLOSE MOV-3-832, PRIMARY WATER MAKEUP TO COW SURGE TANK.

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 57 Of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.11 Feed and Bleed of the CCW System (continued) INITIAL

6. (continued)

C. IF an additional Feed and Bleed is recommended by Chemistry, THEN REPEAT Section 5.11 Step 6.B. D. IF Ll-3-614A, LEVEL IND FOR COW HEAD TANK on VPB is stable below 85%, AND COW Head Tank Overflow Line is drained, THEN PLACE RCV-3-609, COMPONENT COOLING HEAD TANK VENT in AUTO. IV

7. IF in MODE 4, 5, 6 or Defueled, AND CCW System level is being maintained in the Surge Tank, THEN:

A. FEED and BLEED COW: (1) OPEN MOV-3-832, PRIMARY WATER MAKEUP TO COW SURGE TANK. (2) WHEN Ll-3-613A, LEVEL IND FOR CCW SURGE TANK is between 75 and 85%, THEN CLOSE MOV-3-832, PRIMARY WATER MAKEUP TO COW SURGE TANK. (3) ESTABLISH direct communications between Control Room and operator at 3-702D, COW PUMP A DISCHARGE DRAIN. (4) THROTTLE OPEN 3-702D, CCW PUMP A DISCHARGE DRAIN. (5) WHEN LI-3-613A, LEVEL IND FOR CCW SURGE TANK is between 50 and 55%, THEN CLOSE 3-702D, COW PUMP A DISCHARGE DRAIN. B. IF an additional Feed and Bleed is recommended by Chemistry, THEN REPEAT Section 5.11 Step 7.A.

8. NOTIFY Chemistry of completing the COW Feed and Bleed.

9. NOTIFY Maintenance to remove hose from 3-702D, COW PUMP A DISCHARGE DRAIN.

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 58 of 131 PROCEDURE NO.: 3-NO P-030 TURKEY POINT UNIT 3 5.11 Feed and Bleed of the CCW System (continued) INITIAL

10. ENSURE the following are CLOSED:

o MOV-3-832, PRIMARY WATER MAKEUP TO CCW SURGE TAN K IV e 3-702D, COW PUMP A DISCHARGE DRAIN IV

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 59 Of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.12 Lowering CCW System Level

1. IF Chemistry directs COW fluids to be drained into the Molybdate Storage Tank, THEN ENSURE adequate available volume in Molybdate Storage Tank.

2. ESTABLISH direct communications between Control Room AND the Operator performing system draining.

N OTE Unless directed otherwise by Chemistry, drain hoses are required to be routed to the Molybdate Storage Tank. IF permitted by Chemistry, drain hoses may be routed to the storm drains.

3. PERFORM the following at secured CCW PUMP:

IF draining from 3A CCW Pump, THEN CONNECT a drain hose from 3-702D, CCW PUMP A DISCHARGE DRAIN.
IF draining from 3B CCW Pump, THEN CONNECT a drain hose from 3-702E, COW PUMP B DISCHARGE DRAIN.
IF draining from 30 CCW Pump, THEN CONNECT a drain hose from 3-702F, CCW PUMP C DISCHARGE DRAIN.

4. NOTIFY Control Room of commencing CCW System draining.

5. LOWER CCW System Level as follows:

IF draining from 3A CCW PUMP, THEN THROTTLE OPEN 3-702D, CCW PUMP A DISCHARGE DRAIN.
IF draining from 3B CCW PUMP, THEN THROTTLE OPEN 3-702E, CCW PUMP B DISCHARGE DRAIN.
IF draining from 3C COW PUMP, THEN THROTTLE OPEN 3-702F, CCW PUMP C DISCHARGE DRAIN.

EV1SiON NO.: - PiOCEbURE titL: - PAGE: COMPONENT COOLING WATER SYSTEM 60 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.12 Lowering CCW System Level (continued) INITIAL

6. WHEN notified by Control Room that CCW System is at desired level, THEN:

A. IF draining from 3A COW PUMP, THEN: (1) CLOSE 3-702D, CCW PUMP A DISCHARGE DRAIN. IV (2) REMOVE drain hose from 3-702D. (3) CAP 3-702D. B. IF draining from 3B CCW PUMP, THEN: (1) CLOSE 3-702E, COW PUMP B DISCHARGE DRAIN. IV (2) REMOVE drain hose from 3-702E. (3) CAP 3-702E. C. IF draining from 30 COW PUMP, THEN: (1) CLOSE 3-702F, COW PUMP C DISCHARGE DRAIN. IV (2) REMOVE drain hose from 3-702F. (3) CAP 3-702F.

7. IF no additional draining is to be performed, THEN ENSURE Drain Hose at COW PUMP is stored.

8. IF COW System high level resulted in an COW Head Tank overflow, THEN PERFORM Draining CCW Head Tank Overflow Line per Section 5.13.

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 61 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.13 Draining CCW Head Tank Overflow Line INITIAL

1. CONNECT a drain hose to 3-1021, CCW HEAD TANK OVERFLOW LINE DRAIN VALVE.

2. ROUTE the drain hose discharge to a 55 gallon drum or equivalent suitable container.

3. OPEN 3-1021, CCWHEADTANKOVERFLOWLINE DRAIN VALVE.

4. WHEN COW Head Tank Overflow Line is drained, THEN CLOSE 3-1021, COW HEAD TANK OVERFLOW LINE DRAIN VALVE.

IV

5. CHECK LI-3-614A, LEVEL IND FOR COW HEAD TANK indicates on-scale.

6. PLACE RCV-3-609, COW HEAD TANK VENT in AUTO.

IV

7. CHECK RCV-3-609, COW HEAD TANK VENT indicates OPEN.

8. IF no additional draining is to be performed, THEN ENSURE drain hose at 3-1 021, COW HEAD TANK OVERFLOW LINE DRAIN VALVE is removed and stored.

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 62 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.14 Maintenance Alignment for FIC-658B, Unit 3 HHSI Pumps CCW Return INITIAL Flow Indicator CHECK the following:

Unit3is in MODE 1,2,3, or4.

o Unit4 isin MODE 1,2,3, or4. o CCW flow to the Unit 3 HHSI Pumps is aligned to Unit 3.

CCW flow to the Unit 4 HHSI Pumps is aligned to Unit 4.
Unit 3 COW headers are cross-tied.
Unit 4 CCW headers are cross-tied.

NOTE

The following steps should be performed without delay to minimize time of entry into Technical Specification Action Statements.
The following steps align Unit 3 HHSI Pumps to be supplied from COW Header 4B with return flow to CCW Header 4A.

2. ALIGN Unit 3 HHSI Pumps Cooling Water to Unit 4 CCW System:

A. PLACE the following in PULL-TO-LOCK:

3A SAFETY INJECTION PUMP lv
3B SAFETY INJECTION PUMP Iv B. CLOSE and LOCK 3-708F, UNIT 3 CCW HDR B RETURN FROM SI PUMPS.

IV C. CLOSE and LOCK 3-793, UNIT 3 COW HDR B SUPPLY TO SI PUMPS. IV

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 63 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.14 Maintenance Alignment for FIC-658B, Unit 3 HHSI Pumps CCW Return INITIAL Flow Indicator (continued)

2. (continued)

D. CLOSE 838A, CCW HDR B RETURN FROM SI PUMP 3A. IV E. CLOSE 838E, COW HDR B RETURN FROM SI PUMP 3B. IV F. UNLOCK and OPEN 4-793, UNIT 4 COW HDR B SUPPLY TO SI PUMPS. IV G. LOCK OPEN 4-793, UNIT 4 COW HDR B SUPPLY TO SI PUMPS. IV H. OPEN 838C, CCW HDR A RETURN FROM SI PUMP 3A. IV I. OPEN 838G, COW HDR A RETURN FROM SI PUMP 3B. IV J. RECORD flow indication on FIO-658A: GPM Concurrent Verification K. UNLOCK and THROTTLE 4-708E, UNIT 4 COW HDR A RETURN FROM SI PUMPS to maintain flow on FIC-658A at 20 to 30 GPM greater than flow recorded in above step. CV L. LOCK 4-708E, UNIT 4 COW HDR A RETURN FROM SI PUMPS in this throttled position. IV

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 64 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.14 Maintenance Alignment for FIC-658B, Unit 3 HHSI Pumps CCW Return INITIAL Flow Indicator (continued)

2. (continued)

NOTE HHSI Pump CCW Return Flow in the following step should be between 40 and 60 GPM. M. RECORD flow indication on FIC-658A: GPM N. PLACE the following in Standby (mid position) at Unit 3 VPB: 3A SAFETY INJECTION PUMP IV 3B SAFETY INJECTION PUMP IV

3. NOTIFY Shift Manager that FIC-658B is isolated for maintenance.

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 65 of 131 PROCEDURE NO.: 3-NO P-030 TURKEY POINT UNIT 3 5.14 Maintenance Alignment for FIC-658B, Unit 3 HHSI Pumps CCW Return INITIAL Flow Indicator (continued)

4. WHEN maintenance on FIC-658B is complete, THEN ALIGN Unit 3 HHSI Pumps Cooling Water to Unit 3 COW System:

A. PLACE the following in PULL-TO-LOCK:

3A SAFETY INJECTION PUMP IV
3B SAFETY INJECTION PUMP IV B. CLOSE and LOCK the following:

o 838C, CCW HDR A RETURN FROM SI PUMP 3A IV

838G, CCW HDR A RETURN FROM SI PUMP 3B IV C. OPEN 838A, COW HDR B RETURN FROM SI PUMP 3A.

IV

0. OPEN 838E, CCW HDR B RETURN FROM SI PUMP 3B.

IV E. UNLOCK and CLOSE 4-793, UNIT 4 COW HDR B SUPPLY TO SI PUMPS. F. LOCK CLOSED 4-793, UNIT 4 COW HDR B SUPPLY TO SI PUMPS. IV G. UNLOCK and OPEN 3-793, UNIT 3 COW HDR B SUPPLY TO SI PUMPS.

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 66 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.14 Maintenance Alignment for FIC-658B, Unit 3 HHSI Pumps CCW Return INITIAL Flow Indicator (continued)

4. (continued)

H. LOCK OPEN 3-793, UNIT 3 COW HDR B SUPPLY TO SI PUMPS. IV Concurrent Verification I. UNLOCK and THROTTLE 3-708F, UNIT 3 COW HDR B RETURN FROM SI PUMPS to maintain 20 to 30 GPM on FIC-658B. CV J. UNLOCK and THROTTLE 4-708E, UNIT 4 COW HDR A RETURN FROM SI PUMPS to maintain 20 to 30 GPM on F I C-658A. CV NOTE Annunciator X 3/6, SI PP COOLING WATER LO FLOW setpoint is 16.8 GPM. CAUTION COW Flow in the following step should NOT be reduced below 13.6 GPM. K. IF post-maintenance testing of FIC-658B is required, THEN: (1) THROTTLE CLOSED 3-708F, UNIT 3 CCW HDR B RETURN FROM SI PUMPS, until Annunciator X 3/6, SI PP COOLING WATER LO FLOW alarms. (2) CHECK FIC-658B indicates approximately 17 GPM.

EV1iON Na.: - PRdCEtU tItLE: - PAGE: COMPONENT COOLING WATER SYSTEM 67 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.14 Maintenance Alignment for FIC-658B, Unit 3 HHSI Pumps CCW Return INITIAL Flow Indicator (continued)

4. K. (continued)

Concurrent Verification (3) THROTTLE 3-708F, UNIT 3 cow HDR B RETURN FROM SI PUMPS to maintain 20 to 30 GPM on Fl 0-658 B. cv L. WHEN flow is balanced and stabilized at 20 to 30 GPM on both FIC658A AND Fl0-658B, THEN LOCK the following:

4-708E, UNIT 4 COW HDR A RETURN FROM SI PUMPS cv
3-708F, UNIT 3 COW HDR B RETURN FROM SI PUMPS cv M. PLACE the following in Standby (mid position) at Unit 3 VPB:
3A SAFETY INJECTION PUMP lv
3B SAFETY INJECTION PUMP lv

5. NOTIFY Shift Manager that:

FIC-658B is returned to service.
Unit 3 HHSI Pumps Cooling water is aligned to Unit 3 CCW System.

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 68 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.15 Removing 3A CCW HX from Service INITIAL

1. CHECK the necessary ECO is available for 3A CCW HX.

2. ENSURE an operator is in continuous communication with Control Room and is available to adjust CCW flow to the NRHX to maintain VCT temperature between 115 and 120°F.

CAUTION e To prevent exceeding the maximum flowrates on the CCW HXs, the number of operating CCW Pumps should be one less than the number of in-service CCW HXs. e Prior to removing a CCW HX from service CCW Pump C is required to be OFF, unless it is aligned to automatically start on the sequencer due to another pump being out of service.

3. IF two CCW Pumps are operating, THEN STOP one CCW PUMP.

CAUTION When a CCW HX is removed from service, the CCW flow is required to be isolated except as described below: a When Unit is in MODE 5 or MODE 6, (regardless of whether the affected HX tube bundle is filled with water or drained), then ICW may be isolated to one CCW HX, provided that CCW flow remains aligned to all three CCW HXs. In this configuration, the non-running CCW Pumps are NOT required to be placed in PULL-TO-LOCK. a Following plant shutdown after plant has been Defueled greater than 72 hours, AND maintenance requires the ICW System to be operated in a split-header configuration, THEN ICW may be isolated to CCW HXs with CCW flow aligned to two CCW HXs. One CCW HX will operate in the bypass mode and will NOT remove heat from the system. (This alignment was analyzed by Engineering Technical Response Memorandum, dated April 3, 2008).

4. IF both RHR HXs are in service, THEN:

A. PLACE both non-operating CCW Pumps in PULL-TO-LOCK. IV B. ENTER the LCO Action Statement for CCW Pumps.

REViSiON NO. PROCEDURE TITLE: - PAE: COMPONENT COOLING WATER SYSTEM 69 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.15 Removing 3A CCW HX from Service (continued)

5. REMOVE 3A CCW HX from service:

CAUTION Removing a COW HX from service will cause CVCS Letdown line temperature to rise, resulting in a drop in Tave and Reactor Power. A. NOTIFY Control Room that 3A COW HX is being removed from service which will cause CVCS Letdown line temperature to rise, resulting in a drop in Tave and Reactor Power. B. CLOSE 3-712A, CCW HEAT EXCHANGER 3A INLET ISOL VALVE. C. CLOSE 3-50-371, lOW TO CCW HX 3A INLET ISOL.

0. OPEN 3-50-585, COW TO HX 3A lOW TUBESIDE VENT.

E. CLOSE and LOCK 3-50-380, COW HX 3A lOW OUTLET ISOL. F. CHECK areas between the COW HX drain valves and the floor drains are clear of electrical or other sensitive equipment. NOTE While draining the HX Waterbox, care should be taken to prevent exceeding the floor drain capacity. G. OPEN 3-50-374, COW HX 3A ICWTUBESIDE DRN. H. OPEN 3-50-377, COW HX 3A lOW OUTLET PX-1468 ROOT.

6. INITIATE EOO for 3A COW HX.

7. REFER TO 3-OP-019, Intake Cooling Water System for lOW Operation with COW HX 3A out of service.

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 70 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.16 Removing 3B CCW HXfrom Service INITIAL

1. CHECK the necessary ECO is available for 3B COW HX.

2. ENSURE an operator is in continuous communication with Control Room and is available to adjust CCW flow to the NRHX to maintain VCT temperature between 115 and 120°F.

CAUTION e To prevent exceeding the maximum flowrates on the COW HXs, the number of operating CCW Pumps should be one less than the number of in-service COW HXs. Prior to removing a COW HX from service, C COW Pump is required to be OFF, unless it is aligned to automatically start on the sequencer due to another pump being out of service.

3. IF CCW Pumps are operating, THEN STOP one CCW PUMP.

CAUTION When a CCW HX is removed from service, the COW flow is required to be isolated except as described below:

             . When Unit is in MODE 5 or MODE 6, (regardless of whether the affected HX tube bundle is filled with water or drained), then ICW may be isolated to one CCW HX, provided that CCW flow remains aligned to all three COW HXs. In this configuration, the non-running COW Pumps are NOT required to be placed in PULL-TO-LOCK.
             . Following plant shutdown after plant has been Defueled greater than 72 hours, AND maintenance requires the lOW System to be operated in a split-header configuration, THEN lOW may be isolated to two COW HXs with COW flow aligned to two COW HXs. One COW HX will operate in the bypass mode and will NOT remove heat from the system. (This alignment was analyzed by Engineering Technical Response Memorandum, dated April 3, 2008).

4. IF RHR HXs are in service, THEN:

A. PLACE both non-operating COW Pumps in PULL-TO-LOOK. IV B. ENTER the LOO Action Statement for COW Pumps.

REVtS[ON NO.: PROCEDURE ]TI1E: - - - COMPONENT COOLING WATER SYSTEM 71 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.16 Removing 3B CCW HX from Service (continued)

5. REMOVE 3B CCW HX from service:

CAUTION Removing a COW HX from service wifl cause CVCS Letdown line temperature to rise, resulting in a drop in Tave and Reactor Power. A. NOTIFY Control Room that 3B COW HX is being removed from service which will cause CVCS Letdown line temperature to rise, resulting in a drop in Tave and Reactor Power. B. CLOSE 3-712B, CCW HEAT EXCHANGER 3B INLET ISOL VALVE. C. CLOSE 3-50-361, lOW TO COW HX 3B INLET ISOL. D. OPEN 3-50-365, COW TO HX 3B lOW TUBESIDE VENT. E. CLOSE and LOCK 3-50-370, COW HX 3B ICW OUTLET ISOL. F. CHECK areas between the CCW HX drain valves and the floor drains are clear of electrical or other sensitive equipment. NOTE While draining the HX Waterbox, care should be taken to prevent exceeding the floor drain capacity. G. OPEN 3-50-364, COW HX 3B lOW TUBESIDE DRN. H. OPEN 3-50-367, COW HX 3B lOW OUTLET PX-1470 ROOT.

6. INITIATE ECO for 3B COW HX.

7. REFER TO 3-OP-019, Intake Cooling Water System for lOW Operation with COW HX 3B out of service.

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 72 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.17 Removing 3C CCW HX from Service INITIAL

1. CHECK the necessary ECO is available for 3C COW HX.

2. ENSURE an operator is in continuous communication with Control Room and is available to adjust CCW flow to the NRHX to maintain VCT temperature between 115 and 120°F.

CAUTION

To prevent exceeding the maximum flowrates on the CCW HXs, the number of operating CCW Pumps should be one less than the number of in-service COW HXs.

e Prior to removing a COW HX from service the C COW Pump is required to be OFF, unless it is aligned to automatically start on the sequencer due to another pump being out of service.

3. IF two COW Pumps are operating, THEN STOP one COW PUMP from VPB.

CAUTION When a COW HX is removed from service, the COW flow is required to be isolated except as described below: o When Unit is in MODE 5 or MODE 6, (regardless of whether the affected HX tube bundle is filled with water or drained), then lOW may be isolated to one COW HX, provided that COW flow remains aligned to all three COW HXs. In this configuration, the non-running COW Pumps are NOT required to be placed in PULL-TO-LOCK. Following plant shutdown after plant has been Defueled greater than 72 hours, AND maintenance requires the lOW System to be operated in a split-header configuration, THEN TOW may be isolated to two OCW HXs with COW flow aligned to two COW HXs. One COW HX will operate in the bypass mode and will NOT remove heat from the system. (This alignment was analyzed by Engineering Technical Response Memorandum, dated April 3, 2008).

4. IF both RHR HXs are in service, THEN:

A. PLACE both non-operating COW Pumps in PULL-TO-LOCK. IV B. ENTER the LCO Action Statement for COW Pumps.

REVISION NO.: PROCEDURE TITLE: - PAGE: - - COMPONENT COOLING WATER SYSTEM 73 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 517 Removing 3C CCW HX from Service (continued)

5. REMOVE 3C COW HX from Service:

CAUTION Removing a CCW HX from service will cause CVCS Letdown line temperature to rise, resulting in a drop in Tave and Reactor Power. A. NOTIFY Control Room that 3C COW HX is being removed from service which will cause CVCS Letdown line temperature to rise, resulting in a drop in Tave and Reactor Power. B. CLOSE 3-712C, CCW HEAT EXCHANGER 3C INLET ISOL VALVE. C. CLOSE 3-50-351, ICWTO COW HX 3C INLET ISOL. D. OPEN 3-50-355, COW TO HX 3C lOW TUBESIDE VENT. E. CLOSE and LOCK 3-50-382, OUTLET VLV FOR lOW DISCH FROM CCW HX 3C. F. CHECK areas between the CCW HX drain valves and the floor drains are clear of electrical or other sensitive equipment. NOTE While draining the HX Waterbox, care should be taken to prevent exceeding the floor drain capacity. G. OPEN 3-50-354, COW HX 3C ICWTUBESIDE DRN. H. OPEN 3-50-357, COW HX 30 lOW OUTLET PX-1472 ROOT.

6. INITIATE ECO for 30 COW HX.

7. REFER TO 3-OP-019, Intake Cooling Water System for lOW Operation with COW HX 30 out of service.

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 74 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.18 Restoring 3A CCW HX to Service INITIAL CHECK ECO for 3A COW HX is released.

2. ENSURE an operator is in continuous communication with Control Room and is available to adjust CCW flow to the NRHX to maintain VCT temperature between 115 and 120°F.

CAUTION Restoring a CCW HX to service will cause CVCS Letdown line temperature to drop, resulting in a rise in Tave and Reactor Power.

3. RESTORE 3A COW HX to Service:

A. REQUEST that Chemistry determine if the COW fluid can be vented to a floor drain, or if it needs to be collected in a suitable storage container. B. NOTIFY Control Room that the 3A COW HX is being restored to service. C. INFORM RO of potential reactivity changes. D. CLOSE 3-50-377, COW HX 3A lOW OUTLET PX-1468 ROOT. IV E. CLOSE 3-50-374, CCW HX 3A lOW TUBESIDE DRN. IV F. CHECK areas between the COW HX vent valves and the floor drains are clear of electrical or other sensitive equipment. G. OPEN 3-50-371, lOW TO COW HX 3A INLET ISOL. IV H. VENT 3A COW HX from 3-50-585, COW TO HX 3A lOW TUBESIDE VENT. I. ENSURE 3-50-585, COW TO HX 3A lOW TUBESIDE VENT is CLOSED. IV

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 75 of 131 PROCEDURE NO.: 3-NO P-030 TURKEY POINT UNIT 3 5.18 Restoring 3A CCW HX to Service (continued) INITIAL

3. (continued)

J. UNLOCK and OPEN 3-50-380, CCW HX 3A lOW OUTLET ISOL. K. LOCK OPEN 3-50-380, CCW HX 3A ICW OUTLET ISOL. IV CAUTION Placing a CCW HX in service will cause CVCS Letdown line temperature to drop, resulting in a rise in Tavg and Reactor Power. L. NOTIFY Control Room that the following step will cause CVCS Letdown line temperature to drop, resulting in a rise in Tavg and Reactor Power. M. OPEN 3-712A, CCW HEAT EXCHANGER 3A INLET ISOL VALVE. IV

4. NOTIFY Control Room that the 3A CCW HX is restored to service.

5. IF non-operating CCW Pumps were placed in PULL-TO-LOCK due to the CCW HX being removed from service, THEN PLACE non-operating CCW Pumps in AUTO.

IV

6. ENSURE CCW Pumps are restored to current plant requirements.

7. IF throttled per 3-NOP-019 with one ICW/CCW HX OOS, THEN:

A. ENSURE the following are LOCKED OPEN: e 3-50-370, COW HX 3B lOW OUTLET ISOL IV e 3-50-382, OUTLET VLV FOR ICW DISCH FROM CCW HXC IV

EVISKN Nc.: PROCEDURE TItLE: COMPONENT COOLING WATER SYSTEM 76 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 &18 Restoring 3A CCW HX to Service (continued)

7. (continued)

B. ENSURE the following are OPEN: a 3-50-831A, OUTLET ISOL VALVE TPCW HX A ICW SYS a 3-50-831 B, ICW TO TPCW B HX OUTLET ISOL a 3-50-831 C, ICW TO TPCW C HX OUTLET ISOL

vFsroN NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 77 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.19 Restoring 3B CCW HX to Service INITIAL CHECK ECO for 3B CCW HX is released.

2. ENSURE an operator is in continuous communication with Control Room and is available to adjust COW flow to the NRHX to maintain VCT temperature between 115 and 120°F.

CAUTION Restoring a COW HX to service will cause CVCS Letdown line temperature to drop, resulting in a rise in Tave and Reactor Power.

3. RESTORE 3B CCW HX to Service:

A. REQUEST that Chemistry determine if the CCW fluid can be vented to a floor drain, or if it needs to be collected in a suitable storage container. B. NOTIFY Control Room that the 3B CCW HX is being restored to service. C. IN FORM RO of potential reactivity changes.

0. CLOSE 3-50-367, COW HX 3B ICW OUTLET PX-1470 ROOT.

IV E. CLOSE 3-50-364, COW HX 3B ICW TUBESIDE DRN. IV F. CHECK areas between the COW HX vent valves and the floor drains are clear of electrical or other sensitive equipment. G. OPEN 3-50-361, lOW TO COW HX 3B INLET ISOL. IV H. VENT 3B COW HX from 3-50-365, CCW TO HX 3B lOW TUBESIDE VENT. I. ENSURE 3-50-365, COW TO HX 3B lOW TUBESIDE VENT is CLOSED. IV

REViSION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 78 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.19 Restoring 3B CCW HX to Service (continued) INITIAL

3. (continued)

J. UNLOCK and OPEN 3-50-370, CCW HX 3B ICW OUTLET ISOL. K. LOCK OPEN 3-50-370, CCW HX 3B lOW OUTLET ISOL. IV CAUTION Placing a COW HX in service will cause CVCS Letdown line temperature to drop, resulting in a rise in Tavg and Reactor Power. L. NOTIFY Control Room that the following step will cause CVCS Letdown line temperature to drop, resulting in a rise in Tavg and Reactor Power. M. OPEN 3-712B, COW HEAT EXCHANGER 3B INLET ISOL VALVE. IV

4. NOTIFY Control Room that the 3B CCW HX is restored to service.

5. IF non-operating CCW Pumps were placed in PULL-TO-LOCK due to the COW HX being removed from service, THEN PLACE non-operating COW Pumps in AUTO.

IV

6. ENSURE COW Pumps are restored to current plant requirements.

7. IF throttled per 3-NOP-019 with one lOW/COW HX OOS, THEN:

A. ENSURE the following are LOCKED OPEN: 3-50-380, COW HX 3A lOW OUTLET ISOL IV

3-50-382, OUTLET VLV FOR lOW DISCH FROM OCW HXC IV

                 -   PROCEDURE TITLE:                                 PAGE:

COMPONENT COOLING WATER SYSTEM 79 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.19 Restoring 3B CCW HX to Service (continued)

7. (continued)

B. ENSURE the following are OPEN: e 3-50-831A, OUTLET ISOL VALVE TPCW HX A ICW sys e 3-50-831 B, ICW TO TPCW B HX OUTLET ISOL c 3-50-8310, lOW TO TPCW C HX OUTLET ISOL

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 80 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.20 Restoring 3C CCW HX to Service INITIAL CHECK ECO for 30 CCW HX is released.

2. ENSURE an operator is in continuous communication with Control Room and is available to adjust COW flow to the NRHX to maintain VCT temperature between 115 and 120°F.

CAUTION Restoring a COW HX to service will cause OVOS Letdown line temperature to drop, resulting in a rise in Tave and Reactor Power.

3. RESTORE 30 COW HX to Service:

A. REQUEST that Chemistry determine if the COW fluid can be vented to a floor drain, or if it needs to be collected in a suitable storage container. B. NOTIFY Control Room that the 30 COW HX is being restored to service. C. INFORM RO of potential reactivity changes. D. CLOSE 3-50-357, COW HX 30 lOW OUTLET PX-1472 ROOT. IV E. CLOSE 3-50-354, COW HX 30 lOW TUBESIDE DRN. IV F. CHECK areas between the COW HX vent valves and the floor drains are clear of electrical or other sensitive equipment. G. OPEN 3-50-351, lOW TO COW HX 30 INLET ISOL. 1V H. VENT 3000W HX from 3-50-355, COW TO HX 30 lOW TUBESIDE VENT. I. ENSURE 3-50-355, COW TO HX 30 lOW TUBESIDE VENT is CLOSED. IV

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 81 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.20 Restoring 3C CCW HX to Service (continued) INITIAL

3. (continued)

J. UNLOCK and OPEN 3-50-382, OUTLET VLV FOR ICW DISCH FROM CCW HX 3C. K. LOCK OPEN 3-50-382, OUTLET VLV FOR ICW DISCH FROM COW HX 30. lv CAUTION Placing a COW HX in service will cause CVCS Letdown line temperature to drop, resulting in a rise in Tavg and Reactor Power. L. NOTIFY Control Room that the following step will cause CVCS Letdown line temperature to drop, resulting in a rise in Tavg and Reactor Power. M. OPEN 3-7120, COW HEAT EXCHANGER 30 INLET ISOL VALVE. IV

4. NOTIFY Control Room that the 30 COW HX is restored to service.

5. IF non-operating COW Pumps were placed in PULL-TO-LOCK due to the COW HX being removed from service, THEN PLACE non-operating COW Pumps in AUTO.

IV

6. ENSURE COW Pumps are restored to current plant requirements.

7. IF throttled per 3-NOP-019 with one lOW/COW HX OOS, THEN:

A. ENSURE the following are LOCKED OPEN:

3-50-380, COW HX 3A lOW OUTLET ISOL IV
3-50-370, COW HX 3B lOW OUTLET ISOL IV

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 82 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.20 Restoring 3C CCW HX to Service (continued)

7. (continued)

B. ENSURE the following are OPEN: o 3-50-831A, OUTLET ISOL VALVE TPCW HX A lOW SYS o 3-50-831 B, lOW TO TPCW B HX OUTLET ISOL 3-50-8310, lOW TO TPCW C HX OUTLET ISOL

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 83 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.21 Filling CCW HeadlSurge Tank INITIAL IF using MOV-3-832, PRIMARY WATER MAKEUP TO CCW SURGE TANK, to fill Head/Surge Tank, THEN: A. OPEN MOV-3-832, PRIMARY WATER MAKEUP TO COW SURGE TANK. B. WHEN COW Head Tank Level is between 10 and 85%, THEN CLOSE MOV-3-832, PRIMARY WATER MAKEUP TO COW SURGE TANK. lv

2. IF bypassing MOV-3-832, PRIMARY WATER MAKEUP TO COW SURGE TANK, to fill Head/Surge Tank, THEN:

A. ENSURE CLOSED 3-821, DEMIN WATER TO SFP. B. CLOSE 3-10-534, WTP TO SFP MAKEUP ISOLATION VALVE. C. OPEN 3-10-535, PMWTO SFP MAKEUP ISOLATION VALVE.

0. MONITOR the following on VPB during performance of filling Head/Surge Tank:

0 LI-3-614A, LEVEL IND FOR COW HEAD TANK o Ll-3-651, SFP LEVEL E. FILL Head/Surge Tank: (1) IF filling through PCV-3-832, PRIMARY WTR PRESSURE CONTROL VLV TO COW SURGE TANK, THEN ENSURE:

a. 3-71 1A, COW HDR A MAKEUP WATER ISOL is CLOSED.

b. 3-7370, CCW SYSTEM DEMIN WATER/

PRIMARY WATER SUPPLY TIE is OPEN.

c. 3-715, INLET ISOLATION VLV FOR POV-3-832 is OPEN.

REtON NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 84 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.21 Filling CCW Head/Surge Tank (continued) INITIAL

2. E. (1) (continued)

d. 3-711 B, COW HDR B MAKEUP WATER ISOL is OPEN.

(2) IF bypassing PCV-3-832, PRIMARY WTR PRESSURE CONTROL VLV TO CCW SURGE TANK, THEN OPEN 3-711A, CCWHDRAMAKEUP WATER ISOL. (3) While monitoring LI-3-614A, LEVEL IND FOR COW HEAD TANK, THROTTLE OPEN, 3-724D, COW SYSTEM DEMIN WATER SUPPLY. (4) WHEN COW Head Tank Level is between 10 and 85%, THEN CLOSE 3-724D, COW SYSTEM DEMIN WATER SUPPLY. IV F. RESTORE from filling Head/Surge Tank: (1) ENSURE CLOSED 3-71 IA, COW HDR A MAKEUP WATER ISOL. IV (2) CLOSE 3-10-535, PMWTO SFP MAKEUP ISOLATION VALVE. IV (3) OPEN 3-10-534, WTP TO SFP MAKEUP ISOLATION VALVE. IV

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 85 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 5.22 Void Response

1. IF 3A COW pump is required to be vented, THEN VENT 3A COW PUMP casing from 3-703F, CCW PUMP A CASING VENT.

2. ENSURE 3-703F, CCW PUMP A CASING VENT, is CLOSED.

3. IF 3B CCW pump is required to be vented, THEN VENT 3B CCW PUMP casing from 3-703G, COW PUMP B CASING VENT.

4. ENSURE 3-703G, COW PUMP B CASING VENT, is CLOSED.

5. IF 3C CCW pump is required to be vented, THEN VENT 3C COW PUMP casing from 3-703H, CCW PUMP C CASING VENT.

6. ENSURE 3-703H, COW PUMP C CASING VENT, is CLOSED.

7. IF additional venting is required, THEN NOTIFY the System Engineer.

REV1SIOrNO.: PROCEDURETITLE: - - - - COMPONENT COOLING WATER SYSTEM 86 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 6.0 RECORDS

1. The date, time, and section completed shall be entered in the Unit Narrative Log.

2. Problems encountered while performing the procedure (i.e. malfunctioning equipment, delays due to change in plant conditions, etc.) should be entered in the Unit Narrative Log.

3. Completed copies of the following shall be retained in the Shift Managers file until the next performance of the alignment:

Attachment 1, Component Cooling Water Valve Alignment
Attachment 2, Component Cooling Water System Control Switch Alignment o Attachment 3, Component Cooling Water System Breaker Alignment

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 87 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 7M REFERENCES AND COMMITMENTS 7.1 References 7.1.1 Implementing

1. O-OP-061 .13, Waste Disposal System Transferring Water To The Portable Demineralizer

2. O-ADM-033, PTN Industrial Safety Program

3. O-ADM-717, Heavy Load Handling

4. 3-GOP-301, Hot Standby To Power Operation

5. 3-OP-019, Intake Cooling Water System

6. 3-OP-055, Emergency Containment Cooling and Filter Systems.

7. 3-NOP-300, Alternate Shutdown Panel

8. 3-OP-050, Residual Heat Removal System

9. 3-OSP-030.1, Component Cooling Water Pump Inservice Test

10. 3-OSP-030.5, Component Cooling Water Pumps Low Header Pressure Start Test

11. 3-OSP-030.7, CCW Manual Valve Operability Test (Outage)

12. 3-OSP-030.9, Component Cooling Water Flow Balance

13. 3-OSP-053.4, Containment Integrity Penetration Alignment Verification 7.1.2 Developmental

1. Technical Specification Section 3.7.2, Component Cooling Water System

2. UFSAR Sections 6.2.2, 6.5.1 and 9.3

3. Design Basis Document Volume 11 for Component Cooling Water System

4. Basis Document for *op.3o Component Cooling Water System

REVFSON NO. POCEDUE TItLE: - PAGE: COMPONENT COOLING WATER SYSTEM 88 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 7.1.2 Developmental (continued)

5. Plant Drawings 5613-M-3030 Sheets I through 5, Component Cooling Water System

6. 0-ADM-114, Standardization of Acronyms and Abbreviations

7. 0-ADM-717, Heavy Load Handling

8. Miscellaneous:

A. Westinghouse Letter FPL-86-726 (dated 7/29/86), CCW Heat Exchanger Shell Side Flow B. FPL Letter, JPE-PTPO-86-1637, E. Preast to J.A. Labarraque, (Dated 10/24/86), CCW Hx Shell Side Flow Limit C. Worthington Corp Vendor Manual, V000266, John Crane Mechanical Seal, Vendor Drawing F-SP-1 2383 D. JPN-PTN-SEMJ-94-001, Non Regen Heat Exchanger Shell Side Flow Limits (CR 93-1 034) E. JPN-PTN-SENJ-90-1 14, CCW Split Header Configuration Operability Assessment, Rev 2 (Superseded by J PN-PTN-SEN P-95-026) F. Westinghouse Vendor Manual V000479, Model V-i 1001 -BI, Controlled Seal Leakage Reactor Coolant Pump G. JPN-PTN-SENP-95-026, Safety Evaluation for CCW Flow Balance and Post Accident Alignment Requirements to Support Current and Uprated Conditions (LER 250/95-006) H. CR 93-938, Vibration of ECC Bypass Throttle Valves I. JPN-PTN-SEMS-93-044, ECC Bypass CCW Flow J. CR 96-643, 4B RCP Motor Lower Oil Level Alarms K. PLS Document Section 4 L. JPN-PTN-SENP-95-007, Rev. 4, Safety Evaluation for Operability of RHR During Integrated Safeguards Testing M. CR 01-2156, 3-OP-055, Section 7.1, 7.2, and 7.3 Were Changed Incorrectly

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 89 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 7.1.2 Developmental (continued)

8. (continued)

N. CR 2005-1 5034, Water Hammer Condition Following a CCW Pump Start on a Stagnant CCW Header

0. ERT-87-003, High Chloride Concentrations in Unit 3 and 4 Component Cooling Water System, dated 11/30/87 (CTRAC Number 87-1639-34)

P. JPN-PTN-SENP-95-026, Safety Evaluation for CCW Flow Balance and Post Accident Alignment Requirements to Support Current and Uprated Conditions (LER 250/95-006) (This JPN supersedes QAO-PTN-87-512, Comment Regarding Coolant Loop CCW Hx Requirement Definitions) Q. Non-Conformance Report 587-86, Use of Boric Acid Evaporator.

9. Plant Modifications:

A. PC/M 83-08, CCW/HHSI Flow Reversal B. PC/M 85-1 37, Appendix R Valve Hand Operator Addition C. PC/M 86-1 62, Removal of CCW Piping to the Primary Shield Coolers D. PC/M 89-215, Drawing Discrepancies on P&lD 5610-M-10, Sheet 1 and 5610-M-450-57, Sheet 3 E. PC/M 89-219, Drawing Update to P&ID 5610-M-450-57, Sheets 6 and 7, CCW System (30) F. PC/M 87-025, Replacement of Normal Containment Coolers G. PC/M 88-077, RHR Pumps Mechanical Seals and Seal Cooler Replacement. H. PC/M 89-581, Containment Isolation Features Design Basis Implementation (Tech Spec 3.6) I. PC/M 91-064, Changing Pump Service Water Connections J. PC/M 87-258, Load Center 3H & Re-powering of MCC D (3D)

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 90 of 131 PROCEDURE NO.: 3-NO P-030 TURKEY POINT UNIT 3 7.1.2 Developmental (continued)

9. (continued)

K. PC/M 87-265, Swing Switchgear 3D and Transfer of 10W and CCW 30 Pumps L. PC/M 93-034, CCW System Reconfiguration to HHSI Pumps Seal/Thrust Bearing Coolers M. PC/M 94-062, CCW Surge Tank Level Transmitter Replacement N. PC/M 95-054, Temporary Containment Cooling During Refueling Outages

0. PC/M 96-039, Spring/Setpoint Change for the Pilot Operated Lockup Vlvs for the ECC COW Supply/Return Isolation Valves P. PC/M 94-141, Boric Acid Evaporators and Gas Strippers Abandonment Q. PC/M 96-092, Addition of U-3 COW Head Tank R. PC/M 00-016, ORN M-10471, COW Surge Tank Level

                   -   Indicator Replacement S. PC/M 04-026, Appendix R and Safe Shutdown changes and MOV-3-71 6A de-energized.

T. PC/M 03-053, CCW Pump Split Type Mechanical Seal U. PC/M 06-1 03, Component Cooling Water TCV-3-144 Replacement 7.1.3 Management Directives None 7.2 Commitments None

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 91 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 1 of 30) EXCEPTIONS COMPONENT COMPONENT DESCRIPTION REMARKS PERSONNEL PERFORMING MANIPULATIONS PRINTED NAME INITIALS COMPLETION OF LINEUP DATE LINEUP (MMIDD/YY): TIME LINEUP (HH:MM, 24 HR CLOCK): COMPLETED: ,i ,i COMPLETED: LINEUP PRINTED NAME I SIGNATURE: COMPLETED BY: REVIEW OF LINEUP LINEUP REVIEWED PRINTED NAME I SIGNATURE: DATE: (MMIDDIYY): BY:

REV1S1O11NO.: - PROCEDUtItL: PAGE: COMPONENT COOLING WATER SYSTEM 92 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 2 of 30) NOTE Completion of this attachment fulfills the requirements as designated in 3-OSP-053.4, Containment Integrity Penetration Alignment Verification for Closed System checks. COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY INSIDE CONTAINMENT EM ERG CONT CLR A CCW 3-10-704 INLET PRESSURE ROOT VLV OPEN TO P1-3-1544 EMERG CONT CLR A CCW CLOSED & 3-10-283 INLET VENT CAPPED EMERG CONT CLR A CCW CLOSED & 3-10-285 OUTLET DRAIN CAPPED EMERG CONT CLR A CCW 3-10-705 OUTLET PRESSURE ROOT OPEN VLV TO P1-3-1545 ECC A RETURN TO CCW HDR CLOSED & 3-1 0-748 VENT VALVE CAPPED EMERG CONT CLR B CCW 3-10-700 INLET PRESSURE ROOT VLV OPEN TO P1-3-I 540 EMERG CONT CLR B CCW CLOSED & 3-10-282 INLET VENT CAPPED EMERG CONT CLR B CCW CLOSED & 3-10-286 OUTLET DRAIN CAPPED

          .       EMERG CONT CLR B CCW 3-10-701       OUTLET PRESSURE ROOT                      OPEN VLVTO P1-3-1541 ECC B RETURN TO CCW HDR                 CLOSED &

3-1 0-690 VENT VALVE CAPPED EMERG CONT CLR C CCW CLOSED & 3-10-284 INLET VENT CAPPED EMERG CONT CLR C CCW 3-10-702 INLET PRESSURE ROOT VLV OPEN TO P1-3-i 542

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 93 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Comnonent Cooling Water Valve Alignment (Page 3 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY EM ERG CONT. CLR C CCW CLOSED & 3-10-287 OUTLET DRAIN CAPPED EM ERG CONT CLR C CCW 3-10-703 OUTLET PRESSURE ROOT OPEN VLVTO P1-3-I 543 RCPS CCW SUPPLY HDR CLOSED & 3-716E TEST CONNECTION CAPPED RCP A OIL CLRS & THERMAL 3-718A OPEN BARRIER CCW SUPPLY RCP A UPPER BEARING CLR 3-719A OPEN CCW SUPPLY RCP A UPPER BEARING CLR 3-724A THROTTLED CCW OUTLET RCP A LOWER BEARING CLR 3-720A OPEN CCW SUPPLY RCP A LOWER BEARING CLR 3-723A THROTTLED CCW OUTLET RCP A THERMAL BARRIER 3-728A THROTTLED CCW OUTLET RCP B OIL CLRS & THERMAL 3-718B OPEN BARRIER CCW SUPPLY RCP B UPPER BEARING CLR 3-719B OPEN CCW SUPPLY RCP B UPPER BEARING CLR 3-7248 THROTTLED CCW OUTLET RCP B LOWER BEARING CLR 3-720B OPEN CCW SUPPLY RCP B LOWER BEARING CLR 3-723B THROTTLED CCW OUTLET RCP B THERMAL BARRIER 3-7288 THROTTLED CCW OUTLET RCP C OIL CLRS & THERMAL 3-718C OPEN BARRIER CCW SUPPLY RCP C UPPER BEARING CLR 3-719C OPEN CCW SUPPLY RCP C UPPER BEARING CLR 3-724C THROTTLED CCW OUTLET

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 94 of 131 PROCEDURE NO.: 3-NO P-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 4 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY RCP C LOWER BEARING CLR 3-7200 OPEN CCW SUPPLY RCP C LOWER BEARING CLR 3-7230 THROTTLED COW OUTLET RCP C THERMAL BARRIER 3-7280 THROTTLED COW OUTLET ROP A COW OUTLET HDR 3-725A FLOW ROOT VALVE TO OPEN Fl 0-3-629 RCP A COW OUTLET HDR 3-726A FLOW ROOT VALVE TO OPEN FIC-3-629 RCP A COW OUTLET HDR 3-727A OPEN ISO LATI 0 N RCP B COW OUTLET HDR 3-725B FLOW ROOT VALVE TO OPEN Fl 0-3-632 ROP B COW OUTLET HDR 3-726B FLOW ROOT VALVE TO OPEN Fl 0-3-632 RCP B COW OUTLET HDR 3-727B OPEN ISO LATI 0 N ROP C COW OUTLET HDR 3-7250 FLOW ROOT VALVE TO OPEN Fl 0-3-635 ROP C COW OUTLET HDR 3-7260 FLOW ROOT VALVE TO OPEN Fl 0-3-635 RCP C COW OUTLET HDR 3-7270 OPEN ISO LATI 0 N RCPS COW OUTLET HDR CLOSED & 3-730A TEST CONNECTION CAPPED NORM CONT CLR A COW 3-10-654 OPEN ILET NORM CONT CLR A COW 3-10-706 INLET PRESSURE ROOT OPEN VALVE TO P1-3-i 546

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 95 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 5 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY NORM CONT CLR A COW CLOSED & 3-1 0-053 INLET VENT CAPPED NORM CONT CLR A COW 3-10-707 OUTLET PRESSURE ROOT OPEN VALVE TO P1-3-1547 NORM CONT CLR A COW 3-1 0-707A OUTLET I NSTRUMENT VALVE OPEN TO P1-3-I 547 NORM CONT CLR A COW 3-1 0-708 OUTLET FLOW ROOT VALVE OPEN TO FI-3-1444 NORM CONT CLR A COW CLOSED & 3-10-681 OUTLET FE VENT UPSTREAM OF 3-10-708 CAPPED NORM CONT CLR A COW 3-1 0-709 OUTLET FLOW ROOT VALVE OPEN TO FI-3-1444 NORM CONT CLR A COW 3-10-682 CLOSED & OUTLET FE VENT UPSTREAM CAPPED OF 3-10-709 NORM CONT OLR A COW 3-1 0-655 THROTTLED OUTLET NORM CONT CLR B COW 3-10-656 OPEN I N LET NORM CONT CLR B COW 3-10-710 INLET PRESSURE ROOT OPEN VALVE TO P1-3-1548 NORM CONT OLR B COW 3-10-711 OUTLET PRESSURE ROOT OPEN VALVE TO P1-3-1549 NORM CONTCLR B COW 3-10-71 IA OUTLET INSTRUMENT VALVE OPEN TO P1-3-1 549 NORM CONT OLR B COW CLOSED & 3-10-683 OUTLET FE VENT UPSTREAM CAPPED OF 3-10-712

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 96 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 6 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY NORM CONT CLR B COW 3-10-712 OUTLET FLOW ROOT VALVE OPEN TO FI-3-1445 NORM CONT CLR B COW CLOSED & 3-10-684 OUTLET FE VENT UPSTREAM CAPPED OF 3-10-713 NORM CONT CLR B COW 3-10-713 OUTLET FLOW ROOT VALVE OPEN TO FI-3-1445 NORM CONT CLR B COW OPEN OR 3-1 0-657 OUTLET THROTTLED 3-10-662 ROD DRIVE CLR A CCW INLET OPEN ROD DRIVE CLR A COW INLET 3-10-722 PRESSURE ROOT VLV TO OPEN P1-3-1574 ROD DRIVE CLR A COW INLET CLOSED & 3-1 0-695 VENT CAPPED ROD DRIVE CLR A CCW 3-10-723 OUTLET PRESSURE ROOT OPEN VLVTO P1-3-1575 ROD DRIVE CLR A CCW 3-1 0-724 OUTLET FLOW ROOT VLV TO OPEN FI-3-1 448 ROD DRIVE CLR A COW 3-10-725 OUTLET FLOW ROOT VLV TO OPEN FI-3-1448 ROD DRIVE CLR A COW OPEN OR 3-1 0-663 OUTLET THROTTLED NORM CONT CLR D COW 3-10-658 OPEN INLET NORM CONT OLR D COW 3-10-714 INLET PRESSURE ROOT OPEN VALVE TO P1-3-I 550 NORM CONT CLR D COW 3-10-715 OUTLET PRESSURE ROOT OPEN VALVE TO P1-3-1551

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 97 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 7 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY NORM CONT CLR D COW 3-10-716 OUTLET FLOW ROOT VALVE OPEN TO FI-3-1446 NORM CONT CLR D COW 3-10-717 OUTLET FLOW ROOT VALVE OPEN TO FI-3-1446 COW RETURN HDR FROM CLOSED & 3 i 0749 NCCS AND CRDMS VENT CAPPED NORM CONT CLR D COW OPEN OR 3 10 659 OUTLET THROTTLED 3-10-664 ROD DRIVE CLR B COW INLET OPEN ROD DRIVE CLR B COW INLET 3-10-726 PRESSURE ROOT VLVTO P1- OPEN 3-1576 ROD DRIVE CLR B COW INLET CLOSED & 3 10 694

         -     VENT                                  CAPPED ROD DRIVE CLR B COW 3-10-727    OUTLET PRESSURE ROOT                   OPEN VLVTO P1-3-1577 ROD DRIVE CLR B COW 3-10-728    OUTLET                                 OPEN FLOW ROOT VLV TO FI-3-1449 ROD DRIVE OLR B COW 3-10-729    OUTLET                                 OPEN FLOW ROOT VLV TO FI-3-1 449 ROD DRIVE CLR B COW                   OPEN OR 3 1 0- 665 OUTLET                              THROTTLED NORM CONT CLR C COW 3 10 660                                           OPEN INLET NORM CONT OLR C COW 3-10-718   INLET PRESSURE ROOT                    OPEN VALVE TO P1-3-1552 NORM CONT CLR C COW 3-10-719   OUTLET PRESSURE ROOT                   OPEN VALVE TO P1-3-i 553

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 98 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 8 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY NORM CONT CLR C CCW 3-1 0-685 OUTLET FE VENT CLOSED & DOWNSTREAM OF 3-10-720 CAPPED NORM CONT CLR C CCW 3-1 0-720 OUTLET FLOW ROOT VALVE OPEN TO FI-3-l 447 NORM CONT CLR C CCW CLOSED & 3-10-686 OUTLET FE VENT CAPPED DOWNSTREAM OF 3-10-721 NORM CONT CLR C CCW 3-10-721 OUTLET FLOW ROOT VALVE OPEN TO Fl-3-1447 NORM CONT CLR C CCW OPEN OR 3-1 0-661 OUTLET THROTTLED PEN 12 TEST CONN VLV ON CLOSED & 3-737 H CCW LINE DOWNSTREAM OF CAPPED CHECK VLV 3-738 EXCESS LETDOWN HX CCW CLOSED & 3-626C INLET HDR DRAIN CAP P ED EXCESS LETDOWN HX CCW CLOSED & 3-737J OUTLET HDR VENT CAPPED PEN 13 TEST CONN VLV ON CLOSED & 3-739A CCW LINE DOWNSTREAM OF EXCESS LETDOWN HX CAPPED OUTSIDE CONTAINMENT 3-701A CCW PUMP A INLET OPEN CLOSED & 3-701M CCWPUMPAINLETTEST CAPPED CCW PUMP A SUCTION 3-701D PRESSURE ROOT VLV TO OPEN P1-3-i 095A & IST-3-40 3-703F CCW PUMP A CASING VENT CLOSED CCW PUMP A INBD MECH 3-1482 OPEN SEAL COOLANT SUPPLY

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 99 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 9 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY CCW PUMP A OTBD MECH 3-1483 OPEN SEAL COOLANT SUPPLY CCW PUMP A DISCONNECTED 3-703J SAMPLE WATER SUPPLY CLOSED ROOT VALVE CCW PUMP A DISCONNECTED 3-703K CLOSED SAMPLE WATER SUPPLY 3-701P PI-3-IO95AISOL OPEN 3-701R IST-3-40 ISOL CLOSED 3-1012 IST-3-40 VENT CLOSED CCW PUMP A DISCHARGE CLOSED & 3-702D DRAIN CAPPED CCW PUMP A DISCHARGE 3-704A PRESSURE ROOT VLV TO P1- OPEN 3-640A & IST-3-45 3-704E PI-3-640A ISOL OPEN 3-704F IST-3-45 ISOL CLOSED 3-1011 IST-3-45 VENT VLV CLOSED 3-703A CCW PUMP A DISCHARGE OPEN CCW PUMP SUCTION HDR 3-787A OPEN SECTIONALIZI NG 3-71CC P1-3-1097 ISOL OPEN CCW PUMP SUCTION CROSS- CLOSED & 3-701H TIE HDR VENT CAPPED TEMPORARY DEMINERALIZER 3-1184 CLOSED RETURN ISOL CCW PUMP B INLET HDR 3 701J CLOSED VENT 3-701B CCWPUMPBINLET OPEN

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 100 of 131 PROCEDURE NO.: 3-NO P-030 TURKEY POINT UNIT 3 ATTACHMENT I ComDonent Cooling Water Valve Alignment (Page 10 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY 3-701 N CCW PUMP B INLET TEST CLOSED & CAPPED CCW PUMP B SUCTION 3-701E PRESSURE ROOT VLVTO P1- OPEN 3-1095B & IST-3-42 3-701T P1-3-I 095B ISOL OPEN 3-701V IST-3-42 ISOL CLOSED 3-703G CCW PUMP B CASING VENT CLOSED CCW PUMP B INBD MECH 3-1484 CLOSED SEAL COOLANT SUPPLY CCWPUMPBOTBDMECH 3-1485 CLOSED SEAL COOLANT SUPPLY CCW PUMP B DISCONNECTED 3-703L CLOSED SAMPLE WATER SUPPLY CCW PUMP B DISCONNECTED 3-703M CLOSED SAMPLE WATER SUPPLY CCW PUMP B DISCHARGE CLOSED & 3-702E DRAIN CAPPED CCW PUMP B DISCHARGE 3-704B PRESSURE ROOT VLV TO OPEN PI-3-640B & IST-3-34 3-704G PI-3-640B ISOL OPEN 3-704H IST-3-34 ISOL CLOSED 3-703B CCW PUMP B DISCHARGE OPEN CCW PUMP B DISCHARGE CLOSED & 3-703D HDR VENT CAPPED CCW PUMP SUCTION HDR 3-787B OPEN SECTIONALIZING 3-701C CCW PUMP C INLET OPEN CCW PUMP C SUCTION 3-701F PRESSURE ROOT VLV TO OPEN P1-3-I 095C & IST-3-30

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 101 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 1 1 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY 3-701X P1-3-I 095C ISOL OPEN 3-701Y IST-3-30 ISOL CLOSED 3-703H CCW PUMP C CASING VENT CLOSED CCWPUMPCINBDMECH 3-1486 OPEN SEAL COOLANT SUPPLY CCWPUMPCOTBDMECH 3-1487 OPEN SEAL COOLANT SUPPLY CCW PUMP C DISCONNECTED 3-703N CLOSED SAMPLE WATER SUPPLY CCW PUMP C DISCONNECTED 3-703P SAMPLE WATER SUPPLY CLOSED ROOT VALVE CCW PUMP C DISCHARGE CLOSED & 3-702F DRAIN CAPPED CCW PUMP C DISCHARGE 3-704C PRESSURE ROOT VLV TO OPEN PI-3-640C & IST-3-35 3-704J P1-3-64CC ISOL OPEN 3-704K 3C CCW PP IST-3-35 RT CLOSED 3-703C CCW PUMP C DISCHARGE OPEN CCW PUMP C DISCHARGE CLOSED & 3-703E HDR VENT CAPPED CCW SUCTION HDR 3-701L PRESSURE ROOT VLVTO OPEN P1-3-1096 3-712A CCW HX A INLET LINE OPEN CCW HX A INLET PRESSURE 3-733D OPEN ROOT VLV TO PI-3-644A CCW HX A INLET PRESSURE [SOL VLV TO PI-3-644A OPEN 3-712D CCW HX A SHELL DRAIN CLOSED & CAPPED

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 102 Of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Corn ponent Cooling Water Valve Alignment (Page 12 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY CCW HX A SHELL DRAIN CLOSED & 3-713D CAPPED CCW HX A OUTLET HDR VENT CLOSED & 3-713G CAPPED CCW HX A OUTLET 3-733A PRESSURE ROOT VLV TO OPEN P1-3-644 B CCW HX A OUTLET 3-733M PRESSURE ISOL VLV TO OPEN P1-3-644 B CCW HEAT EXCHANGER A 3-713A OPEN OUTLET CCW PUMP DISCHARGE 3-787C OPEN SECTIONALIZI NG CHEM POT FEEDER COW 3705 OPEN SUPPLY CCW DISCHARGE HDR 3-704D PRESSURE ROOT VLV TO OPEN P1-3-612 & P0-3-611 3-701G P0-3-611 ISOL OPEN 3-701K P1-3-612 ISOL OPEN 3-712B COW HX B INLET OPEN COW HX B INLET PRESSURE 3-733E OPEN ROOT VLV TO P1-3-6440 COW HX B INLET PRESSURE 3-733K OPEN ISOL VLV TO P1-3-6440 CLOSED& 3-712E CCW HX B SHELL DRAIN CAPPED CLOSED & 3-713E 00W HX B SHELL DRAIN CAPPED CCW HX B OUTLET HDR TEST CLOSED & 3-713H CONNECTION CAPPED CCW HX B OUTLET 3-733B PRESSURE ROOT VLV TO P1- OPEN 3-644D

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 103 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 13 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY COW HX B OUTLET 3-733G PRESSURE ISOLVLVTO OPEN P1-3-644 D 3-713B CCW HX B OUTLET OPEN COW PUMP DISCHARGE 3-787D OPEN SECTIONALIZING 3-7120 CCWHXCINLET OPEN COW HX C INLET PRESSURE 3-733F OPEN ROOT VLV TO PI-3-644E COW HX C INLET PRESSURE 3-733L OPEN ISOL VLV TO PI-3-644E CLOSED & 3-712F COW HX C SHELL DRAIN CAPPED 3-713F COW HX C SHELL DRAIN CLOSED COW HX C OUTLET HDR TEST CLOSED & 3 713J CONNECTION CAPPED COW HX C OUTLET 3-7330 PRESSURE ROOT VLV TO P1- OPEN 3-644F CCW HX C OUTLET 3-733H PRESSURE ISOL VLV TO OPEN PI-3-644F 3-713C CCW HX C OUTLET OPEN COW HDR B SUPPLY TO CHARGING PUMPS, SPENT 3-835E OPEN FUEL PIT HX, NON-REGEN HX, AND SEAL WATER HX CCW HDR B FLOW ROOT VLV 3-7140 OPEN TO FT-3-613B COW HDR B FLOW ROOT VLV 3-714D OPEN TO FT-3-613B CLOSED & 3-7090 COW HDR B VENT CAPPED

RViSIOFJiid.: OI3URE TITLE: - PAGE: 9 COMPONENT COOLING WATER SYSTEM 104 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 14 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY COW HX OUTLET HDR 3-787H OPEN SECTIONALIZI NG CCW HX OUTLET HDR 3-787G OPEN SECTIONALIZING 3-709B CCW HDR A B VENT CLOSED & CAPPED CCW HX OUTLET HDR 3-787F OPEN SECTIONALIZING CCW HX OUTLET HDR 3-787E OPEN SECTIONALIZING 3-709A CCW HDR A VENT CLOSED & CAPPED CCW HDR A FLOW ROOT VLV 3-714A OPEN TO FT-3-613A CCW HDR A FLOW ROOT VLV 3-714B OPEN TO FT-3-61 3A CCW HDR B RETURN FROM CHARGING PUMPS, SPENT 3-835H OPEN FUEL PIT HX, NON-REGEN HX, AND SEAL WATER HX CCW HDR A RETURN FROM CHARGING PUMPS, SPENT 3-835G CLOSED FUEL PIT HX, NON-REGEN HX, AND SEAL WATER HX COW SYSTEM DEMIN WATER 3-724D CLOSED SUPPLY CCW SYSTEM DEMIN WATER 3-737C OPEN PRIMARY WATER SUPPLY TIE CCW HDR A MAKEUP WATER 3-71 IA CLOSED ISOL COW HDR B MAKEUP WATER 3-711B OPEN ISOL TEMPORARY DEMINERALIZER CLOSED & 3-1173 SUPPLY ISOL CAPPED CCW HDR A SURGE TANK LOCKED 3-710A ISOL OPEN CCW HDR B SURGE TANK LOCKED 3-710B ISOL OPEN

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 105 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 15 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY CHEM POT FEEDER OUTLET 3-705H OPEN TO CCWHDRA CHEM POT FEEDER OUTLET 3-705G CLOSED TO CCWHDRA CHEM POT FEEDER OUTLET 3 - OPEN T000WHDRB CHEM POT FEEDER OUTLET 3-705K CLOSED TOCCWHDRB CHEM POT FEEDER COW 3-705N CLOSED SUPPLY 3-705M CHEM POT FEEDER VENT CLOSED OHEM POT FEEDER 3-746G CLOSED CHEMICAL FILL 3-705L CHEM POT FEEDER DRAIN CLOSED RCV-3-609 COW HEAD TANK VENT OPEN COW HEAD TANK OVERFLOW 3 1021

       -                                               CLOSED LINE DRAIN VALVE COW SURGE TANK LEVEL 3-708A                                             OPEN ROOT VLV TO LT-3-61 3 COW SURGE TANK LEVEL 3-708B                                             OPEN ROOT VLV TO LT-3-61 3 COW SURGE TANK LEVEL 3-7080                                             OPEN ROOT VLV TO LI-3-61 5 CCW SURGE TANK LEVEL 3-708D                                             OPEN ROOT VLV TO LI-3-615 COW SURGE TANK LOCAL                   CLOSED &

3-709 SAMPLE ISOL CAPPED ISOL VLV FOR LT-3-61 3 COW 3-2017 OPEN SURGE TANK OLD CHEM POT FEEDER COW 3-705A CLOSED S U P PLY OLD CCW SYSTEM DEMIN 3-705B CLOSED WATER SUPPLY OLD CHEM POT FEEDER TO 3-7050 CLOSED OCW SURGE TANK ISOL

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 106 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 16 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY OLD CHEM POT FEEDER 3-705D CLOSED OUTLET TO CCW HDR A OLD COW SYSTEM DEMIN 3-705E CLOSED WATER SUPPLY OLD CHEM POT FEEDER 3-705F CLOSED OUTLET TO COW HDR B COW HDR A SUPPLY TO CHARGING PUMPS, SPENT 3-835F CLOSED FUEL PIT HX, NON-REGEN HX, AND SEAL WATER HX PCV-3-832 INLET ISOLATION 3 715 OPEN VLV PRIMARY WTR PRESSURE PCV-3-832 CONTROL VLV TO COW OPEN SURGE TANK P1-3-I 094 COW MAKEUP LINE 3 722 OPEN ROOT VLV ROOT VALVE FOR LI-3-616 3-1014 OPEN OFF COW HEAD TANK ROOT VALVE FOR LI-3-616 3-1015 OPEN OFF COW HEAD TANK COW HEAD TANK VENT/CHEM 3-1016 CLOSED ADDITION VALVE ROOT VALVE FOR LT-3-614 3-1017 OPEN OFF COW HEAD TANK COW HEAD TANK SAMPLE 3-1 018 CLOSED VALVE ROOT VALVE FOR LT-3-614 3-1022 OPEN OFF COW HEAD TANK

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 107 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I ComDonent Cooling Water Valve Alignment (Page 17 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY NOTE I: Valve positions are the expected positions when BOTH Units are in Modes 1 through 4. LOCKED UNIT3CCWHDRBSUPPLY OPEN TO 5.1. PUMPS (NOTE 1) LOCKED UNIT4CCWHDRBSUPPLY CLOSED TO SI. PUMPS (NOTE 1) LOCKED UNIT3CCWHDRASUPPLY 3-708G CLOSED TO S.I. PUMPS (NOTE 1) LOCKED UNIT4CCWHDRASUPPLY 4-708G OPEN TO SI. PUMPS (NOTEI) CCW HDR B SUPPLY TO SI OPEN 838B (NOTE 1) PUMP 3A LOCKED CCW HDR A SUPPLY TO SI 838D CLOSED PUMP 3A (Green Series Key) (NOTE 1) CCW HDR B SUPPLY TO SI OPEN 838F (NOTE 1) PUMP 3B LOCKED CCWHDRASUPPLYTOSI 838H CLOSED PUMP 3B (Green Series Key) (NOTE 1) CCW HDR B SUPPLY TO SI LOCKED 838K CLOSED PUMP 4A (Green Series Key) (NOTE 1) CCW HDR A SUPPLY TO SI OPEN 838M (NOTEI) PUMP4A CCW HDR B SUPPLY TO SI LOCKED 838P CLOSED PUMP 4B (Green Series Key) (NOTE 1) CCW HDR A SUPPLY TO SI OPEN 838S (NOTEI) PUMP4B

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 108 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 18 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY NOTE I: Valve positions are the expected positions when BOTH Units are in Modes I through 4. UNIT 3 cow HDR B RETURN LOCKED 3-708F THROTTLED FROM SI PUMPS (NOTE 1) LOCKED UNIT4CCWHDRBRETURN 4-708F CLOSED FROM SI PUMPS (NOTE 1) UNIT3CCWHDRARETURN LOCKED 3-708E CLOSED FROM SI PUMPS (NOTE 1) LOCKED UNIT 4 cow HDR A RETURN 4-708E THROTTLED FROM SI PUMPS (NOTE 1) 838A cow HDR B RETURN FROM SI OPEN (NOTE 1) PUMP 3A LOCKED 8380 cow HDR A RETURN FROM SI CLOSED PUMP 3A (Green Series Key) (NOTE 1) 838E cow HDR B RETURN FROM SI OPEN (NOTEI) PUMP3B cow HDR A RETURN FROM SI LOCKED 838G CLOSED PUMP 3B (Green Series Key) (NOTE 1) cow HDR B RETURN FROM SI LOCKED 838J CLOSED PUMP 4A (Green Series Key) (NOTE 1) 838L oow HDR A RETURN FROM OPEN (NOTE 1) SI PUMP 4A ccw HDR B RETURN FROM LOCKED 838N CLOSED SI PUMP 4B (Green Series Key) (NOTE 1) 838R cow HDR A RETURN FROM SI OPEN (NOTEI) PUMP4B

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 109 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 19 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY CHARGING PUMPS OIL CLRS 3-737E OPEN COW SUPPLY COW TO CHARGING PUMP A 3-825A OPEN OIL CLR CCW FROM CHARGING PUMP 3-825B THROTTLED AOILCLR CCWTO CHARGING PUMP B 3-8250 OPEN OIL CLR COW FROM CHARGING PUMP 3-825D THROTTLED B OIL CLR EMERGENCY HOSE 3-10-290 CONNECTION TO CHARGING CLOSED PUMP A OIL CLR-RETURN EMERGENCY HOSE 3-10-291 CONNECTION TO CHARGING CLOSED PUMP A OIL CLR-SUPPLY EMERGENCY HOSE 3-10-288 CONNECTION TO CHARGING CLOSED PUMP B OIL CLR EMERGENCY HOSE 3-10-289 CONNECTION TO CHARGING CLOSED PUMP B OIL CLR EMERGENCY HOSE 3-10-298 CONNECTION TO CHARGING CLOSED PUMP C OIL CLR-RETURN EMERGENCY HOSE 3-10-299 CONNECTION TO CHARGING CLOSED PUMP C OIL CLR-SUPPLY COW TO CHARGING PUMP C 3-825E OPEN OIL CLR CCW FROM CHARGING PUMP 3-825F THROTTLED C OIL CLR CHARGING PUMPS OIL CLRS 3-839A COW FLOW ROOT VLV TO OPEN FI-3-660 CHARGING PUMPS OIL CLRS 3-839B COW FLOW ROOT VLV TO OPEN FI-3-660

EViIO4 FO.: - AOóEbURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 110 of 131 PROCEDURE NO.: 3-NO P-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 20 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY CHARGING PUMPS OIL CLRS 3-737D OPEN CCW RETURN SPENT FUEL PIT HX COW 3-772 OPEN SUPPLY SPENT FUEL PIT HX SHELL CLOSED & 3-772A SIDE VENT CAPPED SPENT FUEL PIT HX SHELL CLOSED & 3-772C SIDE DRAIN CAPPED SPENT FUEL PIT HX CCW 3-773A OPEN FLOW ROOT VLV TO FI-3-622 SPENT FUEL PIT HX COW 3-773B OPEN FLOW ROOT VLV TO FI-3-622 SPENT FUEL PIT HX COW LOCKED 3 775 OUTLET THROTTLED SPENT FUEL PIT HX CCW 3-776 OPEN OUTLET 3-777 NON-REGEN HX COW SUPPLY OPEN NON-REGEN HX SHELL SIDE CLOSED & 3-777A VENT CAPPED NON-REGEN HX SHELL SIDE CLOSED & 3-777B DRAIN CAPPED NON-REGEN HX COW FLOW 3-778A OPEN ROOT VLV TO FI-3-620 NON-REGEN HX COW FLOW 3-778B OPEN ROOT VLV TO FI-3-620 NON-REGEN HX TEMP 3-833 CONTROL VLV, TCV-3-144, OPEN INLET NOTE 2: TCV-3-144 is normally controlled in Automatic, and when in Automatic will be in the position demanded. NON-REGEN HX TEMP THROTTLED TCV-3-1 44 (NOTE 2) CONTROL VLV TCV-3-144 DOWNSTREAM CLOSED & 3 841 DRAIN CAPPED

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 111 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Corn Donent Cooling Water Valve Alignment (Page 21 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY NON-REGEN HX TEMP 3-780 CONTROL VLV, TCV-3-144, OPEN OUTLET NON-REGEN HX TEMP 3-834 CONTROL VLV, TCV-3-144, CLOSED BYPASS SEAL WATER HX COW 3781

       -                                              OPEN SUPPLY SEAL WATER HX SHELL SIDE             CLOSED &

3-781A VENT CAPPED SEAL WATER HX SHELL SIDE CLOSED & 3-781B DRAIN CAPPED SEAL WATER HX COW FLOW 3-782A OPEN ROOT VLV TO FI-3-61 8 SEAL WATER HX COW FLOW 3-782B OPEN ROOT VLV TO FI-3-618 SEAL WATER HX CCW 3-784 TH ROTTLED OUTLET SEAL WATER HX COW 3-785 OPEN OUTLET RHR PUMP A & CONT SPRAY LOCKED 3-770B PUMP A SEAL WATER HXS OPEN COW HDR A SUPPLY RHRPUMPASEALWTRHX 3-768A OPEN CCW HDR A SUPPLY RHRPUMPASEALWATERHX 3-769A THROTTLED CCW HDR A OUTLET RHR PUMP A SEAL WATER HX 3-7690 CLOSED OUTLET VENT CONT SPRAY PUMP A SEAL 3-795A WATER HX CCW HDR A OPEN SUPPLY CONT SPRAY PUMP A SEAL 3-795B WATER HX COW HDR A THROTTLED OUTLET RHR PUMP A & CONT SPRAY PUMP A SEAL WATER HXS LOCKED 3-770A OPEN CCW HDR A OUTLET

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 112 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 22 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY RHR PUMP B & CONT SPRAY LOCKED 3-770D PUMP B SEAL WATER HXS OPEN CCW HDR B SUPPLY CLOSED & 3-10-054 CCW HDR B DRAIN CAPPED RHR PUMP BSEALWATERHX 3-768B OPEN CCW HDR B SUPPLY RHR PUMP B SEAL WATER HX 3-769B THROTTLED CCW HDR B OUTLET RHR PUMP B SEAL WATER HX 3-769D CLOSED OUTLET VENT CONT SPRAY PUMP B SEAL 3-795C WATER HX CCW HDR B OPEN SUPPLY CONT SPRAY PUMP B SEAL 3-795D WATER HX CCW HDR B THROTTLED OUTLET RHR PUMP B & CONT SPRAY LOCKED 3-77CC PUMP B SEAL WATER HXS OPEN CCW HDR B OUTLET RHR HXACCWHDRA 3-746A OPEN SUPPLY 3-765A RHR HX A SHELL SIDE VENT OPEN CLOSED & 3-746E RHR HX A SHELL SIDE VENT CAPPED CLOSED & 3-746C RHR HX A SHELL SIDE DRAIN CAPPED

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 113 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 23 of 30) COMPONENT COMPONENT DESCRIPTION POSITION I ALIGNED VERIFIED NUMBER REQUIRED BY BY CAUTION I: The positions of valves 3-748A and B are preset as determined by COW System flow testing. The Engineering Department Manager shall be notified prior to changing the position of these valves. 3-748A should be LOCKED OPEN at approximately 35 percent and 3-748B should be LOCKED OPEN at approximately 38 percent. LOCKED 3-748A RHRHXACCWHDRA OPEN OUTLET (CAUTION 1) LOCKED RHRHXBCCWHDRB 3-748B OPEN OUTLET (CAUTION 1) RHR HX B CCW HDR B 3-746B OPEN SUPPLY 3-765B RHR HX B SHELL SIDE VENT OPEN RHR HX B SHELL SIDE VENT CLOSED & 3-746F CAPPED RHR HX B SHELL SIDE DRAIN CLOSED & 3-746D CAPPED CCW HDR B SUPPLY TO RCP, CONT CLRS, ROD DRIVE 3-835C CLRS, PRIMARY SHIELD, OPEN EXCESS LETDOWN HX, EVAP CLRS, & SAMPLE CLRS COW HDR A SUPPLY TO RCP, CONT CLRS, ROD DRIVE 3-835D CLRS, PRIMARY SHIELD, CLOSED EXCESS LETDOWN HX, EVAP CLRS, & SAMPLE CLRS PEN 21 TEST CONN VLVON CLOSED & 3-10-870 CCW LINE UPSTREAM OF CAPPED MOV-3-1417 CCW LINE TO NCC TEST CONNECTION VALVE CLOSED & 3-10-871 DOWNSTREAM OF CAPPED MOV-3-1417

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 114 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 24 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY PEN 12 TEST CONN VLV ON CLOSED & 3-737F CCW LINE UPSTREAM OF CAPPED 3-737A EXCESS LETDOWN HX CCW 3-737A OPEN SUPPLY ISOL PEN 12 TEST CONN VLV ON CLOSED & 3-737G CCW LINE DOWNSTREAM OF CAPPED 3-737A PEN 3 TEST CONN VLV ON CLOSED & 3-716C CCW LINE UPSTREAM OF CAPPED MOV-3-71 6A PEN 3 TEST CONN VLV ON CLOSED & 3-716D CCW LINE DOWNSTREAM OF CAPPED MOV-3-71 6B PEN 44A TEST CONN VLV ON CLOSED & 3-10-867 CCW LINE UPSTREAM OF CAPPED CV-3-2905 PEN 44A TEST CONN VLV CCWTO ECC LINE CLOSED & 3-10-874 CAPPED DOWNSTREAM OF CV-3-2905 PEN 44B TEST CONN VLV ON CLOSED & 3-10-868 CCW LINE UPSTREAM OF CAPPED CV-3-2903 PEN 44B TEST CONN VLV CLOSED & 3-10-875 CCWTO ECC LINE CAPPED DOWNSTREAM OF CV-3-2903 PEN 44C TEST CONN VLV ON CLOSED & 3-10-869 CCW LINE UPSTREAM OF CV-3-2904 CAPPED PEN 44C TEST CONN VLV CLOSED & 3-10-876 CCWTO ECC LINE CAPPED DOWNSTREAM OF CV-3-2904 CCW HDR A TIE TO EMERG 3-10-651 CLOSED CONT CLR C CCW HDR B TIE TO EMERG 3-10-650 OPEN CONT CLR C

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 115 of 131 PROCEDURE NO.: 3-NO P-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 25 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY SAFE SHUTDOWN CV-3-2903 Sealed in 3-40-1 899 MANUAL CONTROL VENT NORMAL VALVE SAFE SHUTDOWN CV-3-2903 Sealed in 3-40-1 900 MANUAL CLOSE AIR NORMAL ISOLATION VALVE SAFE SHUTDOWN CV-3-2905 Sealed in 3-40-1 901 MANUAL CONTROL VENT NORMAL VALVE SAFE SHUTDOWN CV-3-2905 Sealed in 3-40-1 902 MANUAL CLOSE AIR NORMAL ISOLATION VALVE CV-3-2906, POLV AIR-FAIL Sealed in 3-40-2479 TEST VLV (OPENING NORMAL CYLINDER SIDE) CV-3-2906, POLV AIR-FAIL Sealed 3-40-2480 TEST VLV (CLOSING OPEN CYLINDER SIDE) CV-3-2907, POLV AIR-FAIL Sealed in 3-40-248 1 TEST VLV (OPENING NORMAL CYLINDER SIDE) CV-3-2907, POLV AIR-FAIL Sealed 3-40-2482 TEST VLV (CLOSING OPEN CYLINDER SIDE) CV-3-2908, POLV AIR-FAIL Sealed in 3-40-2483 TEST VLV (OPENING NORMAL CYLINDER SIDE) CV-3-2908, POLV AIR-FAIL Sealed 3-40-2484 TEST VLV (CLOSING OPEN CYLINDER SIDE) CCW HDR A TO EM ERG CONT CLOSED & 3-1 0-039 CLRADRAIN CAPPED CCW HDR B TO EMERG CONT CLOSED & 3-1 0-040 CLRS B & C DRAIN CAPPED CCW HDR B TO EMERG CONT 3-10-054 CLOSED CLR B & C DRAIN EXCESS LD HX CCW OUTLET 3-740A OPEN HDR ROOT VLV TO FI-3-624

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 116 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 26 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY EXCESS LD HX CCW OUTLET 3-740B OPEN HDR ROOT VLV TO FI-3-624 PEN 13 TEST CONN VLV ON CCW LINE DOWNSTREAM OF CLOSED & 3-739B CV-3-739 CAPPED EXCESS LD HX CCW OUTLET 3-737B THROTTLED HDR ISOLATION PEN 13 TEST CONN VLV ON 3-739C CCW LINE DOWNSTREAM OF CLOSED & 3-737B CAPPED 3-835A COW RETURN HDR A ISOL CLOSED 3-835B CCW RETURN HDR B ISOL OPEN PEN43TESTCONNVLVON COW LINE UPSTREAM OF CLOSED & 3-626A CAPPED M OV-3-626 PEN 43 TEST CONN VLV ON CLOSED & 3-6268 COW LINE DOWNSTREAM OF MOV-3-626 CAPPED RCFS THERMAL BARRIERS 3-736 OPEN COW OUTLET HDR ISOLATION PEN 43 TEST CONN VLV ON CCW LINE DOWNSTREAM OF CLOSED & 3-626D 3-736 CAPPED PEN 4 DRAIN/TEST CONN VLV CLOSED & 3-73DB ON CCW LINE UPSTREAM OF MOV-3-730 CAPPED PEN 4 DRAIN/TEST CONN VLV CLOSED & 3-73CC ON COW LINE DOWNSTREAM OF MOV-3-730 CAPPED RCPS BEARING CLRS COW 3-743A OUTLET HDR HIGH PRESS OPEN ROOT VLV TO FI-3-677 RCPS BEARING CLRS CCW 3-743B OUTLET HDR LOW PRESS OPEN ROOT VLV TO FI-3-677

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 117 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 27 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY RCP BEARING OIL COOLERS 3-732 OPEN CCW OUTLET HDR ISOLATION PEN 4 TEST CONN VLV ON 3-730E CCW LINE DOWNSTREAM OF CLOSED & CAPPED 3-732 CCW HDR FROM NORM CONT 3-10-736 AND ROD DRIVE CLRS OPEN FI-3-1462 H. P. ROOT VALVE CCW HDR FROM NORM CONT 3-10-737 AND ROD DRIVE CLRS OPEN FI-3-1462 L. P. ROOT VALVE CCW LINE FROM NCC AND CRDMS PENETRATION 22 CLOSED & 3-1 0-872 TEST CONNECTION VALVE CAPPED UPSTREAM OF MOV-3-1418 PEN 22 TEST CONN VLV ON CLOSED & 3-10-873 CCW LINE DOWNSTREAM OF CAPPED MOV-3-1418 ECC RETURN TO CCW PEN 45A TEST CONN VLV CLOSED & 3-1 0-861 UPSTREAM OF CV-3-2908 & CAPPED CV-3-281 4 PEN 45A TEST CONN VLV ON 3-10-862 CCW LINE DOWNSTREAM OF CLOSED & CAPPED CV-3-2908 & CV-3-2814 EM ERG CLR A CCW OUTLET 3-10-672 OPEN HDR BYPASS LINE ISOLATION EMERG CLR A CCW OUTLET 3-10-738 OPEN HDR ROOT VLV TO FT-3-1464 EMERG CLR A CCW OUTLET 3-10-739 OPEN HDR ROOT VLV TO FT-3-1464 ECC RETURN TO CCW PEN 45B TEST CONN VLV CLOSED & 3-10-863 UPSTREAM OF CV-3-2906 & CAPPED CV-3-281 0 PEN 45B TEST CONN VLV ON 3-10-864 CLOSED & CCW LINE DOWNSTREAM OF CAPPED CV-3-2906 & CV-3-281 0

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 118 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 28 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY EMERG CLR B CCW OUTLET 3-10-670 OPEN HDR BYPASS LINE ISOLATION ECC RETURN TO CCW PEN 45C TEST CONN VLV CLOSED & 3-10-865 UPSTREAM OF CV-3-2907 & CAPPED CV-3-281 2 PEN 45C TEST CONN VLV ON CLOSED & 3-10-866 CCW LINE DOWNSTREAM OF CAPPED CV-3-2907 & CV-3-2812 EMERG CLR C CCW OUTLET 3-10-671 OPEN HDR BYPASS LINE ISOLATION EMERG CLR C TIE TO CCW 3-10-652 OPEN HDR B EMERG CLR C TIE TO CCW 3-10-653 CLOSED HDRA EMERG CLRS B & C CCW 3-10-740 OUTLET HDR ROOT VLV TO OPEN FT-3-1 465 EMERG CLRS B & C CCW 3-10-741 OUTLET HDR ROOT VLVTO OPEN FT-3-1 465 3-786A SAMPLE CLRS COW SUPPLY OPEN 3-781C PZR STM SMPL DRN CLOSED 3-781D PZR STM SMPL DRN CLOSED 3-781E RX COOLANT SMPL DRN CLOSED PRZ STEAM SAMPLE CLR 3-788A THROTTLED COW OUTLET PRZ LIQUID SAMPLE CLR 3-788B THROTTLED CCWOUTLET REACTOR COOLANT SAMPLE 3-788C THROTTLED CLR COW OUTLET SAMPLE CLRS COW OUTLET 3-781F CLOSED HDR TEST CONN.

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 119 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Component Cooling Water Valve Alignment (Page 29 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY SAMPLE CLRS CCW OUTLET 3-781G CLOSED HDR TEST CONN. SAMPLE CLRS CCW OUTLET 3-781H CLOSED HDRTSTCONN. SAMPLE CLRS CCW OUTLET 3-774A OPEN ROOT VLV TO F 1-3-643 SAMPLE CLRS CCW OUTLET 3-774B OPEN ROOT VLV TO F 1-3-643 SAMPLE CLRS CCW OUTLET 3-786B OPEN HDR ISOLATION PASS, GAS COMPRESSORS, & 3-789A OPEN BA EVAP CCW SUPPLY WASTE GAS COMPRESSOR A 0-826A OPEN CCW SUPPLY WASTE GAS COMPRESSOR B 0-826D OPEN CCW SUPPLY WASTE GAS COMPRESSOR A 0-826B THROTTLED CCW OUTLET WASTE GAS COMPRESSOR A 0-826C OPEN CCW OUTLET WASTE GAS COMPRESSOR B 0-826E THROTTLED CCW OUTLET WASTE GAS COMPRESSOR B 0-826F OPEN CCW OUTLET BA EVAP CONCENTRATOR WIRED 3-792A CCW SUPPLY CLOSED BA EVAP CONDENSATE CLR WIRED 3-829 CCW SUPPLY CLOSED BA EVAP CCW OUTLET WIRED 3-792B CLOSED P.A.S.S. GAS COMPRESSORS, 3-789B OPEN

               & BA EVAP CCW OUTLET UNIT 3- UNIT 4 CCWTIE LOCKED 0-779A    BTWN BA EVAP AND WASTE CLOSED GAS COMPRESSORS (INLET)

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 120 Of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT I Comnonent Cooling Water Valve Alignment (Page 30 of 30) COMPONENT POSITION ALIGNED VERIFIED COMPONENT DESCRIPTION NUMBER REQUIRED BY BY UNIT 3- UNIT 4 COW TIE BTWN BA EVAP AND WASTE LOCKED 0-779B GAS COMPRESSORS CLOSED (OUTLET) 0-827A P.A.S.S. CCW SUPPLY OPEN CLOSED& 0-82 1 B WASTE EVAP CCW SUPPLY CAPPED CLOSED & 0-730G WASTE EVAP CCW OUTLET CAPPED 0-730H WASTE EVAP CCW OUTLET CLOSED P.A.S.S. CCW OUTLET HDR CLOSED & 0-790C VENT CAPPED P.A.S.S. COW OUTLET HDR CLOSED & 0-790D VENT CAPPED 0-828 P.A.S.S. COW OUTLET OPEN 0-827B P.A.S.S. COW OUTLET OPEN VENT FOR CHILLED WATER CLOSED & 6733 SUPPLY FROM TEMP CAPPED CONTAINMENT CHILLER DRAIN FOR CHILLED WATER CLOSED & 6734 SUPPLY FROM TEMP CAPPED CONTAINMENT CHILLER VENT FOR CHILLED WATER CLOSED & 6735 RETURN TO TEMP CAPPED CONTAINMENT CHILLER DRAIN FOR CHILLED WATER CLOSED & 6736 RETURN TO TEMP CAPPED CONTAINMENT CHILLER ISOL VLV ON CCW INLET TO 3-5169 OPEN PASS SAMPLE COOLER ISOL VLV ON COW OUTLET 3-51 70 OPEN FROM PASS SAMPLE COOLER

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 121 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT 2 Component Cooling Water System Control Switch Alignment (Page 1 of 4) EXCEPTIONS COMPONENT COMPONENT DESCRIPTION REMARKS NUMBER PERSONNEL PERFORMING MANIPULATIONS Printed Name Initials Completion Of Lineup DATE LINEUP (MMIDDIYY): TIME LINEUP (HH:MM, 24 HR CLOCK): COMPLETED: ,i COMPLETED: LINEUP PRINTED NAME I SIGNATURE: COM PLETED BY: Review Of Lineup LINEUP PRINTED NAME I SIGNATURE: DATE: (MM/DD/YY): REVIEWED BY:

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 122 Of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT2 Component Cooling Water System Control Switch Alignment (Page 2 of 4) COMPONENT NOUN DESCRIPTION POSmON ALIGNED VEFlED NOTE 1: Normally OPEN with associated Breaker 30743 LOCKED OFF. MOV-3-716A, RCP CCW INLET (NOTE 1) MOV-3-716B, RCP CCW INLET OPEN MOV-3-730, RCP BEARING CCW OUTLET OPEN CV-3-739, EXCESS LID HX OUTLET OPEN MOV-3-1417, CCWTO NORMAL CONTAINMENT COOLER OPEN MOV-3-1418, CCW FROM NORMAL CONTAINMENT COOLER OPEN MOV-3-626, RCP SEAL CLG WATER OPEN OUTLET CV-3-2905, 3A EMERG CONTMT COOLER INLET OPEN NOTE 2: Normally CLOSED while TSA 271821 is implemented. Control switch for 3V30B, 3B EM ERG CNTMT COOLER FAN MOTOR is in STOP while TSA 271821 is implemented. CV-3-2903, 3B EMERG CONTMT CLOSED (NOTE 2) COOLER INLET CV-3-2904, 3C EMERG CONTMT COOLER INLET OPEN

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 123 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT 2 Component Cooling Water System Control Switch Alignment (Page 3 of 4) COMPONENT NOUN DESCRIPTION POSiTKN ALIGNED VERlED NOTE 3: Normally CLOSED. When opened, position is maintained by a limiter. Prior to any maintenance on these valves, the Engineering Department shall be notified to ensure that the limiter position on the valves is maintained. CV-3-2908, 3A EMERG CONTMT COOLER CLOSED (NOTE 3) OUTLET CV-3-2814, 3A EMERG CONTMT COOLER OPEN BYPASS NOTE 4: Normally OPEN while TSA 271821 is implemented. A stem block is installed that restrains the valve open and will be removed when the actuator has been repaired or replaced. CV-3-2906, 3B EM ERG CONTMT COOLER OPEN (NOTE 4) OUTLET NOTE 5: Normally CLOSED. Control switch for 3V30B, 3B EMERG CNTMT COOLER FAN MOTOR is in STOP while TSA 271821 is implemented. CV-3-2810, 3B EMERG CONTMT COOLER CLOSED (NOTE 5) BYPASS CV-3-2907, 3C EMERG CONTMT COOLER CLOSED (NOTE 2) OUTLET CV-3-2812, 3C EMERG CONTMT COOLER BYPASS OPEN

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 124 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT 2 Component Cooling Water System Control Switch Alignment (Page 4 of 4) COMPONENT NOUN DESCRIPTION POSITION ALIGNED VERIFIED REQUIRED BY BY NOTE 6: If in Mode 4, 5, or 6 AND associated RHR Loop is in operation, then valve may be OPEN. MOV-3-749A, 3A RHR HX COMP COOLING CLOSED (NOTE 6) OUTLET MOV-3.749B, 3B RHR HX COMP COOLING CLOSED (NOTE 6) OUTLET RCV-3-609, COMP CLG HEAD VENT OPEN

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 125 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT 3 Component Cooling Water System Breaker Alignment (Page 1 of 3) EXCEPTIONS COMPONENT COMPONENT DESCRIPTION REMARKS PERSONNEL PERFORMING MANIPULATIONS PRINTED NAME INITIALS COMPLETION OF LINEUP DATE LINEUP (MM/DD/YY): TIME LINEUP (HH:MM, 24 HR CLOCK): COMPLETED: j j COMPLETED: LINEUP PRINTED NAME I SIGNATURE: COMPLETED BY: REVIEW OF LINEUP LINEUP REVIEWED PRINTED NAME I SIGNATURE: DATE: (MMIDDIYY): BY:

RE\SION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 126 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT 3 Corn Donent Cooling Water System Breaker Alignment (Page 2 of 3) COMPONENT COMPONENT POSITION ALIGNED VERIFIED NUMBER DESCRIPTION REQUIRED BY BY 3A 4160V Switchgear Room Racked IN Blue_Light_ON White Light ON COMPONENT COOLING Red or Green 3AA12 WATER PUMP 3A Light ON L/R Switch in REMOTE Lockout RESET 3B 4160V Switchgear Room Racked_IN Blue_Light_ON COMPONENT COOLING White Light ON 3AB13 WATER PUMP 3B Red or Green Light_ON Lockout RESET 3D 4160V Switchgear Room Racked_IN Blue_Light_ON White_Light_ON COMPONENT COOLING Red or Green 3AD04 Light ON WATER PUMP 3C Normal/Isolate Switch in NORM Lockout RESET

VON NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 127 of 131 PROCEDURE NO.: 3-NO P-030 TURKEY POINT UNIT 3 ATTACHMENT 3 Component Cooling Water System Breaker Alignment (Page 3 of 3) COMPONENT COMPONENT POSITION ALIGNED VERIFIED NUMBER DESCRIPTION REQUIRED BY BY 480V MCC 3B 30617 RHR HX 3B COW OUTLET, ON MOV-3-749B 30624 CCW RETURN FROM ON NORMAL CONTAINMENT COOLERS, MOV-3-1418 30637 CCW RETURN FROM ON RCPS BEARING COOLERS, MOV-3-730 30638 CCW RETURN FROM ON RCPS THERMAL BARRIERS, MOV-3-626 30639 CCW SUPPLY TO RCPS ON OIL COOLERS AND THERMAL BARRIERS, MOV-3-716B 480V MCC 3D 30822 COW TO NCCS, ROD ON DRIVE COOLERS, AND PRIMARY SHIELD COOLERS, MOV-3-1417 480V MCC 3C 30721 RHR HX 3A CCW OUTLET, ON M OV-3-749A 30743 CCW SUPPLY TO RCPS LOCKED OFF OIL COOLERS AND THERMAL BARRIERS, MOV-3-71 6A 30775 PRIMARY WATER ON MAKEUP TO CCW SURGE TANK, MOV-3-832

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 128 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT 4 Comøonent Cooling Water Flow Rates (Page 1 of 4) NOTE

1. Maximum rates are acceptable provided the MAX TOTAL flow is maintained less than 13,680 GPM (6840 GPM for single COW Hx).

2. Minimum flow through the ECC Bypass valves should be adjusted to provide greater than 0 GPM per indication or audibly for each ECC. Due to cooler discharge valve leakage, it is acceptable for the measured flow to exceed 250 GPM to each cooler if the throttle valve is closed. The maximum ECC flowrate is 3200 GPM per cooler for 31 days, or 5000 GPM for 24 hours and 5500 gallons for 1 hour. The method for setting the bypass flows and flow limits are contained in 3-NOP-055.

NORMAL OPERATING FLOW FLOW RATES (GPM) FLOW COMPONENT ADJUSTMENT Initials INDICATION VALVE(S) Minimum Maximum (Note 1) SIS Pumps A 3-708E FIC-658A 20 30 SIS Pumps B 3-708F FIC-658B 20 30 Hdr Charging 3-825B Pumps Oil CIrs 3-825D FI-3-660 150 165 Hx 3-825 F Seal Water Hx 3-784 FI-3-61 8 100 200 Non-Regen Hx TCV-3-144 100 800 CAUTION Spent Fuel Pit Hx flow is adjusted by Flow Balance per 3-OSP-030.9. Any additional flow adjustment must be authorized by the System Engineer. Spent Fuel Hx 3-775 Fl-3-622 (See Caution) (See Caution)

REVISION NO.: PROCEDURE TITLE: PAGE: 9 COMPONENT COOLING WATER SYSTEM 129 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT 4 Component Cooling Water Flow Rates (Page 2 of 4) NORMAL OPERATING FLOW FLOW RATES (GPM) COMPONENT ADJUSTMENT FLOW INDICATION Initials VALVE(S) Minimum Maximum (Note 1) RHR Pump A 3-769A Fl-3-637 8.5 14 Seal Water Hx RHR Pump B 3-769B Fl-3-638 8.5 14 Seal Water Hx CS Pump A 3-795B Fl-3-657 12 17.5 Seal Water Hx CS Pump B 3-795D Fl-3-659 12 17.5 Seal Water Hx CAUTION ECC A & B Hdr flows are adjusted by Flow Balance per 3-OSP-030.9. Any additional flow adjustment must be authorized by the System Engineer. Fl-3-1472 (LCL) >0 1000 ECC A Hdr 3-672 (See Caution) (See Caution) Fl-3-1470 (VPB) (Note 2) (Note 2) 3-670 FI-3-1473 (LCL)

                                                                >0          2000 ECC B Hdr                                                 (See Caution) (See Caution) 3-671         Fl-3-1471 (VPB)      (Note 2)      (Note 2)

RCP 3A Lower 3-723A FI-3-628 5 10 Brng Oil Cooler RCP 3B Lower 3-723B FI-3-631 5 10 Brng Oil Cooler RCP 3C Lower 3-723C FI-3-634 5 10 Brng Oil Cooler

REVISION NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 130 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT 4 Component Cooling Water Flow Rates (Page 3 of 4) NORMAL OPERATING FLOW FLOW RATES (GPM) COMPONENT FLO ADJUSTMENT Initials INDICATION VALVE(S) Minimum Maximum (Note 1) RCP 3A Upper

& Lower Brng         3-724A           FIC-629           155        170 Oil Coolers RCP 3B Upper
& Lower Brng         3-724B            FIC-632           155       170 Oil Coolers RCP 3C Upper
& Lower Brng         3-724C            FIC-635           155       170 Oil Coolers RCP 3A Thermal Barrier      3-728A           Fl-3-630           21         28 Cooling Coils RCP 3B Thermal Barrier      3-728B           Fl-3-633           21         28 Cooling Coils RCP 3C Thermal Barrier      3-728C           Fl-3-636            21        28 Cooling Coils Excess 3737B            Fl3-624             >0       238 Letdown Hx Rod Drive ClrA     3-10-663          Fl-3-1448         220        228 Rod Drive CIr B    3-10-665          Fl-3-1449          220       228 Waste Gas            3-826B            Fl-3-666           20        30 CompA Waste Gas            3-826E           Fl-3-665            20        30 Comp B

VIiON NO.: PROCEDURE TITLE: PAGE: COMPONENT COOLING WATER SYSTEM 131 of 131 PROCEDURE NO.: 3-NOP-030 TURKEY POINT UNIT 3 ATTACHMENT 4 Component Cooling Water Flow Rates (Page 4 of 4) NORMAL OPERATING FLOW FLOW RATES (GPM) COMPONENT FLOW ADJUSTMENT Initials INDICATION VALVE(S) Minimum Maximum (Note 1) NOTE: Minimum flowrates for NCC is that flowrate required to maintain containment temperature less than 120°F. NCC flowrates are re-verified in 3-GOP-301, Hot Standby to Power Operation at NOP/NOT. Any additional flow adjustment must be authorized by System Engineer. NCCA 3-10-655 Fl-3-1444 0 740 NCC B 3-10-657 Fl-3-1445 0 740 NCC C 3-10-661 Fl-3-1447 0 740 NCC D 3-10-659 Fl-3-1446 0 740 Prz Steam 3-788A FI-3-615A 20 35 Sample Hx Prz Liquid 3-788B Fl-3-615B 20 35 Sample Hx Rx Coolant 3-788C Fl-3-615C 20 35 Sample Hx CAUTION RHR A and B Hx flows are adjusted by Flow Balance per 3-OSP-030.9, Component Cooling Water Flow Balance. Any additional flow adjustment must be authorized by the System Engineer, and done using a clamp-on flow instrument.

2 ODI-CO-004 Shift Operations Management System (eSOMS) 0611712011 scope of work to be performed prior to authorization. 4.3 ECO Executors Performs ECO steps in the order written (unless previously noted) in the field and hangs tags associated with the ECO. 5.0 INSTRUCTIONS 5.1 Perform the appropriate section of the Use of the NOMS Software: Index for Clearance performance. Use of the NOMS Software: Index I. Start the ECO MODULE II. Open the ECO MANAGER III. Create a new SECTION IV. Enter new Section descriptive information V. Attach applicable WORK ORDERS to the Section VI. Generate the specific CLEARANCE POINTS VII. SECTION VERIFICATION: signature update VIII. Print SECTION COVER PAGE, SECTION TAG HANG LIST and TAGS IX. Hang the tags X. TAG VERIFICATION For Hanging: first and second verification Xl. SECTION VERIFICATION: signature update XII. Sign-on CONTROLLERS and HOLDERS XIII. Sign-off CONTROLLERS and HOLDERS XIV. SECTION VERIFICATION: signature update; US Removal Authority and print out of the 2

3 ODI-CO-004 Shift Operations Management System (eSOMS) 06/17/2011 TAGS TO BE REMOVED LIST XV. REMOVE the tags TO BE REMOVED FROM LIST XVI US REMOVAL AUTHORIZATION and Resolution of a Restoration Conflict XVII. TAG VERIFICATION for Restoration: first and second verification XVIII. SECTION VERIFICATION: signature update, Tags Verified Removed XIX. Closeout of ECO Number XX. Using the Drag and Drop Method to Generate New Clearance Points XXI. Printing of Necessary Documents XXII. Attaching Work Orders XXIII. Work Order Manager XXIV. NOMS for the SM/US XXV. Boundary Modification & Revisions XXVI. Clearance Walkdown Requirements 3

4 ODI-CO-004 Shift Operations Management System (eSOMS) 0611712011 I. Start the ECO MODULE. A. The ECO Preparer Checklist #1 should be obtained and filled out, with all appropriate steps either checked or N/Ad as applicable during the preparation process. B. Click on Clearance Module icon. C. Log In:

1. Your LOGIN ID is your SLID.

2 Your PASSWORD is the last 4 digits of your SS# (unless it has been changed).

a. To change your password use the Change Password function found under Options on the ECO Module tool bar.

II. Open the ECO MANAGER A. Click on FILE located on the ECO Module tool bar. A second option is to click on the open file folder icon on the toolbar. B. Click on OPEN.

1. This operation will display the ECO LIST in the upper left corner of the screen.

C. Next single click on the (+) sign to the left of ACTIVE ECOs. This operation will open an ECO LIST, which consists of all ECOs in the Active ECO category. On the left half of the window, the Active ECOs will be displayed in a tree format arranged in increasing numerical order. The same information will be displayed as a list on the right half of the screen.

1. The ECO numbering format is: Unit designator Year Month

                                                                       -    -        - Sequential ECO Number (example: 4-00-11-001)

2. The ADD button located at the bottom of the ECO List is used to generate a new ECO number.

4

5 ODI-CO-004 Shift Operations Management System (eSOMS) 0611712011 D. Create a New ECO Number:

1. Click the Add button on the lower left hand corner of the screen

2. From the drop down menu, select ECO (even for Caution Tags).

3. Click OK

4. Fill in the ECO number using the format from ll.C.l.

5. You will be prompted that you have successfully created an ECO number.

Now re-expand the active ECO list; scroll down to the new number and - fFoi.iatted: Bullets and Numberin double click that number. Complete the following fields with as much detail as possible . - Formatted: Bullets and Number, Component to be worked (must match TEDB exactly) Clearance boundaries Scope of work d) Unit NOTE IF the component to be worked is NOT in TEDB then place the component description to be worked in the Clearance boundaries Select the ECO verification Tab - - Formatted: Bullets and Numbering Highlight the Opened By line Double click on the user block; your name will automatically fill in. This will lock all paths entered in the ECO, no changes can be made after electronically signed. G. Select the ECO SECTION List tab. (This can also be performed using Ill).

1. Select NEW

2. Enter the new section name. Then hit the TAB key.

a. For most non-outage sections, use the equipment identification, name or description.

5

6 ODI-CO-004 Shift Operations Management System (eSOMS) 0611712011

b. For outage sections, use the predefined ZONES. This allows tag sharing which reduces the need for multiple tags hanging on a single piece of equipment, thereby reducing man-hours, and man-rem needed to hang multiple overlapping ECOs.

III. Create a new SECTION (This can also be performed using ILG) A. Re-expand the active ECO list, scroll down to the new number and right click that number. Select Create New Active FCC Section.

1. Under freeform, type IN THE EQUIPMENT, DECRIPTICN CR ZONE.

2. Hit the TAB key, then click on Create New Active FCC Section.

3. YES, when prompted to open new section, depress the TAB key (the section name will automatically fill in).

IV. Enter new Section descriptive information. A. Expand the appropriate FCC by single clicking on the (4-) sign for the FCC. This will display all of the sections in this FCC. B. If you Double click on the section number in the expanded tree, the SECTION DETAIL will open in the edit mode. C. The Component to be worked ID number must match the TEDB designation EXACTLY. Search the Equipment Manager for TEDB designations. D. The remaining fields, Section Description, Reason, Hazards, and Special instructions, are freeform fields; i.e. any information may be entered into these fields, try to be as descriptive as possible. F. Select the ATTRIBUTES tab and complete the attributes field. This is especially important for field #2 Safety Related and field #9 Containment Integrity.

1. Requested By may be left blank, however, for online clearances this should be the work week (WWxxx). Add an F at the end if the clearance is emergent (WWxxxE).

6

7 ODI-CO-004 Shift Operations Management System (eSOMS) 06/1712011 V. Attach applicable WORK ORDERS to the Section. A. Click on WORK ORDER(s), TAB on the top of the ECO Section Screen.

1. For this screen the left half of the screen is used by Operations to attach (add) work orders to this specific section; the right half is for the maintenance technician to sign on /sign-off of specific work orders for this section.

B. Click on ADD, located at the lower left corner of the window.

1. A pick-list will drop down from the Work Order data entry field, located in the upper left corner of the window.

C. Scroll down the pick-list to the desired work order, then click on that number. The number should be displayed in the box, click on the save button at the bottom of the screen. Alternatively, the work order number can be entered to find it on the list. D. Click on ADD to add a second work order. Repeat steps B and C as many times as necessary to add all of the applicable work orders. E. If the work order number is not available on the pick list, go to work order manager (steam shovel icon) and add the work order number and other applicable information. F. For information:

1. Once this Section has been hung and verified, the maintenance personnel (technician level) will be able to sign-on/sign-off individual work orders using the right hand side of this screen.

VI. Generate the specific CLEARANCE POINTS. A. Click on ECO SECTION TAGS TAB. B. Click on the ADD button located at the lower left corner of the active window. 7

8 ODI-CO-004 Shift Operations Management System (eSOMS) 06/1712011 C. Enter the Equipment ID for the desired clearance point. This equipment ID must exactly match the equipment ID as defined in the TEDB. If the component is not in the TEDB, then the component can NOT be used as a clearance point! Equipment IDs can only be used once in any ECO Section. Procedure numbers that have been entered in the equipment database can be used to document non-tagged steps. D. Determination of the tag type

1. Click on the Tag type for the specific clearance to be edited/modified. (i.e.

Danger, Caution, info tag, none or restoration checklist)

2. Select the desired tag type from the pick list.

E. Determination of the Placement Configuration.

1. Click on the specific clearance point in the corresponding Placement Configuration.

2. Drop down pick list will appear in the Placement Configuration field.

3. Click the desired position.

4. Repeat for the remaining points.

F. Sequence clearance points:

1. Click on the clearance point to be moved.

2. Use up and down arrows located at the lower right of the screen to move the selected point up of down in the placement sequence.

3. When done, click the RESEQUENCE button on the bottom of the screen to renumber the points for posting.

a. The restoration sequence will default to the reverse of the posting sequence. The Restoration sequence can be modified at a later time.

8

9 ODI-CO-004 Shift Operations Management System (eSOMS) 06/17/2011

4. To assign the same placement sequence to multiple clearance points, directly edit the Placement Sequence field.

a. Click on the desired field.

b. Delete the current sequence number.

c. Enter (type) the desired sequence number. Click Save DO NOT click Re- sequence.

5. Determination of the Restoration Configuration (restored position).

CAUTION Ensure that the Restoration Position is appropriate for the current plant Mode and System/Component Configuration.

Unless otherwise specified P&ID positions are Mode 1
Unless otherwise specified, procedure lineup attachments are for Mode 5

a. When preparing an ECO release, two sources shall be used to determine the as-left component position. These sources shall be included in the ECO package and should include controlled documents such as:

1) P&ID drawings

2) The appropriate procedure section

3) Breaker List

b. Click on the specific clearance point in the Correspondence Restoration Configuration. Restoration Configurations can be filled in later.

c. A drop down pick list will appear in the Restoration position Field.

d. Click on the desired cleared position.

e. Repeat for the remaining points.

G. Re-sequence the order for removing the tags (if required): 9

10 ODI-CO-004 Shift Operations Management System (eSOMS) 0611712011

1. Click on the corresponding Restoration Sequence field.

2. Modify the contents of the field to the desired sequence.

3. Click the SAVE button on the tool bar do NOT click Re-sequence.

H. Perform an on-demand conflict check by clicking the CONFLICT CHECK button located on the bottom of the Section Tags window. CONFLICT CHECK UN-ISSUED will warn of conflicts with other prepared ECO Sections that have not been approved.

1. Checks this sections tags against the tags in all of the sections of all of the active ECOs for both units:

a. Tag type conflicts

b. Position conflicts.

2. A pop-up window will display the results of the conflict check. Conflicts can be printed out for investigation and corrections.

ECO Preparer Verify Checklist #1 is filled out with all appropriate steps either checked or N/Ad as applicable. Upon completion, the ECO preparer shall sign the ECO Prepared By block under the ECO Section Verification tab in the ECO module. J. ECO Reviewer Verify Checklist #1 is filled out with all appropriate steps either checked or N/Ad as applicable. Upon completion, the ECO Reviewer signs LMD 1 or 4 Review block under the ECO Section Verification tab in the ECO module. SECTION VERIFICATION: signature update -

                                                                                                   - IFormatted: Bullets and Numbering A. The 1 st SRO Approval Checklist #2 and SRO Review/Challenge of ECO Prior to Execution         Checklist #3 need to be performed during the Approval Section steps 10

11 ODI-CO-004 Shift Operations Management System (eSOMS) 06/1712011 B. Click on SECTION VERIFICATION C. Double click on appropriate signature

1. Prepared By this signature may be reversed, i.e. erased, by clicking on the Sign-Off button. Changes to the ECO Section by another person will require signing off the original author.

2. US Reviewed By:

a. Conflict check will be performed automatically.

b. An electronic signature is required in order to produce a Section Tag Hang List.

c. Section tags can not be printed until this signature has been entered.

d. Non-reversible signature.

3. SM Reviewed By this signature may be reversed, this signature is NOT required by the NOMS module, but is required by O-ADM-212 for certain systems.

4. Verified Executed this signature is non-reversible, and can only be signed once the Tags have been first and second verified in the computer.

VIII. Print SECTION COVER PAGE, SECTION TAG HANG LIST and TAGS. A. Click on the printer button on the tool bar. Alternatively you can right click on the desired section on the ECO List Tree. B. Select the item to print by placing a check mark in the desired boxes. C. Print the following using the print button: NOTE: A Section Tag List MUST always have a Section Cover Sheet attached. The Section Cover Sheet is the only record of the approval status (signatures) for the Section hang List.

1. ECO Cover Sheet Formatted; Bullets end Numbering

2. Section Cover Sheet 11

12 ODI-CO-004 Shift Operations Management System (eSOMS) 06/1712011

3. Section Tag Hang list D. Tags are printed by clicking on the Print Tags button.

Tag print types selections are:

1. Danger Danger Tag

2. Caution Yellow Caution tag (LLRT, ILRT tags)

3. Info Clearance Information Tags (does not print a tag)

4. MOVATS Red and Blue stripes

5. Operating Permit Red and Blue Stripes IX. HANG THE TAGS A. Prior to Hanging Tags, the ECO Hang/Modify Pre-Job Brief portion of the ECO Manipulations Pre-Job Brief and Discussion Items Checklist #5 should be performed. The checklist needs to be maintained with the package for ECO Removal Pre-Job Brief performance.

B. During the ECO Hang/Modify Pre-Job Brief components that will be repositioned should be Red Circle for additional Human Performance measures. X. TAG VERIFICATION for Hanging: first and second verification. A. Click on SECTION TAGS B. Double click on Placement First Verifier or Placement Second Verification for the desired clearance point. This will display a drop down menu. Clicking on a selection from the drop down menu will perform that function and attach the current time, date and your name to the point(s).

1. VERIFY attests to placement of this point only.

2. VERIFY ALL attests to placement of all points for this ECO section.

Note: The un-verify functions will not remove any information once the data has been saved.

3. UN-VERIFY - removes the First Verification information for this point only.

12

13 ODI-CO-004 Shift Operations Management System (eSOMS) 06/1712011

4. N/A VERIFICATION used by an SRO to identify that the Second Verification is not required for this clearance point. WCCS approval to N/A verification when having Danger Tags.

XI. SECTION VERIFICATION: signature update Note: The un-verify is no longer an option. A. Click on SECTION VERIFICATION. B. Click on Verified Executed.

1. Will not permit sign-on unless all required points are second verified or N/A.

C. Double click on the user block and your name will automatically fill in. XII. Sign-on CONTROLLERS and HOLDERS. A. A CONTROLLER (Section holder) must be signed-on the section to permit any HOLDER (Work Order Holder) to sign-on the section. This is a function of the software. B. CONTROLLER (Section Holder).

1. Click on the Controller tab.

a. The sign-on and sign-off buttons at the bottom of the screen will be active (black) provided the Section has been posted and verified.

2. Click SIGN-ON.

3. The controllers name will automatically appear upon signing on.

4. Each discipline must have a controller assigned.

13

14 ODI-CO-004 Shift Operations Management System (eSOMS) 06/1712011

5. Click SAVE button on the tool bar.

14

15 ODI-CO-004 Shift Operations Management System (eSOMS) 06/1712011 C. Holders (Work order holders).

1. Click on the WORK ORDERS.

2. Click a specific work order in the left side of the window.

3. Click SIGN-ON.

4. The holders name will appear after signed on.

5. More than one person can hold (sign-on) a Work Order.

6. Click SAVE button on the tool bar.

D. For individuals who do not have computer access or clearance ID/password a paper copy ECO Holder Form (Form 533) can be opened by the Controller for that discipline. E. HOLDERS (E-MARKER)

1. Controller signs onto the clearance.

2. Controller starts an ECO Holder Form (Form 533) for the specific job and provides this to the WCCS.

3. WCCS signs onto the clearance as a Holder using the following discipline ID/Password.

Mechanical: LMD1 / PTNLMD1 I&C: LMD2/PTNLMD2 Electrical: LMD3 / PTNLMD3 Projects: LMD4 / PTNLMD4 HP: LMD5 I PTNLMD5

4. Engineering and vendors will sign under the discipline work order they are supporting.

15

16 ODI-CO-004 Shift Operations Management System (eSOMS) 06/1712011 XIII. Sign-off CONTROLLERS and HOLDERS. A. All Work Order holders must sign-off the section to permit the applicable discipline CONTROLLER to sign-off the section. This is a software function. B. Holders (Work Order holders).

1. Click on the WORK ORDER.

2. Click a specific work order in the left side of the window.

Note: More than one person can hold (sign-on) a Work Order

3. Click on the appropriate name.

4. Click SIGN-OFF.

5. Click SAVE button on the tool bar.

C. CONTROLLERS (Section Holders).

1. Click on CONTROLLERS.

Note: More than one person can hold (sign-on) a Work Order

2. Click on the appropriate name.

3. Click SIGN-OFF.

4. Click SAVE button on the tool bar.

16

17 ODI-CO-004 Shift Operations Management System (eSOMS) 0611712011 D. All CONTROLLERS must be signed-off of the section to permit release of the section. XIV. SECTION VERIFICATION: signature update; US Removal Authority and print out of the TAGS TO BE REMOVED LIST. A. The Authorization to Release ECO Checklist #4 should be performed and verified complete as part of the Release Section. B. Click SECTION VERIFICATION. Qualified ECO writer should sign: LFormatted: Bullets and Numbering Work Complete after verifying all hard copies are completely filled out.

2) Equipment I/S boundary checked.

3) Click on the ECO Section Tags folder to prepare the release order and verify restoration checklist.

NOTE Special attention should be given to components inside the boundary that were worked, to be verified in the correct position. A separate system walk-down cannot replace the position verification during the ECO release.

4) Release Review, verify proper releasing order (Tags to Remove - - jFormatted: Bullets and Numbering J button) and check for restoration conflicts (Restoration Conflicts button).

For each component, provide the US with two separate verifications of Configuration Control, such as P& ID and proceeding alignment sheet, or notify WCCS if not available. C. US REMOVAL AUTHORITY. NOTE MANUALLY ALIGN PRINTER PRIOR TO NEXT STEP

1. Double click on user block see the next section of this handout if a Restoration Conflict Message is displayed when the sign-on is attempted.

NOTE: Ensure that the computer reflects the desired positions for the components. DO NOT rely on a hard copy printout of the releasing positions for final approval

18 ODI-CO-004 Shift Operations Management System (eSOMS) 06/1712011

2. Within the Tags-to-Remove pop-up window.

Click on AUTHORIZATION REMOVAL. -1jormatted: Bullets and Numbe

1) Will print the Tags-to-Remove List.

2) Will update the database for the US signature for removal authority.

b. If you click on PRINT.

1) Will print an unauthorized (information-only) Tags-to-Remove List.

An unauthorized watermark banner on the printout identifies the unauthorized status.

3. Will NOT update the database for the US signature for removal authority.

XV. REMOVE the tags, TO BE REMOVED FROM LIST. A. Prior to Removing Tags, the Removal Pre-Job Brief portion of the ECO Manipulations Pre-Job Brief and Discussion Items Checklist #5 should be performed. The checklist was to be maintained with the package for performing this step. B. During the ECO Removal Pre-Job Brief components that will be repositioned should be Red Circle for additional Human Performance measures. XVI. US REMOVAL AUTHORITY and Resolution of a Restoration Conflict. A. A restoration conflict occurs when at least one Restoration Configuration specified on the section to be authorized for removal does not agree with the corresponding Placement Configuration for at least one other approved section. Just as with the placement conflict check, the restoration conflict check is done globally, i.e. all ECOs are screened for conflicts. 18

19 ODI-CO-004 Shift Operations Management System (eSOMS) 0611712011 B. A Restoration Conflict pop-up window will be displayed if the US Removal Authority Sign-on is initiated and a restoration conflict exists. C. The actual position conflicts and affected Sections will appear in the pop-up window. Two options are provided:

1. If the Placement Configuration for the specific component, which is in conflict, is acceptable as the Restoration Configuration then click YES for accepting the Placement Configuration.

a. The Restoration Configuration on the section to be authorized for removal will be automatically updated to agree with the (current)

Placement Configuration for the conflicting section(s).

b. The removal process for the Section may proceed. Remember that the components that produced the restoration conflict, will have the up-dated restoration configurations.

2. If the Placement Configuration for the specific component, which is in conflict, is NOT acceptable as the Restoration Configuration then click NO; the removal process for the Section will not be permitted to continue.

XVII. TAG VERIFICATION for Restoration: first and second verification. A. Click on SECTION TAGS B. Double click on Restoration First Verifier or Restoration Second Verification for the desired clearance point. This will display a drop down menu. Clicking on a selection from the drop down menu will perform that function and attach the current time, date and your name to the point(s).

1. VERIFY attests to restoration of this point only.

2. VERIFY ALL attests to restoration of all points for this ECO section.

Note: The UN-VERIFY functions will not remove any information after tags verified removed 19

20 ODI-CO-004 Shift Operations Management System (eSOMS) 06/1712011

3. UN-VERIFY - removes the First Verification information for this point only.

4. UN-VERIFY ALL removes the First Verificationinformation for all points of this ECO section.

5. N/A VERIFICATION used by an SRO to identify that the Second Verification is not required for this clearance point.

XVIII. SECTION VERIFICATION: signature update; Tags Verified Removed A. Click on SECTION VERIFICATION

1. Click on appropriate signature, usually completed by a Qualified ECO writer. This function will not permit sign-on unless all points are first and second verified for restoration or N/A.

B. Click on SIGN ON this will update the appropriate field with the signed-on individuals initial. XIX. Closeout of ECO Number. Return to ECO Manager screen - Formatted: Bullets and Numbering 1 Double -click on ECO number to be closed, this will change the screen to edit mode Click ECO verification tab. Highlight Closed By, sign for ECO closure, this is normally performed by a Qualified ECO writer SRO Return to ECO manager screen Expand the tree view for the ECO to be archived Right click on the section or sections to be archived, and select print.

3) Print Tags with Verification and ECO Section Cover Sheet.

4) Choose Archive.

5) Once all sections have been archived perform step 2, only this time highlight the ECO number.

C. The ECO and all sections associated with that ECO have now been archived. D. Process complete. 20

21 ODI-CO-004 Shift Operations Management System (eSOMS) 0611712011 XX. Using the Drag-n-drop Method to Generate New Clearance Points. A. Display EQUIPMENT MANAGER and SECTION TAGS in a dual-window display: (Tile Vertical).

1. Click on ECO SECTION TAGS.

2. Cascade the Windows by clicking on the cascade button of the tool bar.

3. Click on the ECO MANAGER will move to the front.

a. Minimize the ECO MANAER by clicking on the button in the upper right corner of the ECO MANAGER

4. Open the EQUIPMENT MANAGER by clicking on the key on the tool bar.

5. Close the Search Criteria pop-up window by clicking on the x in the upper right corner of the Search Criteria window.

6. Click on the vertical dual-window display button on the tool bar.

7. Both the ECO SECTION TAGS and EQUIPMENT MANAGER windows should be displayed side by side on the same screen. This will provide for a drag-and-drop of clearance points from the EQUIPMENT MANAGER to the ECO SECTION TAGS.

THE EQUIPMENT MANAGER SEARCH FEATURE.

1. Open Equipment Search by clicking on the Equipment Manager icon (shaped like a key) on the ECO toolbar.

2. Search criteria:

a. Use wild card operator in the Free Form ID Field.

b. Bracket search string using %, i.e. %MOV% will search for all components whose component ID contains MOV 21

22 ODI-CO-004 Shift Operations Management System (eSOMS) 0611712011

c. Use pick-list for system type and unit field:

Click OK to start search. Formatted: Butets and Numbering

3. Search return will be an EQUIPMENT LIST tree.

B. Drag-and-drop from the EQUIPMENT LIST tree to the ECO SECTION TAGS.

1. Click and hold the left button on the desired component and drag to the SECTION TAGS.

2. Release the mouse button to drop.

3. To enter clearance points without drag-and-drop.

a. Click NEW on the bottom of the ECO SECTION TAGS.

b. Enter component ID number in the clearance point field.

c. Press ENTER.

d. A pop-up window will appear if the equipment ID number you have entered is not a valid TEDB data point. Acknowledge the error by clicking the OK button and try again.

4. Close the Equipment Manager window.

5. Restore the Section Tags to a full display page by clicking on the middle of the three icons located at the upper right corner of the Section Tags window.

XXI. Printing necessary Documents

1. Once the ECO has been approved to hang by the US, the ECO coversheet, ECO section Coversheet, Tag HANG list and tags may be printed.

At the ECO manager screen select the ECO that you wish to print fjormatted: Bullets and Numbej] Open the original tag list section 22

23 ODI-CO-004 Shift Operations Management System (eSOMS) 0611712011 Single click on the printer ICON (3 from left on the tool bar)

3. Place a check mark in the box next to the desired items.

4. Click on print.

Attaching Work Orders - Formatted: Bullets and Numbenng Work orders may be attached to an ECO at any time up to the verification signature for Release Review Work Orders should be attached to the ECO after all clearance points have - - Formatted: Bullets and Numbering been added to the ECO and BEFORE the US signs for review. WCCS approval is required for the qualified ECO writer to attach a Work Order after the US review. Verify proper boundaries and required restoration checklist steps for added Work Orders. Work orders are added via the Work Order tab in the ECO section list, - fiormatted: Bullets and Numbering 1 (using add button in the lower left hand side of the screen). This is a pull down menu. Work Order Manager (this should be filled in by the schedulers) - - Jrmatted: Bullets and Numbering If the work order is NOT listed in the pull down menu (see xxii.3 above), it will have to be added by the individual writing the ECO. a) Go to the ECO module screen after login select the Work Order Manager icon (steam shovel). Select Add enter the work order number (NOT WORK REQUEST #). - Formatted: Bullets and Numbering Work order status, this will be used for the LMD,1= Mech., 2=l&C, 3=Elect., etc. Work order opened, date and time automatically. Work order closed filled in when holder signs off as work complete. Equipment ID- self explanatory. Work order description, fill in as suggested boundaries and Work Scope. Click SAVE, repeat steps as necessary to add work orders. The previous steps will take the place of a clearance request 23

24 ODI-CO-004 Shift Operations Management System (eSOMS) 06/17/2011 XXIV. NOMS FOR THE SMIUS A. Change a Password Open NOMS UTILITY module -j Formatted: Bullets and Numbering Single click on the first icon on the button bar (a hand pointing right) Click on the + near User List Scroll down to the desired name (there are duplicates so ensure you choose the one that has a SLID in the user ID and Login ID field) Single click on the 8th ICON from the RIGHT (a key with an F next to it) Enter a new password for the individual, IF this change is for an Operator, the handheld computer will not recognize this new password until the handheld is downloaded or uploaded at least once. B. To add a component (for use in clearances) Open NOMS Equipment Database. * - - -{ Formatted: Bullets and Number Under FILE, choose open Equipment list.

3) When search screen opens up, click cancel, Under FILE choose New Equipment Item.

Fill in the new equipment ID, description, unit, system and plant. - -{ Foimatted: Bullets and Numbering This is the most important part nd 2 u( Under Config. Type choose the

selection) (the first selection is a # -fFmatted: Bullets and Numbering -]

sign). Fill out tag size Large (tags will not print without this selection). E-mail the WCCS with the component added. There are over 100,000 records in the database make sure the component you are adding is !I there BEFORE you add anything. We do&t want this database to become as corrupted as the PCON database. XXV. BOUNDARY MODIFICATIONS AND REVISIONS CAUTION 24 Complete a Clearance Boundary Modification Form (Attachment 4 in O-ADM-212)

25 ODI-CO-004 Shift Operations Management System (eSOMS) 0611712011

1. During an ECO Boundary Modification and/or Revision the ECO Checklists should be used as necessary based on complexity of the ECO and/or WCS discretion. At a minimum, Checklist #5 should be performed and maintained with the package.

2. At times it will be necessary to modify an existing approved ECO, this will be done via a boundary modification. In NOMS the concept of a Boundary Mod is you first create a replica of the ECO, then you modify this replica as needed. If you need to add components, then you add tagging steps to the replica. If you need to shrink your boundary then delete the steps on the replica that are no longer needed. Then when the original ECO is released only those components not kept in the replica will be released.

3. Identify ECO (section) to be modified From ECO manager select the current approved section, this is most probably the Original Tag List.

4. Open the section to be modified in the edit mode.

5. Under section detail tab, click copy to active.

When pop-up screen appears type applicable NEW section number, [FoIr1atted: uIIets and Numbering i.e. BM1, BM2, etc., Hit the Tab key. If this is a NON-Work Stoppage type Boundary Mod VERIFY that all three boxes are checked to copy over the work order #, holders and controllers. Then click copy active ECO section to active. If this is a Work Stoppage Boundary Mod, UN-CHECK the box labeled and Work Order Holders. Then click copy active ECO section to active. Modify the ECO as necessary to accommodate the needs of the requesting department Sign: Prepared (Qualified ECO writer) AFTER REVIEW, Sign: US Review You can now print out a new section cover sheet including any new 25

26 ODI-CO-004 Shift Operations Management System (eSOMS) 06117/2011 tags necessary for the Boundary MOD, IF adding tags you will print out a new Section Tag HANG List for Boundary Mod 1 Complete the necessary section verification signatures up to and including Verified Executed IF this was a Work Stoppage type boundary Mod, Once it is approved AND Verified Executed, the work orders, and Holders can once again be attached to the new section (Boundary Mod). Print out a new section tag HANG list (if necessary).

1. Print out a new Section Cover Sheet and return the control form to the applicable Maintenance disciplines.

IF REMOVING TAGS

6. If the need arises to remove tags in order to perform the Boundary Mod then you will proceed as if you were going to release the active /

original section of the ECO. IF NON Work Stoppage type Boundary Mod, it is now possible for the - jFormatted: Bullets and Numbering Maintenance personnel to sign off the old ECO section and release the necessary tags to complete the Boundary Modification. The new ECO Section is their boundary. Sign all signature blocks associated with an ECO release (of the old Tag List), after the new section approval. Upon the old section release approval by the US (to release unneeded tags) the only tags which will be authorized to release will be the ones that are not incorporated in the Boundary modification. Now it will be necessary to complete the process by performing the administrative requirements.

1) Verify all signatures which were signed in the computer are signed on the hard copy of the section to be released (Original Tag List).

Attach the boundary mod section cover sheet to the original ECO. - - Formatted: Bullets and Numbering Attach the new section tag hang list to the ECO. Attach the boundary mod section tag HANG list (if used) to the original ECO.

6. A Revision is performed in the ECO module exactly like a Boundary Mod and does not require the use of the forms. The difference is that 26

27 ODI-CO-004 Shift Operations Management System (eSOMS) 0611712011 revisions are usually performed on ECOs that no one is an active controller. Since no one owns the ECO there would be no controllers to approve a Boundary Mod. Revisions may be performed on actively held ECOs if it does not alter the ECO boundary, i.e. adding vent or drain rigs, adding an annunciator to the ASL, adding a restoration step, info tags, or no Tag steps. XXVI. Clearance Walkdown Requirements

1) Normally conducted by Operations personnel to be completed by T-3 point in the 13-week scheduling process.

2) Utilize Checklist #4 to conduct the walkdown.

3) May be waived by Operations supervision or other site designated Clearance coordinators for justifiable reason, such as:

i. Emergent Clearance that no reasonable benefit from conducting a walkdown is expected since the Clearance is to be hung in the near future (1-2 days).

ii. Repetitive Clearance, which the needs are well understood, such as bi-monthly diving activities. iii. Resource limitations prevent the ability to complete the walkdown. This should not be the normal practice.

4) If the Clearance Walkdown is waived, document the basis and authorizing supervisor on Checklist # 4 (Clearance Walkdown Checklist)

Comments.

6.0 REFERENCES

/COMMITMENT DOCUMENTS 0-ADM-212.1 - iFormatted: BuNets and NumbeJ PTN PMAI #PMOO-06-015 PTN PMAI #PMOO-07-073

4. CR 07-37638 27

3 9 10 - 500TRWEST 240 00 805 RGo_og1o1 ITO FLORIDA Clii LINE I I TO FLAGAMI LNE TO FURGAMI LINE 41 TO oiioo I I Sb MCGREGOR SUB TO LINDGREN LINE TO LEAEE LINE #1 TO 000IS LINE 43 AlA GALLOWAY TAP. TO DAVIS LINE 42 VIA AILLON TO 000IS LINE #1 I COLLECTOR Boo SCO 8063 f 4 8017 BGR2 CODA ___ 8081 80102 80127 80178 85105 00220 80346 8020 tWAbO 80128 OW75 i5 I BW29 BWSR BWS2 9W114 fr4 88139 IF 89117 80263 I BOB? I [0009 0041 1__.i?.9_ 4 8066 9079 8044 fi- 80120 8G1S1 I1S 1___FF_ RG1291 00332 rI IlRO 0053 8078 8050 80138 00163 80100 00153 80300

                                                                                                                                                                                                                                                                                                             çF1
                                                                                                                                                                                                                                                                                                             )

161 w 8 I fr I OWNS 8018 886813 0080 8 wi frn1 371 80172 08150 80162 OW1R5 00187 BW1S4 3 80142 80165 80177 BW2R1 80246 BW275 rr I OG28 ( GAl15 80152 I I r IO4 8040 8093 8031 0021 80149 80174 80199 00130 00189 00254 I BW52 8888 AW43 8033 NW12R 8M1O6 80141 OWIIR I 80195 OW230 10 09102 j006R 8G76 BOSS BG4S 80148 80198 / MAIN 80176 00100 00188 90212 80297 SOUTAEAST 240 VI BUS 80112 TRANSFORMER I H I NORTHEAST 240 60 BUS I r 8GlO2 80135 j RE TRANSFORMER 4 MAIN 4 STARTUP 3 MAIN 4021 TRANSFORMER 4001 TRANSFORMER 4003 TRANSFORMER 3001 UNTS 1 & 2 TOUNITI TO STARTUP TRANSFORMER MAIN TRANSFGMER COLLECTOR SEE NOTE S NOTE 5 BUS SODS

                                           ?MR                                                                                                                  3 M.R1NSEILERATOR 4 000ILWRY                           1 3 STARTUP TRMNSFORMER 4002                                                                                                                               flf*fl TRANSFORMER 3003 J

1 3C TRANSFORMER 3 AUOILIAAV 3021 TRANSFORMER 3002 EMERGENCY DIESEL EMERGENCY DIESEL GENERATOR EMERGENCY DIESEL GENERATOR EMERGENCY DIESEL GENERATOR GENERATOR 4K4R RKAA 3K4R 3640 AC ,) :8 E ) 4* 38 30 4160 I I 1111! VOLT ISbF)I )o)DI5IO) I_ICIDIOFFICIDICI IIC )o O))fl)Sb ICIDIDI!ICR ROSES ILITI)) 11l IHHI14 II II IIl3 Il III 555WR flK RjSSflSb S S ! I IS )S 45 4150 4160 I (VOLT III (VOLT I I I<4IT SOS I r

             .1 SEE POLISHING DEMINERALIZER AREA                                                                                                    RE ICW                                                                                       1 CCW          L    3C ICW 1                                                                                                                            M 0

C 40 4OO7 4006 SbJ._ 3007 3006 3004 3022+ ,/_/ 3005*3*

                                                                                                                                                                                                       ]                                  3D                              30 4                                 4E(4RR1)

T 444 T )4J 40 4F ) Ji I 4 H 4005 T II I). 1*1 I5 jlifj[,j)I) I) I(1ER I 5 YiLrifiri RATARE I INTMKE S ESEL KOS 0PDEKM 2 2

                                                         &W                                                                                                                         N               44 244                               II       44              40                 N         4            *1             40     fl         480 4803                                    _MM,5                                                                                                                                                                       3A             3D OG4B14K                                                                                                                                                                                                                                                                                      (MOTOR COMA. NON         )4r,6           40       ONIT    ATM EDO 48         SWITCH        AITAL   VITAL   VITAL  EDO 4* NON         VITAL SWITER         CORP.      606                  I      #3      NON        UNIT      SWITCR      NON           EDO            VITAL          VITML     VITAL       SWITCA     NON            VITAL         CONTROL COOLING     VITAL                    POLISRINO     4       AITAL               GEAR                                         AITAL            GEAR        COOLING       VITAL            0<I,_POLISH NO     VITAL         3         GEAR      VITAL       30039                                                  GEAR        VITAL                      EERTER I 5540<5                                                                                                                            WATER                        (yy>OAMSEfl_

WATER FUEL I 5545) DEM SEW AMRER REACTOR BLOD. ROOM FOEL REACTOR BLDG. TORBINE ROOM FOEL REACTOR 98900 ROOM WASTE BLDG. WASTE FOEL REACTOR ROOM 3* TORRINE AREA AREA ALIZER TAP AREA UREA 48 AREA AREA AREA AREA 40 AREA AREA TAP 38 DISPOSAL AREA DISPOSAL AREA AREA 900* AREA <//,)) UREA UREA Sb F I IN PLACE

REFER TO BREAKLR LST OWG 5510 EB55 FOR ADDITIONAL BREAKERS AND LOADS RE 000NDONED IN PLACE 3E F F WATER RODWOSTE LEADS LIFTED I55o1 LEADS LIFTED TREATMENT BUILDING EAD FII E: S610TE 1591 SR I OWC RADRASTE BLDG. INTAKE INTAKE AREA PLANT NOTES: AREA TORKEV POINT NWCLEMR ONIES 3 a 4 POD I SEE 5A1OE1S22 FOR ADDITIONAL INFORMATION RAW NO SUU8RR 94S 2 DELETED 3 DELEIEO

4) 4900 TIELINE BETWEEN LOAD CENTERS 3E & 4E IS

TEMPORARY MAINTENANCE OPERATING DIAGRAM 5610TE1591 TIE MND ITS OSE IS COSTROLLED 80 PROCEDURE 3/4 OP 006. PL ELECTRICAL

5) NOTIFY NPS PRIOR TO COMMENCIND WORK ON THIS SVSTEM. DISTRIBUTION 911181 1 62 3 4 4L s L

8 0 - SOUTHWEST 200 KU BUS 8Gi868G1 61 ITO FLORIDA CITH LNE TO FLAGAMI LINE 864196 I TO FL060RI LINE ff1 I I To J I 010 MEGRESOR SUM TO LINTGREN LINE TO LKUEE ONE ff1 TO TOVIS LINE ff3 VA GULLONAY TAP. TO DAUIS LINE ff2 VA K LLLNN I COLLECTOR TO 000IS LINE ff1 BUS 5CD 8062 8617 0042 8681 86178 80228 RG346 t 8069 ( t 8R1U4 80128 WRITS IF owoo [ 8A54 : RWH2

1 80263 IT I I 8087 8041 8060 ___ft 1 8044 80185 80126 80151 AGI29 80332 8689

( 1G57 125 IO3 1lA 640140 8653 8078 8056 80101 80138 86103 XG16S 80153 80300 8W161 I WINOS 8WRO 8808 88137 I RA1SVI 80175 80154 SWI55I 8W2O1 8W275 8028 I 8677 8G19 8080 86172 80162 86187 80142 86177 8G245 I L 86115 86152 8040 8693 8031 8021 86149 86174 80109 80130 86189 R025R 8WS2 IT-1 owsa WW43 O OW33 8W124 881869 8W1181 1 BA119SI 10 UNIT 2 8076 8055 8045 SS14R 80198 ( RAIN 86176 86106 80188 80212 86297 86601 SOUTHEAST 240 ITO 905 SW1 12 H H NORTWEAST 240 TRANSFORMER 4C TRANSFOWMEF 4 MRIN 4 STARTUP H 50100 I; 3 ARIA 80136 a r ( 4021 TRRNSITRMER Hoot -y- TRANSFOAMER 40 3801 p TRUNSEORMER UNITS 1 N TO UNIT 1 TO STARTUP TRANSFORMER MAIN TRRNSFUMER COLLECTOR SEE NOTE NOTE S BUS SASS 4 MRIN GENERATOR 3 RAIN GENERATOR 774 Mw 22 KU 4 OUXILON 774 lAOS 22 AT 3 STORTUP TRANSFORMER 4X02 TRUNSFORWER 3003

                                                                                                          --J-*

3C 3 OUUILIORV TRANSFGROER 3802 iTI I T EMERSENEY DIESEL EMERGENCY OIESEL GENERATOR EAERGENEV DIESEL GENERATOR EMERGENCY DIESEL GENERATOR GENERATOR 0448 OKRA 3K48 36440 H RE 48 ) $ 40 ) a) THE ) I *38 j ) 34 4160 10 6 a$ CT UOLT I) I I I a)a) )g) TT° IoaoI TO LA I ISaI.a)rIa

                     ,_                                                                                                        )              )               ITI I 10                 I IIi I I                                  1T)I IS:t)GiT )                                                                                                                               RUSE5 Iai0IC )                )5 )_                                    1)

II 15 I II I$II III IIII IiAI2 1 THO 0150 O 3

                                                                                                                                                                                                                                                                                      )T I )T.           4160 I  I          400LT                                                                                       I    I                    lOOT SOS 1                                                                                                           BOS                                                                                        T ig)5 EEW          L     3E ION icE0]

T!L A OREAj 0 DlM 22 TSR 1 , 64 c 1 L ,,,./TcaEITRLaZER 3ROS 3R04 48 T 1i 38 1 3C O 450 I +/-T48 F 4 T * :I .3:1 UGLT T 48 T 4

                                                                                              .                                                                                                                                                                                                                                                                    A aIaIII                 aIaI0                              15                                                                                                       LOAS CENTER IOTOK OICSEL                                  L ADS L                                    L 0443       4G              4B4K                                                                                                                                                                        ji5S                                  3O             5 MOTOR CONY     NON          )aO[/91              ffA      UNIT    NON EOG 48         SWITCH      VITRL       VITAL   OTAL   ETG 40 NON       UITAL  SWITCH        EGIAP.       NON                   I         is        NON        UNIT     SRITEU       NON           EGG              UITAL          AITAL     UITAL       SWITCH   NON       VITAL        CONTROL ETOLINS     OITAL         )i)4,Z4        POLISHING      4      VITAL               GEAR                                           SITUL            GEAR        COOLING        UITAL                       PULINVINO      UITRL       3        GEAR        AITUL       30430                                                    GEAR      VITAL                CENTER RATER    FOAL I                  OEMINER OWNER REACTOR SLOG.              ROOM                  FUEL REACTOR BLDG           TURBINE       ROOM         OUTER                          ,y6A0alIE8 I 5){CJ                                                                                                                                                POEL                                     REACTOR AMBER        ROOM        WASTE         SLOG.           WASTE           FUEL     REACTOR      ROOM 30        TARRUE AREA    AREA                             ALIZER      TAP    AREA      ABEA        45                   AREA    UREA     AREA        AREA          4A          AREA          AREA                                       AREA      VAR          38     SISPOSAL        AREA        OIVPOOAL                       OREA                       AREA

(//A3) XREA AREA AREA IN PLACE

REFER TO BREAKER LIST 000 SOlOAASS FOR AOOITIUNRL ARERVERS ANU L090S NB4NOTNEUUS PLACE WATER RROTLASTE LEAOS LIFOEU

_!h TREATMENT BUILDING EnS FIl F: SAl 08F TONI NA I NOV CSS ROTWANTE RCTG INTAKE INTAKE AREA PLANT NOTESa TURKEY POINT NOCLEAR ONITS 3 & POD 1 SEE 561OEIS22 FOR ADDITIONAL INFTRMRTITN 2 TELETED DR4RIIIANLH*RER NUN 3 DELETED

4) RSOU TIELINE SETSNEEN LOXO CENTERS 3E IN 4E IS A TEMPORARY MOINTENONCE OPERATING DIAGRAM 5610TE1591 TIE AND ITS USE IS CONTROLLED MY PROCEDURE 3/4UPTOO. PPL ELECTRICAL RAN

5) NOT Fl BPS PRIOR TO COMMENCING WURK UN TRIO SYSTEM. DISTRIBUTION 44661 1 62 L 3 - L I A 1

BREAKER LIST PAGENO. INPUT DATA FILE PTP.BL.44 LP34 / LP34A (UNIT 3 4160V SWGR. RM.) (3P04) CODE HEATER BREAKER SCHEMATIC EQUIP. NO. BREAKER LOCATION CKT OESC EQUIPMENT AND OR LOCATION NUMBER PNL SCHED. 25 E200 3B05 FEED F1M MCC 3A (BKR 30521) VIA 32(034 LP34 MAIN E230 DUP064 E307--7 25 E30354 MTR HTR REACTOR COOLANT PP 3A(3P200A); NOTE: SEE BKR 3AAO1 LP34-5 E334 DUP064 E3077 25 E-303-54 Nfl NTR REACTOR COOLANT PP 3B(3P200B); NOTE: SEE BKR 3ABO1 LP34-S E337 DUP064 E3O77 25 E30354 MTR HTR CIRC WTR PP 3A1 (3P7A) NOTE: SEE BKR 3AA16 LP3411 E336 OUPO64 E3077 25 E303-54 MTR NTR REACTOR COOLANT PP 3C (3P200C); NOTE: SEE BHE 3A306 LP3412 E337 DUP064 E307--7 25 E30354 MTR HTR CIRC WTR PP 3A2 (3P7C); NOTE: SEE BKR 3AA18 LP3417 E336 DUP064 E3O77 25 E303-54 MTR NTR CIRC WTR PP 3B1 (3P7B); NOTE: SEE BKE 3A316 LP34-18 E339 DUP064 E3O77 25 E30354 SPC HTR 5KV SWGR 3A CUB 18 NTRS LP3423 E336 OUP-064 25 E30354 MTR HTR CIRC WTR PP 3B2 (3P70); NOTE: SEE BKR 3AB18 LP34-24 E339 OUP064 E3077 25 E30354 SPARE LP3429 E230 DUP064 E3077 25 E-3O3-54 SPC HTR 5KV SWGR 3B CUB 18HTS LP34-30 E339 OUP064 E3077 25 E303-54 MTR NTR SUM CAN FEED PP 3A(3P1A); NOTE: SEE BKE 3AA03 LP34-33 E334 DUPO64 E3077 CODES: NAB-NOT AS BUILT TURKEY POINT PLANT UNITS 3 & 4 REV. 332 RES-RESERVED BREAKER LIST 5610E--855 SH.44

BREAKER LIST PAGENO. 2 INPUT DATA FILE PTP.BL.44 LP34 / LP34A (UNIT 3 4160V SWGR. 514.) (3P04) CODE HEATER BREAKER SCHEMATIC EQUIP. NO. BREAKER LOCATION CKT DESC EQUIPMENT AND OR LOCATION NUMBER PNL SCHED. 25 SPARE LP3434 NOTE: SEE BKR 3AB03 25 E30354 MTR HTR SWGR 3AA02 & 3AB05 FANS LP3435 E334 DUP064 E3077 25 E30354 MTR HTR SWGR 3AB02 & 3AA05 FANS LP3436 E337 DUP064 E3077 25 E30354 MTR HTR INTAKE COOLING PP 3A (3P9A); NOTE: SEE SEA 3AA19 LP3437 E336 DUP064 E3077 25 E303-54 MTR HTR INTAKE COOLING PP 35 (3P9B); NOTE: SEE SEA 3AB17 LP34-38 E339 DUP064 E3077 25 E-303-54 SPC HTR MISCELLANEOUS CONTROL DEVICES IN RELAY RACK LP34-39 E468 3QR47; NOTE: SEE BKRS 3D0120, 3P0610, LP3821 DUP064 E3O77 254 SPARE (PC/M 87265) LP3440 25 E30354 MTR HTR CONDENSATE PP 3A(3P6A); NOTE: SEE SEA 3AA21 LP34-41 E336 DUP064 E3077 25 E303-54 MTR HTR CONDENSATE PP 3B (3P65) LP3442 E339 DUP064 E3077 25 E-30354 3P04 FEED FROM LP34 LP34A MAIN E23O DUP064 E3078 25 E30354 MTR HTR HTR DRAIN PP 3A (3P3A); NOTE: SEE SEA 3AA07 LP34A-43 E334 DUP064 E3078 504 E30354 SPARE (PC/M 04150) LP34A44 E3078 CODES: NAB-NOT AS BUILT TURKEY POINT PLANT UNITS 3 & 4 REV. 332 RES-RESERVED BREAKER LIST 561OE855 SH.44

BREAKER LIST PAGENO. 3 INPUT DATA FILE PTP.BL.44 LP34 / LP34A (UNIT 3 4160V SWGR. RN.) (3P04) CODE HEATER BREAKER SCHEMATIC EQUIP. NO. BREAKER LOCATION CKT DESC EQUIPMENT AND OR LOCATION NUMBER PNL SCHED. 7 E-303-54 MTR HTR TURB PLANT COOLING WTR PP 3A(3P11A); NOTE: SEE BKR 3AA11 LP34A-45 E335 E3078 7 E-303-54 MTR HTR TUEB PLANT COOLING WTR PP 3B (3P11B) LP34A-46 E338 NOTE: SEE BKR 3AB11 E3078 7 E-303-54 MTR HTR COMPONENT COOLING WTR PP 3A (3P211A) LP34A-47 E-335 NOTE: SEE BKR 3AA12 E3078 7 E-303-54 MTR HTR COMPONENT COOLING WTR PP 3B (3P211B) LP34A-48 E-338 NOTE: SEE BER 3RB13 E3078 7 E30354 MTR HTR SAFETY INJECTION PP 3A (3P215A); NOTE: SEE HER 3AA13 LP34A-49 E335 E3078 7 E-303-54 MTR HTR SAFETY INJECTION PP 3B (3P215B); NOTE: SEE BKR 3AB12 LP34A-50 E338 E3078 7 E30354 MTR HTR TURB AUX OIL PP; NOTE: SEE BKR 30312 LP34A-51 E3 41 E3078 252 SPARE (PC/N 87265) LP34A52 232 E-303-54 MTR HTR SPENT FUEL PIT PP (3P212A & B) NOTE: SEE BKR 30309 (PC/M 89-272) LP34A53 E341 5613E28SH28J 379 E30354 SPC HTR EMERGENCY LOAD SEQUENCER-3A(3C23A) (CRN-E-15307 PC/M 95-099) LP34A-54 E342 NOTE: SEE BKRS 30014, 300129, 3P0715 7 E30354 MTR HTR CHARGING PP 3A (3P201A); NOTE: SEE BKR 30105 LP34A55 E340 E-3078 7 E-303-54 MTR HTR CHARGING PP 3B (3P201B); NOTE: SEE BKR 30203 LP34A56 E340 E3078 CODES: NAB-NOT AS BUILT TURKEY POINT PLANT UNITS 3 & 4 REV. 332 RES-RESERVED BREAKER LIST 5610E855 SH.44

BREAKER LIST PAGENO. 4 INPUT DATA FILE PTP.BL.44 LP34 / LP34A (UNIT 3 4160V SWGR. PM.) (3P04) CODE NEATER BREAKER SCHEMATIC EQUIP. NO. BREAKER LOCATION CKT DESC EQUIPMENT AND OR LOCATION NUMBER PNL SCHED. 7 E303-54 MTR HTR CONTAIN SPRAY PP 3A (3P214A); NOTE: SEE BRA 30109 LP34A57 E340 E3078 517 E-30354 MTR HTR CONTAIN SPRAY PP 3B (3P214B) CRN-E-16957(PC/M 03-106) LP34A-58 E341 NOTE: SEE BRA 30403 DUP064 E3078 502 E30354 MTR HTR CRD MG SET 3A (3S6) NOTE: SEE BRK 30108 (PC/M 04117) LP34A59 E340 E3078 502 E30354 MTR HTR CR1) MG SET 3B (3S7) ; NOTE: SEE BRA 30401 (PC/M 04117) LP34A60 E341 E3078 7 E-3O354 MTR HTR TURNING GEAR OIL PP (3P31); NOTE: SEE BRA 30510 LP34A61 E345 E3078 348 E-303-54 MTR HTR EMERG BEARING OIL PP (3P30); NOTE: SEE BRA 31)3127 LP34A-62 E357 (PC/M 94054 CRNE15010) E3078 7 E-303-54 MTR HTR TURNING GEAR DRIVE 3A (3T08); NOTE: SEE BRA 30512 LP34A-63 E345 E3078 387 E30354 PER DEWPOINT METER MI36430 (PC/M 93108) LP34A64 E1279 E27, 26E 7 E30354 MTR HTR AIR SIDE SEAL OIL PP (3P36) LP34A-65 E-345 NOTE:SEE BRA 30505 E3078 7 E-30354 MTR HTR CONDENSATE TRANSFER PP 3A (3P5) LP34A-66 E346 NOTE: SE BRA 30574 E3078 7 E-3O3-54 MTR HTR NORMAL CONTAINMENT COOLER 3A (3V1A) LP34A-67 E345 NOTE: SEE BRA 30518 E3078 366 E30354 MTR HTR CHARGING PP 3C (3P201C) (CRNE15198 PC/M 95031) LP34A68 E-341 NOTE: SEE BRA 35008 E3078 CODES: NAB-NOT AS BUILT TURKEY POINT PLANT UNITS 3 & 4 REV. 332 PEE-RESERVED BREAKER LIST 561OE855 SH.44

BREAKER LIST PAGENO. 5 INPUT DATA FILE PTP.BL.44 LP34 / LP34A (UNIT 3 4160V SWGR. RN.) (3P04) CODE HEATER BREAKER SCHEMATIC EQUIP. NO. BREAKER LOCATION CKT DESC EQUIPMENT AND OR LOCATION NUMBER PNL SCHED. 7 E30354 MTR HTR RESIDUAL NT REMOVAL PP 3A (3P210A) LP34A69 E336 NOTE: SEE BER 3AA15 E3078 7 E-303-54 MTR HTR RESIDUAL NT REMOVAL PP 3B (3P210B) LP34A-7O E-339 NOTE: SEE BKR 3AB15 E3078 7 E30354 SPC NTR 480V LC 3A(3B01) & 3B(3B02) SPACE HTRS LP34A71 E3078 155 E-303-54 HTR/XDR 480V LC 3C(3B03) SPACE HTRS/PRESSURIEER AC CONTROLLER PWR LP34A-72 METERING TRANSDUCER & 480V LC 3D(3B04) SPACE NTRS. (PC/N 87-011) E3078 12 SPARE LP34A73 379 E-343 SPC HTR ENEROENCY LOAD SEQUENCER PANEL3B (3C23B) (CRNE-15307 PC/N 95-099) LP34A74 E30354 NOTE: SEE BREAKERS 3D235, 3D239, 3P0813 7 PWR RAD-3-6417 WIDE RANGE NOBLE GAS RADIATION MONITOR LP34A-75 E-151 & AIR EJECTOR PCN 80131 7 SPARE LP34A-76 340 E-30354 PWR CATHODIC PROT RECT 3A1 (3E7A1) INLET PANEL 3C475 (PC/N 93-023) LP34A77 E-51 CONDENSER WATERBOX 3AN E40 340 E-303-54 PWR CATHODIC PROT RECT 3A1 (3E7A3) OUTLET PANEL 3C477 (PC/N 93-023) LP34A78 E-55 CONDENSER WATERBOX 3AN E-40 340 E30354 PWR CATHODIC PROT RECT 3B1 (3E7A2) INLET PANEL 3C479 (PC/N 93023) LP34A79 E-51 CONDENSER WATERBOE 3BN E-40 340 E-30354 PWR CATHODIC PROT RECT 3B1 (3E7A4) OUTLET PANEL 3C481 (PC/N 93-023) LP34A80 E-55 CONDENSER WATERBOE 3BN E40 CODES: NAB-NOT AS BUILT TURKEY POINT PLANT UNITS 3 & 4 REV. 332 RES-RESERVED BREAKER LIST 5610E855 SM.44

BREAKER LIST PAGENO. 6 INPUT DATA FILE PTP.BL.44 LP34 / LP34A (UNIT 3 4160V SWGR. NM.) (3P04) CODE NEATER BREAKER SCHEMATIC EQUIP. NO. BREAKER LOCATION CKT DESC EQUIPMENT AND OR LOCATION NUMBER PNL SCHED. 340 E30354 PWR CATHODIC PROT RECT 3A2 (3E7B1) INLET PANEL 3C483 (PC/M 93-023) LP34A81 E-51 CONDENSER WATERBOX 3A.S E-40 340 E-30354 PWR CATHODIC PROT RECT 3A2 (3E7B3) OUTLET PANEL 3C485 (PC/N 93023) LP34A-82 E-55 CONDENSER WATERBOX 3AS E40 340 E30354 PNR CATHODIC PROT BECT 3B2 (3E7B2) INLET PANEL 3C487 (PC/N 93023) LP34A83 E-153 CONDENSER WATERBOX 3B5 E-40 340 E-30354 PHA CATHODIC PROT RECT 3B2 (3E7B4) OUTLET PANEL 3C489 (PC/N 93-023) LP34A-84 E-55 CONDENSER WATERBOX 3B5 E40 CODES: NAB-NOT AS BUILT TURKEY POINT PLANT UNITS 3 & 4 REV. 332 BES-RESERVED BREAKER LIST 5610E855 SH.44

Clearance Section Coversheet Turkey Point Nuclear Plant Clearance: 3-,t0-08-002 Focus on Safety First Clearance Section: 3P211A 3A CCW PUMP OVERHAUL 11/17/2011 12:5 Component to be Worked: .

  °211A                                                               . ..
 .DMPONENT COOLINGPUMPA               .    .

202 _COMPONENT COOLING PUMP ROQM Reason for SM or Revision : Reason for Clearance OVERHAUL PUMP MOTOR . . REPLACE PUMP BEARINGS . Hazards Electrical Hazard Pressurized Piping . Rotating Equipment CCW contains MOLYBDATES POSSIBLE CONTAMINATION Special Instructions: Refer to TECH SPEC 3.7.2 Verify 3B AND/OR 3C CCW pump running PRIOR TO HANGING ECO Align 3D 4kV bus over to 3A 4kV bus if desired THIS ECO IS FULL ISOLATION/VENT AND DRAIN ... PRIOR TO HANGING EGO, VERIFY EMPTY BARRELS STAGED TO RECEIVE CONTAMINATEb.WATER. Clearance Section Attributes: .. . Attribute :. Attribute Description . Value idgout Type .

;afet, Related                                        .               .         ..                  ..                              .

Risk Significant : rech Spec .. Load Threatening . ... Load Limiting . .. . .. Requested By .. . . ystem Number ,.

ontainment Integrity . . . ...

Work Order(s) List lumber I Equipment II Description ., .. 36011333-01 3 - 3P211A / COMPONENT COOLING PUMP 3A MOTOR (BREAKER #3AA12) / 3P211A PUMP MOTOR/SWAP SPARE 3 3P211A 10005363-01 - 3P211A I COMPONENT COOLING PUMP A / REPLACE PUMP BEARINGS VIB INCREASING 1 3P211A arance Section Verification Prepared Status 4 . .J . .Descriptión .. . .

                                                                                                                 .,.       ..Name                           Verification Date
                           .          prepared                                                  .      FUNK, DAVID                                       p9/02/2010 14:11 Page 1 of2

Clearance Section Coversheet Turkey Point Nuclear Plant Cleara47ce: 3-10-08-002 Focus on Safety First Clearance Section: 3P211A 3A CCW PUMP OVERHAUL 11/17/2011 12:50 [ Reviewed Status Descriptión Name Verification Date Reviewed . .... D 2 Review MD 2 Review LMD 3 Review MD 3 Review . Engineering review Engineering review pproved by SRO pprovedby SRO MCKEE, JOE 9/02/2010 15 14 Reviewed by NPS .. Reviéwedby NPS* .. FLYNN, RANDYE . 9/02/2010 16:33 (erified Executed : rifid Eecuted . : BLOOM, SEAN 9/02/2010 21:22 Release Review By : . .: eIease Review By . fv4y ED ..... 9/02/2010 21:23 Release Authorized By f . Rélase Autholizéd By :. : BLOOM, SEAN. 9J02/2010 21:24 ags Verif. Removed By gVerif..Rembved By BLOOM, SEAN .. 9/02/2010 21:25 EOOS log Updated if required EOOS log Updated if required . Documen Document Document Description . Document Fileflame Order Number . . .. 1 1 5613-M-3030_SHT Lpdf j:\pcc\Procedures\PDF\!DrawinMaters\!PODs\PID\S6I3\5613-M-3O3OSHT 1.pdf . . : 2 2 FECH SPEC.pdf j:\pcc\Procedures\PDF\Tedi Spec\TECH.SPEC.pdf 3 3 3-OP-030.pdf j:\pcc\Procedures\PDF\OP\3\3bP-O3O\3-OP-O3O.pdf 4 4 [77.pdf j :\pcc\Procedures\PDF\!DawingMasters\!PODs\Breaker List\4160V Switchgear\77.pdf .*:* Page 2of2

Clearance St7n Tag List ThIs form is only for Clearan VALKDOWN verification Clearance: 3-.J-08-002 Clearance Section: 3P211A 3A CCW PUMP OVERHAUL 11/17/2011 12:50 fag Equipment Ver Pla Placement Place. 1st Place. 2nd Ver Rest Rest. Config. Rest. 1st Rest. 2nd fype Req Seq Configuration Verif Verif Req Seq *As Left (If Duff.) Verif Verif Equipment Description Date/Time Date/Time Date/Time Serial No.

Equipment Location
Date/Time Notes
Notes No Tag 3P211A SC 1 PERFORM PLACE, ALAN L -

N/A PLACE, ALAN L C 26 Not Verified N/A BLOOM, SEAN 16:38 09/02/2010 16:38

IF DESIRED, BLOOM, SEAN 09/02/2010 21:0 260 COMPONENT COOLING ALIGN 3D 4KV LIGN 3D 4KV BUS 09/02/2010 21:30 PUMP A BUS TO 3A 4KV BACK TO NORMAL not required at this
202 BUS 3B 4KV BUS time COOLING PUMP ROOM nfo tag P211A-CONTROL SWITCH SC 2 HANG TAG RICARDO, DANNY SC 25 VOODWARD, I 09/01/2010 20:10 ABRIEL 09/05/2010 224 3A CCW PP CONTROL 21:57 WITCH VPB 3C05 CONTROL ROOM VERTICAL ANEL Danger AA12 V 3 RACKED OUT PLUS RICARDO, DANNY LUBERT, JONATHAN IV 24 LUBERT, JONATHAN ANOVSKY, PETER 20:10 19/01/2010 20:50 09/05/2010 10:39 09/05/2010 10:2 225 A COMPONENT COOLI TER PUMP (3P211A) 68 V SWITCHG OM Danger 4A-47 .V 4 )FF PLUS RICARDO, DANNY LUBERT, JONATHAN IV 23 LUBERT, JONATHAN FRITCH, JOHN B 20:10 )9/01/2010 20:51 09/05/2010 10:39 09/05/2010 10:2 226
MTR HTR-COMPONENT OOLXNG WATER PUMP 3 211.A) 68 V SWITCIIG tIM Danger -703A IV 5 DLOSE PLUS RICARDO, DANNY LUBERT, JONATHAN IV 22 WOODWARD, RIPPLETT, RO1 20:10 )9/01/2010 20:51 ABRIEL 09/05/2010 09/05/2010 21:17 227
STOP VLV FOR CCW PUMP A 21:21 DISC[l
202 OOLING PUMP ROOM Danger 3-lOlA IV 6 CLOSE PLUS MACHADO, CHRIS RIPPLETT, RON IV 21 V000WARD, RIPPLETT, RON 09/02/2010 17:37 09/02/2010 17:52 GABRIEL 09/05/2010 09/05/2010 21:47 261
ISO VLV TO CCW PUMP A 21:21 IN LET
202 COOLING PUMP ROOM No Tag 3-703F-HOSE IV 7 REMOVE CAP AND MACHADO, CHRIS RIPPLETT, RON IV 20 VOODWARD, RIPPLETT, RON HOSE 09/02/2010 17:37 09/02/2010 17:52
INFORM NWE TO ABRIEL 09/05/2010 09/05/2010 21:47 262
VENT VLV ON CCW PUMP A DISPOSE OF FULL 21:21 CASING HOSE
INITIALLY ROUTE BARRELS.
202 _COMPONENT HOSE TO BARREL COOLING PUMP ROOM FOR COLLECTION OF CONTAMINATED, MOLYBDATED WATER UNTIL PUMP VENTED.

IS Page 1 of 4

Clearance S( n Tag List This form is only for Clearan VALKDOWN verification Clearance: 3-.U-08-002 Clearance Section: 3P211A 3A CCW PUMP OVERHAUL 11/17/201.112:50 rag Equipment Ver Pta Placement Place. 1st Place. 2nd Ver Rest Rest. Config. Rest. 1st Rest. 2nd rype Req Seq Configuration Verif Verif Req Seq *As Left (If Duff.) Verif Verif Equipment Description Date/Time Date/Time Date/Time Serial No.

Equipment Location
Date/Time Notes
Notes No Tag 3-703F-THROTTLE SC 8 FHROTTLE -

Not Hung BLOOM, - Not Hung BLOOM, - NV 19 N/A Not Verified N/A BLOOM, SEAN 09/02/2010 21:21SEAN 09/02/2010 21:22 BLOOM, SEAN 09/02/2010 21:24 263

VENT VLV ON CCW PUMP A
DO NOT EXCEED Not hung. WiN be rolled to caution tags in 09/02/2010 21:24 not hung ASING HOSE DRAIN SYSTEM rolled to caution tags in rev 1 not hung
202 APACITY. USE Rev 1 OOLING PUMP ROOM BARRELS FOR DRAINING.

Danger 3-703F IV 9 OPEN - Not Hung BLOOM, - Not Hung BLOOM, IV - - 18 CLOSED Not Verified N/A BLOOM, SEAN 09/02/2010 21:21SEAN 09/02/2010 21:22 BLOOM, SEAN 09/02/2010 21:24 264

VENT VLV ON CCW PUMP A Not hung. Will be rolled to caution tags in 09/02/2010 21:24 not hung ASING rolled to caution tags in rev 1 not hung
202 Rev 1 DOOUNG PUMP ROOM No Tag 3-702D-HOSE SC 10 REM CAP INS HOSE MACHADO, CHRIS SC 17 VOODWARD, 17:37 GABRIEL 09/05/2010 265
DRAIN VLV FOR CCW PUMP
ROUTE HOSE TO 21:21 DISCH BARREL FOR
202 COLLECTION OF COOLING PUMP ROOM CONTAMINATED, MOLYBDATED VATER No Tag L-702D-THROTTLE SC 11 El-IROTTLE -

Not Hung BLOOM, - Not Hung BLOOM, NV 16 N/A Not Verified - N/A BLOOM, AN SEAN 09/02/2010 21:2i SEAN 09/02/2010 21:22 BLOOM, SEAN 09/02/2010 21:24 266

DRAIN VLV FOR CCW PUMP
DO NOT EXCEED Not hung. Will be rolled to caution tags in 09/02/2010 21:24 not hung DISCH DRAIN SYSTEM rolled to caution tags in rev 1 not hung
COMPONEN T COOLING CAPACITY. USE Rev 1 PUMP ROOM BARRELS FOR DRAINING.

Danger 3-702D V 12 )PEN Not Hung- BLOOM, - Not Hung BLOOM, V 15 LOSED AND Not Verified - - N/A BLOOM, SEAN 09/02/2010 21:2 SEAN 09/02/2010 21:22 APPED BLOOM, SEAN 9/02/2010 21:24 267

DRAIN VLV FOR CCW PUMP Not hung. Will be rolled to caution tags in 09/02/2010 21:24 not hung DISCH rolled to caution tags in rev 1 not hung
202 Rev 1 COOLING PUMP ROOM Restorati 3AA12-GROUND NV 13 V 14 ;0NzALEz, SCHILLING, MIHAEL Checklist RAYMOND 9/05/2010 09:46 4.16KV BKR TO CCW PUMP 9/05/2010 09:44 229 (P211A) 368 V SWITCHGEAR ROOM Restorati 3-1011 NV 1 v. 13 VOODWARD, rnPPLErr, RO

hecklist ABRIEL 09/05/2010 9/05/2010 21:48 TEST VLV FOR IST-3-45 21:21 268 ND IST-4-33 COMP OOLING PMP A DISCHARGE

202 TMf DI IMD DflflM Pag2of4

Clearance S( n Tag List This form is only for Clearan YALKDOWN verification Clearance: 3-.L 1-O8-OO2 Clearance Section: 3P211A 3A CCW PUMP OVERHAUL 11/17/2O1t 12:50 rag Equipment Ver Pla Placement Place. 1st Place. 2nd Ver Rest Rest. Config. Rest. 1st Rest. 2nd rype Req Seq onfiguration Verif Verif Req Seq *As Left (If Duff.) Verif Verif

Equipment Description Date/Time Date/Time Date/Time Date/Time Serial No.
Equipment Location
Notes
Notes Restorat 3-704F NV 15 .. . V. . -. -.-..- - . - - -. - -.- ..... . ...

12 V000WARD,. RIPPLETT, RON Checklist ,ABRIEL 09/05/2010 09/05/2010 21 l8

ROOT. VLVT0 ZN-SERVICE 21:21 269, . . WEST IND AT DISCH oF.ccW PLiMPA H
202 OMPONENT OOLING PUMP ROOM Restorati 3704E :.

f4J 16 ,L:c::., IV 11 . VOODWAkO, RIPPLET1 RON hecklist ,ABRIEL 09/0512010 9/05/2010 21 48 ROOT VLV TO PI-640A AT 21 21 270 DISCH OF CW PUMP A

202 COMPONENT OOLXNG PUMP ROOM Restoati 3-704A NV 17 IV 10 VOODWARD RIPPLETr, RON Checklist GABRIEL 09/05/2010 09/05/2010 21 I8 ISO VLV TOPRESS AND 1ST 2i21.

271 NDS ATCCW..PUMP A DISCH..

202 OOLING PUMP ROOM

                                                                                               .:,.,c....                                  .

Restorati 3-703K NV, 18 . . .. V 9. -. . VOODWARD, . .. EIPPLEfl RON Dheckhst GABRIEL 09/05/2010 09/05/2010 21 I8

                  *:ISLVFORCCWPUMPA 21:21 272            . DISCHARGE VENT LINE                 ,:

202COMPONENT OOLING PUMP ROOM Restoratti 3-703) NV 19 IV 8 VOODWARD RIPPLE1T, RON

heckhst ABRIEL 09105/2010 9/05/2010 21 418

Iso vLvF0R CCW PUMP A 21:21..

273. . . DIsCHARGE.vENr LINE

                  *202 COOLIN PUMP ROOM,:..

Restorati 3-701M IV VOODWARD, RIPPLETT, ROIl Dhecklist - . . . . .. ., ABRIEL 09/05/2010. 9/05/2010 21:48,:.

                  *TEsTvLvToc.JpuMPA.                                                                                                                                                                 21:21  ....:

274 SUcTION

202

OOLING PUMP RooM Restorath 3 701D NV 21 [V 6 VQODWARb, RIPPLETT, ROJ.

Checklist ABRIEL 09/05/2010 J9/05/20102148 aoOTVLVTOPRESSXND& 1:21 275 ST AT CCW PUMP A SUCTION

202: COMPONENT...

OOLING PUMP ROOM Page3of4

Clearance Y (on Tag List This form is only for Clearar WALKOOWN verification Clearance: .,. 0-08-002 Clearance Section: 3P211A 3A CCW PUMP OVERHAUL 11/17/2011 12:58 ag Equipment Ver Pla Placement Place. 1st Place. 2nd Ver Rest Rest. Config. Rest. 1st Rest. 2nid Eype Seq onfiguration Verif Verif Req Seq *As Left (If Duff.) Verif Verif Equipment Description Date/Time Date/Time Date/Time Date/Time Serial No.

Equipment Location
Notes Notes

                                                                                        -.                                                5           -                 - -

Restorátl 37O1P NV 22 - - . IV NOODWARD, 1RIPPLETT RN hecklist ABRIEL 09/05/2010 09/05/2010 2Z 48

ISO VLV TO PI-1095A ON 21 21 276 .. . DCW PUMP A SUCTION..

                 *202 cOMPONENT OOLING PUMP ROOM Restorati 3 701R                                          NV    23                                                                   IV    4                                    NOODWARD,              [rR!PPLETr, RU)N heckhst                                                                                                                                                                      3ABRIEL 09/05/2010 )9/05/2010 21 48

ISO VLV IN SERVICE TEST:. 21:21:.

277., . . IND ON. CCW PUMPA SUCTION

202 OOLING PUMP ROOM:.

U .. , Restorati 31012 NV 24 IV. 3 - NOODWARD, RIPPLE1T, .RN Checklist - - - 3ABRIEL 09/05/2010 09/05/2010 2J 48

- -

TEST VLV FOR IST-3-40 21 21 78 ND XST-4-31 COMPONENT OLING PUMP SUcTI N
202 COMPONENT OOLING PUMP RoOM:..::....:,.

estorati 3-1483 NV 25 . IV. 2 WOODWARD, FRIPPLE1T, RN Checklist 09105)2010 09/05/2010 2*48

--..- CCWPUMPAOTBDMECH 21:20 Z79 SEAL COOLANT SUPPLY ISOLATION VALVE :

                 *202                     ::

DOOLING PUMP ROOM eStorati 3-1482 *26 . . :v 1 : -. .- - - - - VOODWARD,. FRIPPLEIT 1 RON Checklist ABRIEL 09/05/20i0 09/05/2010 2i48

CCW PUMP A INBDMECH. 21:20 SEAL COOLANT SUPPLY soL.ATI0N VALVE
202 _COMPONENT COOLING PUMP ROOM Page 4of4

Appendix C Job Performance Measure Form ES-C-I Worksheet Facility: Turkey Point Task No: 01038034100 JPM: Evaluate conditions for restart of Refueling Preshuffle JPM

Title:

in the spent fuel pit. JPM No: 01038034101 K/A

Reference:

2.3.12 (3.2/3.7) Category: NRC Examiner: Exam inee: (N/A for Utility Exams) Facility Evaluator: Date: Method of TestinQ Simulated Performance X Actual Performance Classroom X Simulator Plant Read to the examinee: I 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: Refueling Preshuffle activities were interrupted in the Unit 3 Spent Fuel Pit. The SM desires to resume preshuffle activities. The following plant conditions exist:

Spent Fuel pool Level is 56 ft 11 inches.
Spent fuel boron concentration is 2130 ppm as determined by the last sample taken 36 hrs ago.
Control Room Temperatures are 75°F.
ONLY one communications system is functional.
HP coverage is available.
FME Controls for the Spent Fuel Pit Area are not in effect.

The following plant components are inoperable:

Spent Fuel Pit skimmer pump is OOS.
Rl-3-1419B, Unit 3 SPENT FUEL PIT EXHAUST DUCT, is inoperable. A portable monitor without an alarming device has been substituted.

o Unit 3 SEP SPING Mid Range Noble Gas Monitor is 005.

C Control room AC Air Handler is OOS.

INITIATING CONDITIONS The SM has asked you to evaluate conditions for recommencement of Preshuffle in accordance with 3-NOP-040.3, Fuel Handling and insert Shuffle in the Spent Fuel Pit. Identify all the items, if any that will prevent the recommencement of preshuffle. NUREG 1021 Rev 9 Appendix C

Appendix C Page 2 of 12 Form ES-C-I Task Standard: Reviews the given conditions based on the criteria in Attachment 2 of 3-NOP-040.3, Fuel Handling and Insert Shuffle in the Spent Fuel Pit. Determines only the following as preventing preshuffle restart: A. SEP Level less than 570. B. Rl-3-1419B, Unit 3 SPENT FUEL PIT EXHAUST DUCT replacement monitor does not have an alarming device. C. FME Controls for the spent fuel pool are not in place. D. C Control Room Air Handler is OOS. - Required Materials:

3-NOP-040.03, FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT General

References:

3-NOP-040.03, FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT NUREG 1021 Rev 9 Appendix C

Appendix C Page 3 of 12 Form ES-C-I Initiating Cue: Evaluate the given conditions and the equipment that is QOS and identify all the items that will prevent recommencement of the preshuffle. Terminating Cue: Attachment 2 of 3-NOP-040.3 reviewed and problems identified that will prevent preshuffle restart. Time Critical Task: No Validation Time: 10 minutes HAND JPM BRIEFING SHEET TO EXAMINEE AT THIS TIME! NUREG 1021 Rev9AppendixC

Appendix C Page 4 of 12 Form ES-C-I SIMULATOR SETUP ResettolC# N/A Load Lesson N/A Ensure Simulator Examinee Checklist is complete N/.A NUREG 1021 Rev9AppendixC

Appendix C Page 5 of 12 Form ES-CT Denote critical steps with a check mark(J) StarI Time Obtain a copy of 3-NOP-040.3. FUEL HANDLING AND INSERT STEP 1 : SHUFFLE IN THE SPENT FUEL PIT (From the initiating cue.) Standard: Obtains a copy of 3-NOP-040.3. Cue Provide a copy of 3-NOP-.040.3. Comment NUREG 1021 Rev 9 Appendix C

Appendix C Page 6 of 12 Form ES-C-I STEP 2 : Reviews Precautions and Limitations. 1 S AT UNSAT Standard: Precautions and limitations were reviewed. Cue Comment NOTE: NUREG 1021 Rev9AppendixC

Appendix C Page 7 of 12 Form ES-C-I Identifies Attachment 2, Restart Minimum Equipment Checklist as the STEP 3 : appropriate Attachment. SAT UNSAT Standard: Goes to Attachment 2 Cue

Comment NOTE:

NUREG 1021 Rev 9 Appendix C

Appendix C Paqe 8 of 12 Form ES-C-I NUREG 1021 Rev 9 Appendix C

Appendix C Page 9 of 12 Form ES-C-I Evaluates Attachment 2 Equipment and Minimum Requirements for - STEP 5 Restart column and initials. SAT UNSAT Standard: Compares the 1 1 Listed items against the given conditions. Cue Comment If the operator asks about the status of equipment on Attachment 2, NOTE: state ALL equipment is available and operable as noted on the initial conditions. NUREG 1021 Rev 9 Appendix C

Appendix C Page 10 of 12 Form ES-C-I Identifies AND Records reasons for stopping fuel shuffle on Attachment 2. A. Spent Fuel Pit Level is less the 57O. B. RI-1419B is inoperable and the portable monitor does not have an alarm. Standard: C. 3Air Handlers are not in Operation D. Continuous FME Coverage is required. Cue Corn ment NOTE: The only problems that would prevent restart are those identified in Rows 2, 5 10, II. NUREG 1021 Rev 9 Appendix C

Appendix C Page II of 12 Form ES-C-I Verification of Completion 01038034100--Evaluate conditions for restart of Refueling Preshuffle in JPM Number/Title: the spent fuel pit. Examinees Name: NRC Examiner: (N/A for Utility Exams) Date Performed: Facility Evaluator: Number of Attempts: Time to Complete: Question Documentation: Question:

Response

Result: Satisfactory/Unsatisfactory Examiners signature and date: NUREG 1021 Rev9AppendixC

JPM BRIEFING SHEET The examiner wilt exIain the iTiitil OnditiOr, 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: Refueling Preshuffle activities were interrupted in the Unit 3 Spent Fuel Pit. The SM desires to resume preshuffle activities. The following plant conditions exist:

Spent Fuel pool Level is 56 ft 11 inches.
Spent fuel boron concentration is 2130 ppm as determined by the last sample taken 36 hrs ago.
HP coverage is available.
ONLY one communications system is functional.
Control Room Temperatures are 75°F.
FME Controls for the Spent Fuel Pit Area are not in effect.

The following plant components are inoperable:

Spent Fuel Pit skimmer pump is OOS.
RI-3-1419B, Unit 3 SPENT FUEL PIT EXHAUST DUCT, is inoperable. A portable monitor has without an alarming device has been substituted.
Unit 3 SFP SPING Mid Range Noble Gas Monitor is OOS.
C Control room AC Air Handler is OOS.

INITIATING CONDITIONS The SM has asked you to evaluate conditions for recommencement of Preshuffle in accordance with 3-NOP-040.3, Fuel Handling and insert Shuffle in the Spent Fuel Pit. Identify all the items, if any that will prevent the recommencement of preshuffle. 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 NUREG 1021 Rev9AppendixC

The examiner w When you com INITIAL CON DI Refueling Presl The SM desires The following p1

Spen o Spenl o HPcc
ONLi
Contr
FME The following p1
Speni o Rl been
C C

3 INITIATING CO The SM has as NOP-040.3, Fu prevent the recc Acknowledge t HAND

REVISION NO.: PROCEDURE TITLE: Lt1 PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 26 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 ATTACHMENT 2 Restart Minimum Equipment Checklist (Page 1 of2) Minimum Checked Applicable Tech. Equipment! Conditions Requirement for Initials REMARKS Spec. Shuffle Spent Fuel Pit Ventilation System OPERABLE N/A IF level drops below minimum, THEN INSERT Spent Fuel Pit Level 57 0 3.9.11 ft4 fuel assembly in a storage location. Spent Fuel Pit Water surface and subsurface CHECK Daily IF NOT clear, THEN is clear enough to allow good visibility during CLEAR N/A REQUEST RP place Tn-Nuclear in service, refueling operations / change filters, or skim pool surface as needed. May be waived by Radiation Protection Spent Fuel Pool Demin aligned to SFP In service AMi N/A supervision if clarity and dose rates permit. RI-3-1407B, RI-3-141 9B, and Rl-3-1 421 IF area monitor is NOT operable, THEN OPERABLE /t N/A Remote/Local Indications and Alarms INSTALL a portable monitor with an alarm. IF tube gate is OPEN, THEN CHECK daily. Greater than or Spent Fuel Pit Boron Concentration equal to 3.9.14.b IF tube gate is CLOSED, THEN CHECK by the 2100 ppm most recent SFP boron sample and an additional sample is NOT required. Spent Fuel Storage Pool Area High Gaseous (A& Table 3.3-4 Item 2a OPERABLE Radioactivity Monitor Action 28 PERFORM Attachment 4, Refueling Communications Headsets/other reliable CONTINUOUS N/A Communication Verification Checklist. At least communication system Control Room to SFP Iw one communication system is functional. RP Coverage CONTINUOUS N/A

REVISION NO.: PROCEDURE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT PROCEDURE NO.: 27 of 31 3-NOP-040.03 TURKEY POINT UNIT 3 ATTACHMENT 2 Restart Minimum Equipment Checklist (Page 2 of 2) Minimum Checked Equipment! Conditions Requirement for Initials Applicable Tech. REMARKS Shuffle Spec. Control Room Emergency Ventilation System OPERABLE y14 3.7.5 Requires 3 air handlers and 2 compressors and Control Room air temperature 120°F. FME Monitor CONTINUOUS - N/A (1 Reason for stopping fuel shuffle. SQer L S 7 j(4 q j4e WLtdAtvt 0 f4t jV(4 f9 Name Date Time Signature Performed By (RO or SRO)

                                                                                                  &W41                4%L2 Unit Supervisor confirms conditions are met to restart Shift Manager gives permission to restart Reviewed By:

Shift Manager or SRO Designee Date

Procedure No. TURKEY POINT UNIT 3 3-NOP-040.03 NORMAL OPERATING PROCEDURE Revision No. F L SAFETY RELATED 8 CONTINUOUS_USE

Title:

FUEL HANDlING AND INSERT SHUFFLE IN THE SPENT FUEL PIT Responsible Department: OPERATIONS Special Considerations: This is an Upgraded Procedure. Initial use should include increased awareness because of potential technical and/or sequential changes to the procedure. After initial use of this procedure, provide comments back to the Procedure Upgrade Project. FOR INFORMATION ONLY Before use, verity revision and change documentation (if applicable) with a controlled index or document. DATE VERIFIED_______ INITIAL________ Revision Approved By Approval Date UNIT # UNIT 3 DATE DOCT PROCEDURE 0 Sam Shafer 07/30/09 DOCN 3-NOP-040.03 SYS STATUS COMPLETED 8 Randy Flynn 09/14/1 1 REV 8

                                                                                  # OF PGS

REVISION NO.: PROCEDURE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 2 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3

                           .        REVISION

SUMMARY

Rev. No. Description 8 AR 1674392, 09/14111, Alex Hay

              . Remove North hook restriction for DSC fuel loading.
              . Revise use of spacer during DSC fuel loading as optional.
              . Revised Attachment 4, Refueling Communication Verification Checklist, identified conference numbers.

7 AR 1668835, 07I22I11, Alex Hay Added restrictions for the use of the SFP Bridge Crane when a spacer is used in the SFP (Step 4.2.1.18). 6 AR 581462, 06121111, Alex Hay

              . Added reference to two new Unit 3 Cask Operation procedures (3-NOP-1 16.01 and 3-NOP-1 16.02). Account for DSC fuel loading and off-loading operations.
              . Added change to SFP level and boron concentration requirements to account for DSC fuel loading and unloading operations.

5 PCR 09-3347, 0111 9I11, Roger Sablone Enhance procedure by changing SEP level alarms per CR 08-1 1825. 4 AR 579080, 11129110, David Dagitz Revise to address the installation of Metamic Inserts, clarify the unlocking and locking of fuel handling tools by the RPSS and correct several procedural references.

REVISION NO.: PROCEDURE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 3 of 31 PROCEDURE NO.: 3.-NOP-040.03. TURKEY POINT UNIT 3 TABLE OF CONTENTS SECTION PAGE 1.0 PURPOSE 4 2.0 PRECAUTIONS AND LIMITATIONS 4 3.0 PREREQUISITES 5 4.0 INSTRUCTIONS 8 4.1 Startup 8 4.1.1 Initial Conditions 8 4.2 Operation 9 4.2.1 Fuel Shuffle and Dry Shielded Canister (DSC) Fuel Loading or Off-Loading 9 4.2.2 Insert Shuffle 15 4.3 Shutdown 17 5.0 INFREQUENT OPERATIONS 17 6.0 RECORDS 18

7.0 REFERENCES

AND COMMITMENTS 19 ATTACHMENTS ATTACHMENT 1 Pre-Shuffle Minimum Equipment Checklist 22 ATTACHMENT 2 Restart Minimum Equipment Checklist 26 ATTACHMENT 3 SFP Lip Lighting Receptacles 28 ATTACHMENT 4 Refueling Communication Verification Checklist 29

REVS1ON NO.: - PROCEDtJRE TITLE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 4 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 1.0 PURPOSE This procedure provides instructions to perform fuel handling operations in the Spent Fuel Pool when core offload or reload is NOT in progress. 2.0 PRECAUTIONS AND LIMITATIONS 2.1 Precautions

1. FME controls shall be in place per MA-AA-101-1 000, Foreign Material Exclusion Procedure.

2. Underwater tools with hollow tube sections should have flood holes or an alternate means of flooding the tube sections. This will enable water to enter the tube and provide shielding against radiation streaming.

3. Keeping the doors of the New Fuel Room and the Spent Fuel Pit closed while transporting new fuel assemblies will assist in maintaining cleanliness control of new fuel assemblies. Doors may be momentarily opened for essential egress.

4. Verbatim repeat-backs and phonetic alphabet shall be used during all communications.

5. Phone talkers should identify themselves by the station they are manning, and identify the station they are calling such as, New Fuel Room, this is the Spent Fuel Pool. Personal names should NOT be used.

2.2 Limitations

1. Heavy loads greater than 2000 pounds are prohibited from travel over irradiated fuel assemblies in the Spent Fuel Pool.

2. A minimum level of 57 feet 0 inches shall be maintained in the Spent Fuel Pool at all times.

3. Fuel assembly should NOT move into Transfer Canal from Spent Fuel Pit until the Lifting Frame is in the full up position and verified.

4. All personnel designated to operate refueling equipment shall be trained on that equipment and approved by the Shift Manager.

5. Any item to be removed from the Spent Fuel Pit shall be approved by Radiation Protection prior to removal and surveyed by Radiation Protection upon removal.

REViSION NO.: P1OCEDURE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 5 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 3.0 PREREQUISITES TNITIAL

1. ENSURE Spent Fuel Pit boron concentration greater than 2100 ppm except for ISFSI fuel loading and off-loading operations, which will be determined by Reactor Engineering.

2. ENSURE Spent Fuel Pit water level between 57 feet 0 inches and 57 feet 5 inches.

3. ENSURE SFP level is between 57 0 and 57 11 for ISFSI fuel loading and off-loading operations.

4. IF y of the following conditions exist:

a Spent Fuel Pit water clarity is questionable a Radiation Protection recommends SFP Demineralizer in operation for local dose rates THEN ENSURE SFP Demineralizer and/or TriNuke filter(s) in operation. NOTE

Fuel handling equipment testing is required if maintenance has been performed or the equipment has been idle for greater than one month.
New fuel handling equipment testing is required if new fuel is to be moved from the New Fuel Room to the Spent Fuel Pit.

5. IF required per Operations Coordinator, THEN ENSURE 3-OSP-038.4, Spent Fuel Pool Bridge Crane Operability Test, complete.

6. IF new fuel is to be moved from New Fuel Room to Spent Fuel Pit, THEN ENSURE the following complete:

A. 0-OSP-039.1, New Fuel Elevator Periodic Test B. 0-OSP-039.2, New Fuel Monorail Hoist Periodic Test C. 3-OSP-039.3, New Fuel Bridge Crane Periodic Test

7. ENSURE Shuffle Data Sheets or equivalent, reviewed and approved per 0-ADM-556, Fuel Assembly and Insert Shuffles, prior to commencing fuel assembly or fuel insert movement.

REVISION NO: PROCEDURE TIILE: - PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 6 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 3.0 PREREQUISITES (continued) INITIAL

8. ENSURE 3-OSP-034.2, Spent Fuel Pit Ventilation System Air Flow Test, performed within 18 months plus the grace period.

9. ENSURE 3-OSP-034.1, Spent Fuel Pit Inlet and Exhaust Damper Operability Test, performed within one month.

10. ENSURE the following procedures are in the SFP area, as directed by Refueling SRO or Fuel Handling Supervisor:

A. O-ADM-035, Limitations and Precautions for Handling Fuel Assemblies B. O-ADM-556, Fuel Assembly and Insert Shuffles C. MA-AA-1O1-1 000, Foreign Material Exclusion Procedure D. 0NOP-034.02, Metamic Insert Installation / Removal and Metamic Coupon Installation E. 3-NOP-039.01, New Fuel Elevator Operating Instruction F. 3-NOP-040.03, Fuel Handling and Insert Shuffle in the Spent Fuel Pit G. 3-ONOP-033.2, Refueling Cavity Seal Failure H. 3-ONOP-033.3, Accidents Involving New and Spent Fuel I. 3-ONOP-038.1, Loss of Refueling Equipment or Support Function J. 3-OP-038.1, Preparation for Refueling Activities K. 3-OP-038.5, Spent Fuel Pit Bridge Crane Operation L. 0-OP-038.12, Spent Fuel Assembly Handling Tool Operating Instruction M. 3-OP-039.3, New Fuel Bridge Crane Operating Instructions N. 0-OP-040.7, RCC Change Tool

0. 0-OP-040.8, BPRA Handling Tools P. 0-OP-040.1O, Operating and Maintenance Procedure for the Turkey Point Nozzleless Fuel Assembly Handling Tool

REVISION NO.: PROCDURE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 7 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 3M PREREQUISITES (continued) INITIAL

10. (continued)

Q. 3-NOP-116.O1, Dry Shielded Canister Fuel Loading, as applicable R. 3-NOP-116.02, Dry Shielded Canister Fuel Off-Load, as applicable

11. ENSURE satisfactory channel check complete for the following Area Radiation Monitors per 3-OSP-201 .1, RO Daily Logs, OR the monitor is replaced by a temporary portable monitor equipped with an alarm:

A. Rl-3-1407B, Unit 3 SPENT FUEL PIT CANAL AREA B. Rl-3-1419B, Unit 3 SPENT FUEL PIT EXHAUST DUCT C. Rl-3-1421 B, Unit 3 SPENT FUEL PIT NORTH WALL

12. CHECK Unit 3 Spent Fuel Pit SPING High Range Noble Gas Monitor, OPERABLE, per Chemistry performance of O-OSP-2005, Miscellaneous Test, Checks and Operating Evolutions.

13. NOTIFY RP that RPSS authorization will be required to acquire the key to unlock and lock the fuel and insert handling tools located on the SFP handling tool rack or the pass-over bracket.

REViSION NO.: PROCEDUE titL: .- PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 8 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 4.0 INSTRUCTIONS 4.1 Startup 4.1.1 Initial Conditions

1. ENSURE Radiation Protection Shift Supervisor established survey controls (RPT or remote monitoring) prior to commencing fuel shuffle.

NOTE Original Shuffle Data Sheets maintained in the Control Room serve as the permanent history.

2. ENSURE original Shuffle Data Sheets maintained in Control Room.

3. PLACE copies of Shuffle Data Sheets or equivalent at SFP Bridge Crane.

4. IF a vendor procedure will be used, THEN:

A. ENSURE vendor procedure reviewed and approved per O-ADM-005, Control of On-Site Services, prior to movement of individual fuel rods. B. RECORD vendor procedure number: Vendor procedure

5. REFER TO Attachment 3, SFP Lip Lighting Receptacles, AND ENSURE underwater lights are energized.

6. IF moving fuel in the SFP, THEN PERFORM Section 4.2.1, Fuel Shuffle and Dry Shielded Canister (DSC) Fuel Loading or Off-Loading.

7. IF moving only inserts in the SFP, THEN PERFORM Section 4.2.2, Insert Shuffle.

REV1SlOlf NO.: POCEbUtItL: -- PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 9 of 31 PROCEDURE NO.: 3-NOP-04003 TURKEY POINT UNIT 3 4.2 Operation 4.2.1 Fuel Shuffle and Dry Shielded Canister (DSC) Fuel Loading or Off-Loading

1. ENSURE the following for SpectraLink Communication System:

A. Cell phones with headsets pre-staged at each required station. B. Cell phones are charged. C. Battery charger, with spare batteries, available at each station. D. Extra cell phone and headset available at each station.

2. IF cleanliness of the SFP Ventilation Inlet and Exhaust Filters are questionable, THEN REQUEST System Engineer determine if filters are acceptable to support fuel movement.

3. IF SFP Ventilation Inlet or Exhaust Filters pressure gauges indicate greater than 1.6 inches water, THEN REQUEST Mechanical Maintenance replace filters.

4. ENSURE Transfer Canal is filled and 3-12-031, UNIT 3 FUEL TRANSFER TUBE GATE VALVE, is CLOSED during fuel assembly movement in the Spent Fuel Pit (Section 7.2 Commitment 1).

5. OBTAIN RPSS authorization to remove the lock from the SFF handling tool rack and pass-over bracket.

Authorizing RPSS Date

6. DIRECT RP to remove the lock on the SFP handling tool rack or pass-over bracket.

NOTE The minimum equipment or support function specified by Attachment 1, Pre-Shuffle Minimum Equipment Checklist, must be continuously met prior to and during movement of fuel. If a loss of any of the equipment or support function occurs, 3-ONOP-038.1, Loss of Refueling Equipment or Support Function, shall be performed.

7. PERFORM Attachment 1, Pre-Shuffle Minimum Equipment Checklist, prior to moving fuel.

VIiON NO.: PROCEDURE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 10 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 4.2.1 Fuel Shuffle and Dry Shielded Canister (DSC) Fuel Loading or Off-Loading (continued)

8. CHECK 3-OSP-034.2, Spent Fuel Pit Ventilation System Air Flow Test, performed within 18 months plus the grace period.

RECORD date of performance:_______________

9. CHECK 3-OSP-034.1, Spent Fuel Pit Inlet and Exhaust Damper Operability Test, performed within one month.

RECORD date of performance:_______________

10. IF moving fuel in the Transfer Canal, THEN ENSURE SFP to Transfer Canal Gate, removed.

NOTE There are three refueling communication systems to provide reliability as well as redundancy during refueling activities. Two are cell phone based systems and the other is a hard-line phone based system. If a problem exists with one of the systems, it should be corrected as soon as possible.

11. ESTABLISH communications using Attachment 4, Refueling Communication Verification Checklist.

NOTE All lanyards must meet the requirements of MA-AA-101-1000, Foreign Material Exclusion Procedure, Attachment 1, Tools and Devices.

12. INSPECT all FME lanyards used in the area of the Spent Fuel Pit to ensure the following:

A. Lanyards are in good repair and have NO signs of excess wear. B. Lanyards are fastened securely on both ends. C. Only designed lanyards are used (i.e., NO lanyards made of tape, cotton string, etc.).

RVISION NO.: PROCEDURE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 11 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 4.2.1 Fuel Shuffle and Dry Shielded Canister (DSC) Fuel Loading or Off-Loading (continued)

13. IF moving fuel assemblies into the SFP from New Fuel Room, THEN:

A. ENSURE the following stations, as a minimum, are in direct communications: (1) SRO or Fuel Handling Supervisor in SFP (2) Qualified Operator or Engineer in New Fuel Room. (3) Control Room personnel, who at the discretion of the Operations Manager or Assistant Operations Manager, are either:

a. Two Qualified Engineering Representatives

b. One Qualified Engineering Representative and one Licensed Operator B. PERFORM concurrent verification of each step by the two Control Room personnel prior to fuel assembly movement.

C. ENSURE, as a minimum, the following is communicated between stations for each verification: (1) Step number from Shuffle Data Sheet (SDS) (2) Specific location in SFP

14. IF moving fuel assemblies in the SFP with NO fuel movement in other locations except the Dry Shielded Canister (DSC), THEN:

A. ENSURE the following, as a minimum, in direct communication: (1) SEP Spotter or Cable Watch (2) SRO or Fuel Handling Supervisor in SEP (3) Control Room personnel, who at the discretion of Operations Manager or Assistant Operations Manager, are either:

a. A qualified Engineering Representative

b. A licensed Operator

REVISION NO.: PROCEDUR1iTLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 12 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 4.2.1 Fuel Shuffle and Dry Shielded Canister (DSC) Fuel Loading or Off-Loading (continued)

14. (continued)

B. ENSURE the three personnel in communication perform a verification of Shuffle Data Sheets and SFP Crane Index, if applicable, for each fuel movement prior to latching and unlatching the fuel assembly. C. ENSURE as a minimum, the following is communicated between stations for each verification: (1) Step number from the Shuffle Data Sheet (SDS) (2) Specific location in the SFP

15. IF fuel shuffle is for preparation a core reload, THEN ENSURE RWST on purification per 3-OP-033, Spent Fuel Pit Cooling System.

16. ENSURE Spent Fuel Pool water clarity adequate for fuel movement.

17. IF moving irradiated assemblies or other irradiated material, THEN REQUEST Radiation Protection monitor exposure rates at exterior Spent Fuel Pool walls to ensure they remain less than or equal to 1 mR/h above background.

NOTE A spacer may be used with the short spent fuel handling tool to facilitate latching or unlatching fuel assemblies in the SEP racks for loading or off-loading fuel in a DSC.

18. WHEN fuel is to be moved to a Dry Shielded Canister (DSC) in the SEP Cask Area, THEN PLACE a spacer of 20 inches or less in a rack storage location as specified by Reactor Engineering Supervisor.

REVTS[ON NO.: PROCEDURETITLE: - - PAGE: 8 FULL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 13 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 4.2.1 Fuel Shuffle and Dry Shielded Canister (DSC) Fuel Loading or Off-Loading (continued) CAUTION IF a fuel assembly is staged on the spacer, NO other fuel assembly or insert may be moved.

19. COMMENCE fuel shuffle using Shuffle Data Sheets and 0-NOP-040.01, Handling New Fuel Shipping Containers and New Fuel Assemblies, or 3-NOP-116.01, Dry Shielded Canister Fuel Loading, or 3-NOP-1 16.02, Dry Shielded Canister Fuel Off-Load.

A. PERFORM Attachment 1, Pre-Shuffle Minimum Equipment Checklist, once per shift while work is in progress. B. IF necessary to make changes to Shuffle Data Sheet, THEN: (1) INITIATE changes to the Shuffle Data Sheet per 0-ADM-556, Fuel Assembly and Insert Shuffles. (2) OBTAIN Shift Manager approval for all changes in Fuel Handling Data Sheets, per 0-ADM-556, Fuel Assembly and Insert Shuffles.

20. IF fuel movement is stopped, THEN PERFORM Attachment 2, Restart Minimum Equipment Checklist, prior to restart.

NOTE Reactor Engineering may waive location verifications

21. WHEN fuel shuffle or DSC fuel loading / off-loading is complete and fuel assembly and insert locations have been verified (if required),

THEN: A. RETURN all SFP handling tools to the SFP handling tool rack or pass-over bracket. B. DIRECT RP to install lock on SEP handling tool rack or pass-over bracket. C. DRAIN Transfer Canal per 3-OP-201, Filling/Draining the Refueling Cavity and SFP Transfer Canal, if desired.

REVISION NO.: PROCEDURE TItLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 14 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 4.2.1 Fuel Shuffle and Dry Shielded Canister (DSC) Fuel Loading or Off-Loading (continued)

22. IF required by Reactor Engineering, THEN REQUEST Reactor Engineering verify fuel assemblies and inserts in correct location in the SEP or DSC fuel cells when fuel shuffle or DSC fuel loading I off-loading is complete.

REViSION NO.: - PROCEDURE TITLE: - PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 15 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 4.2.2 Insert Shuffle NOTE Insert shuffles in the SEP do NOT require continuous communication with Control Room.

Insert shuffles in the SEP do NOT require the Control Room Emergency Ventilation System to be OPERABLE.
Metamic Inserts are considered to be insert shuffles.
The same criteria applies to the movement of Metamic Inserts as it does to all other fuel inserts (i.e., RCCAs, WABAs, BPRA5, etc).

1. ENSURE Spent Fuel Pool water clarity adequate for fuel movement.

2. ENSURE Transfer Canal is filled and 3-12-031, UNIT 3 FUEL TRANSFER TUBE GATE VALVE, is CLOSED during insert movement in the Spent Fuel Pit (Section 7.2 Commitment 1).

3. OBTAIN RPSS authorization to remove the lock from the SEP handling tool rack and pass-over bracket.

Authorizing RPSS Date

4. DIRECT RP to remove the lock on the SEP handling tool rack or pass-over bracket.

5. ENSURE a management representative is available to provide oversight responsibility during all component shuffles.

6. ENSURE another qualified individual and the management representative are available to perform independent verification prior to insert movement.

REVISION NO.: PROCEDUE titLE: - PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 16 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 4.2.2 Insert Shuffle (continued) NOTE All lanyards must meet the requirements of MA-AA-1 01-1000, Foreign Material Exclusion Procedure, Attachment 1, Tools and Devices.

7. INSPECT all FME lanyards used in the area of the Spent Fuel Pit to ensure the following:

A. Lanyards are in good repair and have no signs of excess wear. B. Lanyards are fastened securely on both ends. C. Only designed lanyards are used (i.e., no lanyards made of tape, cotton string, etc.).

8. NOTIFY Radiation Protection Shift Supervisor that the Insert Shuffle is commencing.

9. NOTIFY RCO that the Insert Shuffle is commencing.

10. COMMENCE fuel shuffle using Shuffle Data Sheets.

11. IF necessary to make changes to Shuffle Data Sheet, THEN:

A. INITIATE changes to the Shuffle Data Sheet per 0-ADM-556, Fuel Assembly and Insert Shuffles. B. OBTAIN Shift Manager approval for all changes in Fuel Handling Data Sheets, per 0-ADM-556.

12. WHEN insert shuffle complete, THEN:

A. RETURN all SFF handling tools to the SFP handling tool rack or pass-over bracket. B. DIRECT RP to install lock on SFP handling tool rack and pass-over bracket. C. DRAIN Transfer Canal per 3-OP-201, Filling/Draining the Refueling Cavity and SFP Transfer Canal, if desired.

EVIION NO.: PROCEDURE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 17 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 4.3 Shutdown

1. REFER TO Attachment 3, SFP Lip Lighting Receptacles, and SECURE lighting as required.

5.0 INFREQUENT OPERATIONS None

REVISION NO.: IROCEtUIE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 18 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 6.0 RECORDS

1. The date, time, and section completed shall be entered in the Unit Narrative Log.

2. Problems encountered while performing this procedure (i.e.,

malfunctioning equipment, delays due to change in plant conditions, etc.) should be entered in the Unit Narrative Log.

3. Completed copies of the below listed items document compliance with Tech Specs surveillance requirements and shall be transmitted to QA Records for retention:

A. Attachment 1, Pre-Shuffle Minimum Equipment Checklist B. Attachment 2, Restart Minimum Equipment Checklist C. Attachment 4, Refueling Communication Verification Checklist

RVISION NO.: OOOURE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 19 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 7M REFERENCES AND COMMITMENTS 7.1 References 7.1.1 Implementing

1. 0-ADM-035, Limitations and Precautions for Handling Fuel Assemblies

2. 0-ADM-217, Conduct of Infrequently Performed Tests or Evolutions

3. 0-ADM-556, Fuel Assembly and Insert Shuffles

4. 0-NOP-034.02, Metamic Insert Installation I Removal and Metamic Coupon Installation

5. 3-NOP-039.01, New Fuel Elevator Operating Instructions

6. 3-NOP-116.01, Dry Shielded Canister Fuel Loading

7. 3-NOP-1 16.02, Dry Shielded Canister Fuel Off-Load

8. 3-ON OP-033.2, Refueling Cavity Seal Failure

9. 3-ONOP-033.3, Accidents Involving New or Spent Fuel

10. 3-ONOP-038.1, Loss of Refueling Equipment or Support Function

11. 3-OP-033, Spent Fuel Pit Cooling System

12. 3-OP-038.1, Preparation for Refueling Activities

13. 3-OP-038.5, Spent Fuel Pit Bridge Crane Operating Instructions

14. 0-OP-038.12, Spent Fuel Assembly Handling Tool Operating Instruction

15. 3-OP-039.3, New Fuel Bridge Crane Operating Instructions

16. 0-OP-040.1, Handling New Fuel Shipping Containers and New Fuel Assemblies

17. 0-OP-040.7, RCC Change Tool

18. 0-OP-040.8, BPRA Handling Tools

19. 0-OP-040. 10, Operating and Maintenance Procedure for the Turkey Point Nozzleless Fuel Assembly Handling Tool

REViSION NO.: OCt)U TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 20 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 7.1.1 Implementing (continued)

20. 3-OP-201, Filling/Draining the Refueling Cavity and the SFP Transfer Canal

21. 3-OSP-034. 1, Spent Fuel Pit Inlet and Exhaust Damper Operability Test

22. 3-OSP-034.2, Spent Fuel Pit Ventilation System Air Flow Test

23. 3-OSP-038.4, Spent Fuel Pit Bridge Crane Operability Test

24. 0-OSP-039. 1, New Fuel Elevator Periodic Test

25. 0-OSP-039.2, New Fuel Monorail Hoist Periodic Test

26. 3-OSP-039.3, New Fuel Bridge Crane Periodic Test

27. 0-OSP-200.5, Miscellaneous Tests, Checks and Operating Evolutions

28. 3-OSP-201.1, RO Daily Logs

29. MA-AA-101-1000, Foreign Material Exclusion Procedure 7.1.2 Developmental

1. T.S. 3/4.9.5, Refueling Operations Communications

2. T.S. 314.9.7, Crane Travel Spent Fuel Storage Areas

3. T.S. 3/4.9.11, Water Level Storage Pool

4. T.S. 3/4.9.14, Spent Fuel Storage

5. T.S. 3/4.7.5, Control Room Emergency Ventilation System

6. T.S. Table 3.3-4, Item 2.a, Unit 3 Spent Fuel Storage Pool Gaseous Radioactivity

7. QI-2-PTN-4, Housekeeping

8. 0-ADM-005, Control of On-Site Services

9. 0-ADM-552, Work Requirements for Maintaining Cleanliness in the Spent Fuel Rooms

REViSION SO.: OdEDURE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 21 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 7.1.2 Developmental (continued)

10. 0-HPA-001, Radiation Work Permit Initiation and Termination

11. IE Inspection Report 250-87-36 and 251-87-36

12. FPL Letter No. QAO-PTN-88-784, Observation - Dirty Spent Fuel Pit Ventilation Filters, dated October 20, 1988

13. QA Audit Report QAO-PTN-90-003

14. QA Audit Report QAO-PTN-90-023

15. T.S. License Amendment 234

16. PC/M 08-201, Unit 3 In-Mast Sipping Modification, Ultrasonic Inspection and Fuel Rod Reconstitution, Rev. 0, Page 8 of 30, Step 1.8.3 7.1.3 Management Directives None 7.2 Commitments

1. CTRAC 92-0152-34 in Response to NRC Info Notice 88-92 Supp 1, Potential for Spent Fuel Pool Draindown

REVISION NO.: PROCEDURE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 22 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 ATTACHMENT I Pre-Shuffle Minimum Equipment Checklist (Page 1 of 4) The minimum equipment or support function specified by Attachment 1 must be continuously met during the movement of fuel. If a loss of any of the equipment or support function occurs; 3-ONOP-038. 1, Loss of Refueling or Support Function, must be performed. Minimum Time Allowed Equipment! Nights Days Applicable Requirement Before Stopping Remarks Conditions Initials Initials Tech. Spec. for Shuffle Fuel Movement Spent Fuel Pit IMMEDIATE N/A OPERABLE Ventilation System Inspect daily for cleanliness. If cleanliness of the SFP Ventilation Inlet and Exhaust Filters is in Spent Fuel Pit Inlet and N/A N/A question, REQUEST System Engineer N/A Exhaust Filters determine if the cleanliness of the filters is acceptable to support fuel movement. Spent Fuel Pool Demin May be waived by Radiation Protection In service IMMEDIATE N/A aligned to SFP supervision if clarity and dose rates permit. IF level drops below minimum for any reason, Spent Fuel Pit Level 57 0 1MM ED lATE 3.9.11 THEN INSERT fuel assembly in a storage location. SFP water surface and CHECK Daily IF NOT clear, THEN REQUEST subsurface clear N/A 1MM ED lATE N/A RP to place Tn-Nuclear in service, change CLEAR enough for good filters, or skim the pool surface as needed. visibility during shuffle

REVISION NO.: PROCEDURE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 23 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 ATTACHMENT I Pre-Shuffle Minimum Equipment Checklist (Page 2 of 4) Minimum Nights Time Allowed Equipmentl Days Applicable Requirement Before Stopping Remarks Conditions Initials Initials Tech. Spec. for Shuffle Fuel Movement Rl-3-1 407B, Remote RI-3-1419B, and OPERABLE IF area monitor is NOT operable, THEN RI-3-1 421 IMMEDIATE N/A Local INSTALL a poriable monitor with an alarm. Remote/Local Indications and Alarms OPERABLE IF Tube Gate is OPEN, THEN CHECK daily. Greater than Spent Fuel Pit Boron IF Tube Gate is CLOSED, THEN CHECK most or equal to N/A IMMEDIATE 3.9.14.b Concentration recent SEP boron sample, and an additional 2100 ppm sample is NOT required. SFP Area High 1 1 Table 3.3-4 Gaseous Radioactivity OPERABLE IMMEDIATE Item 2a CHECK twice per shift. Monitor 2 2 Action 28 Communications 1 1 headsets/other reliable CONTIN1I ICI ic IMMEDIATE N/A CHECK twice per shift. communication system Control Room to SFP 2 2 1 1 RP Coverage CONTINUOUS IMMEDIATE N/A CHECK twice per shift. 2 2 Control Room 1 1 CHECK twice per shift. Emergency Ventilation OPERABLE 1MM ED lATE 3.7.5 Requires 3 air handlers and 2 compressors System 2 2 Control Room air temperature 120°F.

REVISION NO.: PROCEDURE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 24 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 ATTACHMENT I Pre-Shuffle Minimum Equipment Checklist (Page 3 of 4) Minimum Time Allowed Equipmentl Nights Days Applicable Requirement Before Stopping Remarks Conditions Initials Initials Tech. Spec. for Shuffle Fuel Movement FME Monitor CONTINUOUS IMMEDIATE N/A PERFORM communications check between required stations to verify communication system functioning properly at beginning of each shift. IMMEDIATE N/A IF communication system is NOT functional, THEN PERFORM Attachment 4, Refueling Communication Verification Checklist. At least Communications one communication system shall be functional. See Remarks System IF using a cell phone based communication system, THEN CHECK daily that there is a battery charger with spare batteries and an extra N/A N/A cell phone and headset at each station. IF NOT, THEN immediately NOTIFY Fuel Handling Supervisor and SM. (The Fuel Shuffle can continue while equipment is being replaced.)

REVISION NO.: PROCEDURE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 25 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 ATTACHMENT I Pre-Shuffle Minimum Equipment Checklist (Page 4 of 4) NightShift Day Shift Name Date Time Signature Name Date Time Signature Performed By (RCO or SRO) Unit Supervisor confirms conditions met to start Shift Manager gives permission to start Reviewed By: Shift Manager or SRO Designee Date

REVISION NO.: PROCEDURE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 26 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 ATTACHMENT 2 Restart Minimum Equipment Checklist (Page 1 of 2) Minimum Checked Applicable Tech. Equipment! Conditions Requirement for Initials REMARKS Spec. Shuffle Spent Fuel Pit Ventilation System OPERABLE N/A IF level drops below minimum, THEN INSERT Spent Fuel Pit Level 57 0 3.9.1 1 fuel assembly in a storage location. Spent Fuel Pit Water surface and subsurface CHECK Daily IF NOT clear, THEN is clear enough to allow good visibility during CLEAR N/A REQUEST RP place Tn-Nuclear in service, refueling operations change filters, or skim pool surface as needed. May be waived by Radiation Protection Spent Fuel Pool Demin aligned to SEP In service N/A supervision if clarity and dose rates permit. RI-3-1407B, RI-3-1419B, and Rl-3-1421 IF area monitor is NOT operable, THEN OPERABLE N/A Remote/Local Indications and Alarms INSTALL a portable monitor with an alarm. IF tube gate is OPEN, THEN CHECK daily. Greater than or IF tube gate is CLOSED, THEN CHECK by the Spent Fuel Pit Boron Concentration equal to 3.9.14.b most recent SEP boron sample and an 2100 ppm additional sample is NOT required. Spent Fuel Storage Pool Area High Gaseous Table 3.3-4 Item 2a OPERABLE Radioactivity Monitor Action 28 PERFORM Attachment 4, Refueling Communications Headsets/other reliable N/A CONTINUOUS Communication Verification Checklist. At least communication system Control Room to SEP one communication system is functional. RP Coverage CONTINUOUS N/A

REVISION NO.: PROCEDURE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 27 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 ATTACHMENT 2 Restart Minimum Equipment Checklist (Page 2 of 2) Minimum Checked Applicable Tech. Equipment] Conditions Requirement for Initials REMARKS Spec. Shuffle Requires 3 air handlers and 2 compressors and Control Room Emergency Ventilation System OPERABLE 375 Control Room air temperature 120°F. FME Monitor CONTINUOUS N/A Reason for stopping fuel shuffle. Name Date Time Signature Performed By (RO or SRO) Unit Supervisor confirms conditions are met to restart Shift Manager gives permission to restart Reviewed By: Shift Manager or SRO Designee Date

REVISION fJO.: ROCEDURE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 28 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 ATTACHMENT 3 SFP Lip Lighting Receptacles (Page 1 of 1)

1. IF operation of underwater lights are required, THEN PLACE jj of the following breakers to ON as required.

Breaker Description Normal Position LP39 (SPENT FUEL PIT UNIT 3 AREA) NOTE 1: Breakers are normally OFF unless SFP operations require underwater lights. LP39-8 RCPT SPENT FUEL PIT SE WALL EL 58 OFF (NOTE 1) LP39-1O RCPT EL 58 SPENT FUEL PIT E WALL OFF (NOTE 1) LP39-1 I RCPT EL 58 SPENT FUEL RM E WALL OFF (NOTE 1) LP39-12 RCPT EL 58 SPENT FUEL PIT N WALL OFF (NOTE 1) LP39-13 RCPT EL 58 FUEL TRANSFER CANAL SE WALL OFF (NOTE 1) LP39-14 RCPT EL 58 SPENT FUEL PIT NW WALL OFF (NOTE 1) LP39-1 5 RCPT EL 58 FUEL TRANSFER CANAL S WALL OFF (NOTE 1) LP39-17 RCPT EL 58 SPENT FUEL PIT WWALL OFF (NOTE 1) LP39-18 RCPT CASK WASH AREA EL 18 & PLATFORM EL 31 OFF (NOTE 1)

2. WHEN operation of the underwater lights are NO longer required, THEN ENSURE the above breakers are OFF.

FEViSION NO.: OOEDURE TITLE: PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 30 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 ATTACHMENT 4 INITIAL Refueling Communication Verification Checklist (Page 2 of 3)

2. B. (continued)

(3) PERFORM communications check between aM stations. Li Control Room SFP NFR C. IF using SpectraLink Nortel Communication System, THEN: (1) ESTABLISH conference bridge by dialing 5095 or other dedicated conference bridge number. Li Li Li Control Room SEP NER (2) PERFORM communications check between all stations. Li Li Li Control Room SEP NER D. IF using Hard-Line Phone Communication System, THEN: (1) CONNECT phones to local phone jack OR UTILIZE an installed wall or desk phone. Control Room SEP NER (2) ESTABLISH conference bridge by dialing 5095 or other dedicated conference bridge number. Li Cl Cl Control Room SEP NFR (3) PERFORM communications check between all stations. Li Cl Li Control Room SEP NER

3. NOTIFY Unit 3 RCO of the results of the communications check.

REVISION NO.: OCOUE TITLE: - - -- PAGE: 8 FUEL HANDLING AND INSERT SHUFFLE IN THE SPENT FUEL PIT 31 of 31 PROCEDURE NO.: 3-NOP-040.03 TURKEY POINT UNIT 3 ATTACHMENT 4 Refueling Communicat ion Verification Checklist (Page3of3)

3. (continued)

Performed By: Print/Sign Initials Date Performed By: Print/Sign Initials Date Performed By: Print/Sign Initials Date Reviewed By: Unit Supervisor (Print/Sign) Date

Appendix C Job Performance Measure Form ES-C-I Worksheet Facility: Turkey Point Task No: 02201052300 Classify Event and Task

Title:

Complete SNF JPM No: 02201052320 K/A

Reference:

G2.4.41 (RO 2.9; SRO 4.6) Examinee: NRC Examiner: Facility Evaluator: Date: Method of Testing: Classroom Simulated Actual Performance Performance X Classroom X Simulator Plant Read to the examinee: I 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: o Unit 3 is in MODE 5 at 185°F, Unit 4 is in MODE 1 at 100% power.

At 0800, a Loss of Off-site Power occurred on Unit 3 due to a loss of the Unit 3 Startup Transformer.
The operating crew implemented 3-ONOP-004, Loss of Offsite Power.
At 0810, the 3A EDG the 3B EDG tripped and repair teams are investigating.

o At 0820, Unit 3 heated up above 200°F

At 0845, NO power is available from any source.

o The operators notes the following parameters: o RCS temperature is 205° F and increasing slowly. o Wind speed is 10mph. o Wind direction is from 180°. Initiating Cue:

You are the Emergency Coordinator in the Control Room. Based upon current plant conditions, classify the event using 0-EPIP-20101, Duties of Emergency Coordinator; including Protective Action Recommendations, if any.
Raise your hand as soon as you have classified the event. At that time the examiner will provide you with a copy of the Florida Nuclear Plant Emergency Notification Form, F-439.

You will then complete the Florida Nuclear Plant Emergency Notification Form, F-439; using 0-.EP I P-20 134, Offsite Notifications and Protective Action Recommendations.

When you have completed the Florida Nuclear Plant Emergency Notification Form, F-439, raise your hand to inform the Examiner you are done.
There are elements of this task that are Time Critical Task Standard:

2011 NRC Exam (SRO) JPM-A.4 NUREG 1021 Rev 9 Appendix C

Appendix C Page 2 of 10 Form ES-C-I

Classific8tion of Alert, EAL CA3, is declared within 15 minutes of starting The task.
Applicant determines that NO Protective Action Recommendations (PARs) are warranted.
The Florida Nuclear Plant Emergency Notification Form is completed in accordance 0-EPIP-201 34, Offsite Notifications and Protective Action Recommendations, with NO errors on required items identified with a and within 15 minutes of event declaration.

Required Materials:

0-EPIP-20101, Duties Of Emergency Coordinator
0-EPIP- 20134, Offsite Notifications and Protective Action Recommendations
Florida Nuclear Plant Emergency Notification Form, F-439.

General

References:

0-EPIP-20101, Duties Of Emergency Coordinator
0-EPIP- 20134, Offsite Notifications and Protective Action Recommendations Time Critical Task: Yes Validation Time: 20 minutes 2011 NRC Exam (SRO) JPM-A.4 NUREG 1021 Rev 9 Appendix C

iMULAToR SETUp. NOT Applicable 2011 NRC Exam (SRO) JPMA.4 NUREG 1021 Rev 9 Appendix C

Appendix C Page 4 of 10 Form ES-C-I Denote critical steps with a check mark (1) Start Time STEP I Obtain the required materials. STANDARD Applicant obtains 0-EPIP-20101, Duties of Emergency Coordinator, and a copy of the EAL Tables. EVALUATOR CUE: Provide Applicant with a copy of 0-EPIP-20101, Duties of Emergency Coordinator, and a copy of the EAL Tables. CUE EVALUATOR CUE: Annotate Start Time once Applicant begins review of 0-EPIP-20101, Duties of Emergency Coordinator. Start Time: COMMENT 2011 NRC Exam (SRO) JPM-A.4 NUREG 1021 Rev 9 Appendix C

[Ajpendix C Page 5 of 10 Form ES-C-I Review 0-EPIP-20101, Duties of Emergency Coordinator, to SAT STEP 2 determine if the EAL Tables must be used to classify the event (0-EPIP-20101, Step 5.1.2). UNSAT Applicant reviews 0-EPIP-201 01, Duties of Emergency STANDARD Coordinator; for the event depicted in the Initial Conditions, and determines that Attachment 2 must be used to declare the event. CUE COMMENT PROCEDURE EXCERPT: 5.1.2 Classifying the Event

1. The Initiating Conditions (ICs) and Emergency Action Levels (EALs) and their technical bases have been organized as NOTE follows:

Attachment 2, Emergency Classification Cold Conditions Table Contains all the EALs and bases, that apply when the RCS temperature is less than or equal to 200°F. 2Q11 NRC Exam (SRO) JPM-A.4 NUREG 1021 Rev 9 Appendix C

Appendix C Page 6 of 10 Form ES-C-I

Classify Off-Normal Event using present conditions AND declare most conservative emergency class using SAT STEP 3 Attachment 2 UNSAT (D-EPIP-20101, Step 5.3.4.3)

Applicant classifies the event as an Alert (CA3) by interpreting the information given in the Initial Conditions, comparing the information to the criteria in Attachment 2, Cold Conditions STANDARD Table; and declaring the EAL within 15 minutes of starting the JPM. CA3 Loss of All Off-site and All On-site AC Power to Emergency Busses for 15 minutes or Longer. EVALUATOR CUE: Annotate Stop Time for the classification when Applicant declares the event by raising his/her hand. Stop Time: Total Time to Declare Event: CUE EVALUATOR CUE: Provide the Applicant with a copy of the Florida Nuclear Plant Emergency Notification Form, F-439 (SNF). Annotate Start Time when Applicant receives the form. Start Time: COMMENT 2011 NRC Exam (SRO) JPM-A.4 NUREG 1021 Rev 9 Appendix C

Apendix C Page 7 of 10 Form ES-C-I Review 0-EPIP-201 34, Offsite Notifications and Protective STEP 4 SAT Action Recommendations (PARs) and determines if any PARs q are warranted. UNSAT (0EPIP20134, Attachment 3, form F-444; and Step 1.7) Applicant reviews 0-EPIP-20134, Offsite Notifications and STANDARD Protective Action Recommendations, Section 1.7 and

Attachment 3, and determines that PARs are NOT warranted.

CUE COMMENT 2011 NRC Exam (SRO) JPM-A.4 NUREG 1021 Rev 9 Appendix C

Appendix C Page 8 of 10 Form ES-C-I Complete Florida Nuclear Plant Emergency Notification Form. SAT STEP 5 (0-EPIP- 20134, Attachments IA & I B) UNSAT (Turkey Point Nuclear Form, F-439) The Applicant completes a Florida Nuclear Plant Emergency Notification Form, with NO errors noted on required items (annotated by a *), within 15 minutes. STANDARD Item 2b (astensk) is not critical The date and time of classification on the SNF, Item 5, is a critical step. EVALUATOR CUE: Provide the Applicant with a copy of the Florida Nuclear Plant Emergency Notification Form, F-439 (SNF). Annotate Stop Time when Applicant completes the form. Stop Time: CUE Total Time to Complete F-439: TERMINATING CUE: The task is complete when the Applicant returns the JPM Briefing Sheet to the Evaluator. COMMENT EVALUATOR NOTES: Step by step instructions for completing the Florida Nuclear Plant Emergency Notification Form are contained within 0-EPIP- 20134, Offsite Notifications and Protective Action Recommendations, and Attachment I B. NOTE The time critical element is complete when the Florida Nuclear Plant Emergency Notification Form is complete. See the exam key for a copy of the completed Florida Nuclear Plant Emergency Notification Form. In Step 1 1, the only critical item is that the Applicant checks A No recommended actions at this time. Applicant could enter data such as N/A or none. Stop Time 2011 NRC Exam (SRO) JPM-A.4 NUREG 1021 Rev 9 Appendix C

rAppendix C Page 9 of 10 Form ES-C-I Verification of Completion: Job Performance Measure No. 02201052320 Examinees Name: Examiners Name: Date Performed: Facility Evaluator: Number of Attempts: Time to Complete: Question Documentation: Question:

Response

Resu It: Satisfactory/Unsatisfactory Examiners signature and date: 2011 NRC Exam (SRO) JPM-A.4 NUREG 1021 Rev 9 Appendix C

I Appendix C Page 9 of 10 Form ES-C-I Verification of Completion: Job Performance Measure No. 02201052320 Examinees Name: Examiners Name: Date Performed: Facility Evaluator: Number of Attempts: Time to Complete: Question Documentation: Question:

Response

Result: Satisfactory/Unsatisfactory Examiners signature and date: 2011 NRC Exam (SRO) JPM-A.4 NUREG 1021 Rev 9 Appendix C

JPM BRIEFING SHEET I 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: 0 Unit 3 is in MODE 5 at 185°F, Unit 4 is in MODE 1 at 100% power. o At 0800, a Loss of Off-site Power occurred on Unit 3 due to a loss of the Unit 3 Startup Transformer. o The operating crew implemented 3-ONOP-004, Loss of Offsite Power. o At 0810, the 3A EDG and the 3B EDG tripped and repair teams are investigating.

At 0820, Unit 3 heated up above 200° F
At 0845, NO power is available from any source.
The operators notes the following parameters:

o RCS temperature is 205°F and increasing slowly. o Wind speed is 10mph. o Wind direction is from 180°. Initiating Cue: o You are the Emergency Coordinator in the Control Room. Based upon current plant conditions, classify the event using 0-EPIP-20101, Duties of Emergency Coordinator including Protective Action Recommendations, if any. o Raise your hand as soon as you have classified the event. At that time the examiner will provide you with a copy of the Florida Nuclear Plant Emergency Notification Form, F-439. You will then complete the Florida Nuclear Plant Emergency Notification Form, F-439; using 0-EPIP-20 134, Offsite Notifications and Protective Action Recommendations.

When you have completed the Florida Nuclear Plant Emergency Notification Form, F-439, raise your hand to inform the Examiner you are done.
There are elements of this task that are 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. 2011 NRC Exam (SRO) JPM-A.4 NUREG 1021 Rev 9 Appendix C

JPM BRIEFING SHEET I 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:

Unit 3 is in MODE 5 at 185°F, Unit 4 is in MODE 1 at 100% power.
At 0800, a Loss of Off-site Power occurred on Unit 3 due to a loss of the Unit 3 Startup Transformer.
The operating crew implemented 3-ONOP-004, Loss of Offsite Power.
At 0810, the 3A EDG and the 3B EDG tripped and repair teams are investigating.
At 0820, Unit 3 heated up above 200°F
At 0845, NO power is available from any source.
The operators notes the following parameters:

o RCS temperature is 205°F and increasing slowly. o Wind speed is 10mph. o Wind direction is from 180°. Initiating Cue:

You are the Emergency Coordinator in the Control Room. Based upon current plant conditions, classify the event using 0-EPIP-20101, Duties of Emergency Coordinator including Protective Action Recommendations, if any.
Raise your hand as soon as you have classified the event. At that time the examiner will provide you with a copy of the Florida Nuclear Plant Emergency Notification Form, F-439.

You will then complete the Florida Nuclear Plant Emergency Notification Form, F-439; using 0-EPIP-201 34, Offsite Notifications and Protective Action Recommendations.

When you have completed the Florida Nuclear Plant Emergency Notification Form, F-439, raise your hand to inform the Examiner you are done.
There are elements of this task that are 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. 2011 NRC Exam (SRO) JPM-A.4 NUREG 1021 Rev 9 Appendix C

FLORIDA NUCLEAR PLANT EMERGENCY NOTIFICATION FORM Online Verification: LI STATE LI MIAMI-DADE COUNTY LI MONROE COUNTY A This Is A Drill B. LI This Is An Actual Event -

2. A. Date xxlxxlxx *B. Contact Time:__________ C. Reported by: Name___________________________

0. Message Number:1 E. Reported From: Control Room LI TSC El EOF F. InitiallNew Classification OR LI Update Notification

3 SITE A. LI Grystal River UNIT 3 B. LI St. Lucic UNIT 1 C. LI St. Lucic UNIT 2 D. Turkey Point UNIT 3 E. LI Turkey Point UNIT 4
4 EMERGENCY CLASSIFiCATION: A. LI Notification Of Unusual Event B. Alert C. LI Site Area Emergency D. LI General Emergency
5 A. EMERGENCY DECLARATION: B. LI EMERGENCY TERMINATION Date: XX /XX IXX Time: XX:XX
6. REASON FOR EMERGENCY DECLARATION:** A. EAL Number:CA3 OR B. LI Description______________

7. ADDITIONAL INFORMATION OR UPDATE: A. None OR B. LI Description_______________________________

8. WEATHER DATA: A. Wind direction from 180 degrees. B. Downwind Sectors Affected R,A.B
9 RELEASE STATUS: A. None (Go to Item 11) B. LI In Progress C. LI Has occurred, but stopped (go to Item 11)

10. RELEASE SIGNIFICANCE CATEGORY (at the Site Boundary)

A. LI Under evaluation B. LI Release within Normal Operating Limits (Tech Specs) C. LI Non-Significant (Fraction of PAG Range)D. LI PAG Range (Protective Actions required) E. LI Liquid release (no actions required)

11. UTILITY RECOMMENDED PROTECTIVE ACTIONS FOR THE PUBLIC:

A. 0 No recommended actions at this time. B. LI The utility recommends the following protective actions: EVACUATE ZONES:__________________ OR Miles Evacuate Sectors Shelter Sectors No Action Sectors SHELTERZONES:______________ 0-2 2-5 5-10 AND consider issuance of potassium iodide (Kl) If form is completed in the Control Room, go to item 15. If completed in the TSC or EOF, continue with item 12.

12. PLANT CONDITIONS:

A. Reactor Shutdown? LI YES LI NO B. Core Adequately Cooled? LI YES LI NO C. Containment Intact? LI YES LI NO D. Core Condition: LI Stable LI Degrading

13. WEATHER DATA: A. Wind Speed mph B. Stability Class______

14. ADDITIONAL RELEASE INFORMATION: A. LI Not applicable (Go to Item 15)

Distance Projected Thyroid Dose (CDE) for 1 Hour Projected Total Dose (TEDE) for 1 Hour I Mile (Site Boundary) B. mrem C. mrem 2 Miles D. E. mrem 5 Miles F. mrem G. mrem 10 Miles H. mrem I. mrem

15. (Do not read to State) EC or RM Approval SignatureShift Manager DateX)(IX)(IXX TimeXXXX MESSAGE RECEIVED BY: Name Date I I Time______

IF EMERGENCY CLASS ESCALATION IS KNOWN TO BE NECESSARY AND A NEW NOTIFICATION FORM WILL BE TRANSMITTED WITHIN 15 MINUTES, THEN YOU MAY GO TO EC/RM APPROVAL SIGNATURE LINE. ITEMS ARE EVALUATED FOR NRC PERFORMANCE INDICATORS (PIs) F-43911:2 Rev 9 (11109109)

FLORIDA MJCLEAR PLANT EMERGENCY NOTIFICATION FORM METEOROLOGICAL WORKSREET SECTOR

REFERENCE:

the chart below If the wind direction then the affected SECTOR INFORMATION: WIND SECTOR [A] N [B] NNE [C] NE [Dl ENE [E] E [F] ESE [G] SE [H] SSE [J] S [K] SSW [L] SW [M] WSW [N] W [P] WNW [Q] NW [R] NNW can be used to determine sectors affected by a radiological release, through comparison with wind direction from the meteorological recorders in the Control Room. is directly on the edge of two sectors (e.g., 110, 33°, 56°, etc.), an additional sector should be added to the protective action recommendations. For example, if the wind direction is from 78°, sectors for PARs should be L, M, N and P. WIND FROM DEGREES WIND TOWARD SECTORS AFFECTED 348-11 S HJK 11-33 SSW JKL 33-56 SW KLM 56-78 WSW LMN 78-101 W MNP 101-123 WNW NPQ 123-146 NW PQR 146-168 NNW QRA 168-191 N RAE 191-213 NNE ABC 213-236 NE BCD 236-258 ENE CDE 258-281 E DEF 281-303 ESE EFG 303-326 SE FGH 326-348 SSE GHJ STABILITY CLASSIFICATION

REFERENCE:

Either ERDADS or the below chart can be used to determine atmospheric stability classification for notification to the State of Florida. Primary method is from z\T via the South Dade (60 meter) tower. Backup method is from Sigma Theta via the Ten Meter Tower. If neither meteorological tower is available, Stability Classification shall be determined using data from National Weather Service (See 0-EPIP-20126, Off-site Dose Calculations). CLASSIFICATION OF ATMOSPHERIC STABILITY: Primary Backup Stability Pasquill DeltaT Sigma Theta Classification Categories (°F) Range (Degrees) Extremely unstable A AT-1.7 ST22.5 Moderately unstable B -1.7<AT-l.5 22.5>ST 17.5 Slightly unstable C -1.5<AT-1.4 17.5> ST 12.5 Neutral D -1.4 <AT -0.5 12.5>ST7.5 Slightly stable E -0.5 <AT +1.4 7.5>ST3.8 Moderately stable F +1.4 <AT +3.6 3.8> ST2.1 Extremely stable C +3.6 <AT 2.1 > ST Meteorological information needed to fill out the Florida Nuclear Plant Emergency Notification Form is available from the Dose Calculation Worksheet (0-EPLP-20126). The Worksheet shall be filled out by Chemistry and given to the Emergency Coordinator. F-439!2:2 Rev 9 (11109109)

FLORIDA NUCLEAR PLANT EMERGENCY NOTIFICATION FORM Online Verification: El STATE LI MIAMI-DADE COUNTY LI MONROE COUNTY i A. . This IsA Drill B. ThisisAnActual Event

2. A. Date I I *B. Contact Time:________ C. Reported by: Name____________________________

D. Message Number:___________________ E. Reported From: LI Control Room LI TSC LI EOF F. LI InitiallNew Classification OR El Update Notification

 *3 SITE         A. LI Crystal Rivcr UNIT 3            B. El       St. Lucic UNIT I          C. El      St. Lucic UNIT 2 D. El Turkey Point UNIT 3             E. El       Turkey Point UNIT 4 EMERGENCY CLASSIFICATION:             A. LI Notification Of Unusual Event          B. LI Alert

[ C. LI Site Area Emergency D. LI General Emergency [*5 A. LI EMERGENCY DECLARATION: B. LI EMERGENCY TERMINATION Date: I I Time: I

 *6. REASON FOR EMERGENCY DECLARATION:** A. El EAL Number:                                      OR B. LI Description_____________

7. ADDITIONAL INFORMATION OR UPDATE: A. El None OR B. LI Description_______________________________

 *3 WEATHER DATA:             A. Wind direction from                            B. Downwind Sectors Affected
 *9 RELEASE STATUS: A.

El None (Go to Item II) B. LI In Progress C. El Has occurred, but stopped (go to Item 11)

10. RELEASE SIGNIFICANCE CATEGORY (at the Site Boundary)

A. LI Under evaluation B. LI Release within Normal Operating Limits (Tech Specs) C. LI Non-Significant (Fraction of PAG Range)D. El PAG Range (Protective Actions required) E. El Liquid release (no actions required) ll. UTILITY RECOMMENDED PROTECTIVE ACTIONS FOR THE PUBLIC: A. LI No recommended actions at this time. B. LI The utility recommends the following protective actions: EVACUATE ZONES:__________________ OR Miles Evacuate Sectors Shelter Sectors No Action Sectors SHELTERZONES:______________ 0-2 2-5 5-10 AND consider issuance of potassium iodide (KI) If form is completed in the Control Room, go to item 15. If completed in the TSC or EOF, continue with item 12.

12. PLANT CONDITIONS:

A. Reactor Shutdown? LI YES LI NO B. Core Adequately Cooled? El YES El NO C Containment Intact? LI YES LI NO D. Core Condition: LI Stable LI Degrading

13. WEATHER DATA: A. Wind Speed mph B. Stability Class_______

14. ADDITIONAL RELEASE INFORMATION: A. LI Not applicable (Go to Item 15)

Distance Projected Thyroid Dose (CDE) for 1 Hour Projected Total Dose (TEDE) for 1 Hour I Mile (Site Boundary) B._ mrem C. mrem 2 Miles D. mrem E. mrem 5 Miles F._ mrnm G. mrem 10 Miles H. mrem I. mrem

15. (Do not read to State) EC or RM Approval Signature Date I I Time_______

MESSAGE RECEIVED BY: Name Date I I Time______ IF EMERGENCY CLASS ESCALATION IS KNOWN TO BE NECESSARY AND A NEW NOTIFICATION FORM WILL BE TRANSMIUED WITHIN 15 MINUTES, THEN YOU MAY GO TO EC/RM APPROVAL SIGNATURE LINE. ITEMS ARE EVALUATED FOR NRC PERFORMANCE INDICATORS (PIs) F-43911:2 Rev 9(11109/09)

FLORIDA NUCLEAR PLANT EMERGENCY NOTIFICATION FORM METEOROLOGICAL WORKSHEET SECTOR

REFERENCE:

The chart below can be used to determine sectors affected by a radiological release, through comparison with wind direction from the meteorological recorders in the Control Room. If the wind direction is directly on the edge of two sectors (e.g., 11°, 330, 56°, etc.), an additional sector should be added to the protective action recommendations. For example, if the wind direction is from 78°, then the affected sectors for PARs should be L, M, N and P. SECTOR INFORMATION: WINI) SECTOR WIND FROM DEGREES WINI) TOWARD SECTORS AFFECTED [A] N 348-11 S HJK [B] NNE 11-33 SSW JKL [C] NE 33-56 SW KLM [D] ENE 56-78 WSW LMN [E] E 78-101 W MNP [F] ESE 101-123 WNW NPQ [G] SE 123-146 NW PQR [H] SSE 146-168 NNW QRA [J] S 168-191 N RAB [K] SSW 191-213 NNE ABC [L] SW 213-236 NE BCD [M] WSW 236-258 ENE CDE [N] W 258-281 E DEF [P] WNW 281-303 ESE EFG [Q] NW 303-326 SE FGH [R] NTh4W 326-348 SSE GHJ $TABILITY CLASSIFICATION

REFERENCE:

Either ERDADS or the below chart can be used to determine atmospheric stability classification for notification to the State of Florida. Primary method is from z\T via the South Dade (60 meter) tower. Backup method is from Sigma Theta via the Ten Meter Tower. If neither meteorological tower is available, Stability Classification shall be determined using data from National Weather Service (See 0-EPIP-20126, Off-site Dose Calculations). CLASSIFICATION OF ATMOSPHERIC STABILITY: Primary Backup Stability Pasquill Delta T Sigma Theta Classification Categories (°F) Range (Deees Extremely unstable A AT -1.7 ST22.5 Moderately unstable B -1.7 <AT -1.5 22.5>ST 17.5 Slightly unstable C -1.5 <AT -1.4 17.5> ST 12.5 Neutral D -1.4 <AT -0.5 12.5 > ST 7.5 Slightly stable E -0.5 <AT +1.4 7.5>ST3.8 Moderately stable F +1.4 <AT +3.6 3.8> ST 2.1 Extremely stable G +3.6 <AT 2.1 > ST Meteorological information needed to fill out the Florida Nuclear Plant Emergency Notification Form is available from the Dose Calculation Worksheet (0-EPIP-20 126). The Worksheet shall be filled out by Chemistry and given to the Emergency Coordinator. F-43912:2 Rev 9 (11109109)

GUIDANCE FOR DETERMINING PROTECTIVE ACTION RECOMMENDATIONS (PARS) BASED ON PLANT CONDITIONS General No recommended Emergency? actions at this time H (Note 3) YES Mjis Evacuate Sectors Shelter Sectors No Action Sectors 0-2 NONE ALL NONE NO 2 5

                                                                     -        NONE           (sectors affected)   ALL REMAINING 5-10      NONE               NONE                   ALL (Note 3)

YES YES MHes Evacuate Sectors 1 Shelter Sectors No Action Sectors Continue to Assess Conditions and Evaluate 0-2 ALL NONE NONE further Protective Action 2 5

      -      (sectors affected)  ALL REMAINING        NONE                                                        Recommendations based on 5-10         NONE                ALL              NONE                                                          0ff-Site Dose Projections (Note 3)

NOTES: (1) Severe core damage is indicated by any of the following:

        - Loss of critical functions required for core protection (e.g. loss of injection with LOCA)
        - High Core temperatures (Valid CET> 700°F)
        - CHRRM Reading of greater than or equal to 1 .3E4 RIhr (2)      Loss of physical control of Control Room or reactor operating areas required for continued safe plant operation to intruders.

(3) See additional Guidance for Determining PARs in Emergency Plan Implementing Procedures. F444/1:5 Rev. 4 (0-EPIP-20134)

BASED ON MANUAL DOSE CALCULATIONS RELEASE DURATION LESS THAN 2 HOURS (PUFF RELEASE) Beyond 10 miles use this column and the 10 mile dose value. Total Dose Thyroid Dose 0-2 Miles 2-5 Miles 5-10 Miles TEDE OR CDE Dose (mRem) (mRem) Use 1 Mi. value Use 2 Mi. Value Use 5 Mi. Value

                  < 500 mRem          <1000 mRem          None             None            None 500mRem            l000mRem            S(ALL) but                 but                            S(DW)           S(DW)
                  <1000 mRem          <5000 mRem l000mRem           S000mRem            S(ALL) but                 but                           S(ALL)          S(ALL)
                  <5000 mRem        < 25000 mRem 5000 mRem          25000 mRem        E(ALL)       E(DW)+S(AR)    E(DW)+S(AR)

RELEASE DURATION GREATER THAN OR EOUAL TO 2 HOURS Beyond 10 miles use this column and the 10 mile dose value. Total Dose Thyroid Dose 0-2 Miles 2-5 Miles 5-10 Miles TEDE OR CDE Dose (mRem) (mRem) Use 1 Mi. value Use 2 Mi. Value Use 5 Mi. Value

                  < 500 mRem          <1000 mRem          None             None            None 500 mRem           1000 mRem but                 but           S(ALL)           S(DW)           S(DW)
                  <1000 mRem          <5000 mRem 1000 mRem             5000 mRem but                 but           E(ALL)       E(DW)+S(AR)    E(DW)+S(AR)
                  <5000 mRem         < 25000 mRem 5000 mRem          25000 mRem        E(ALL)          E(ALL)      E(DW)+S(AR)

SUMMARY

0-2M1. 25M1. 51OMI. PARs based on Plant Conditions PARs based on Total Dose (TEDE) PARs based on Thyroid Dose (CDE) Most Conservative PARs based on Plant Conditions and Dose Projections LEGEND OF ABBREVIATIONS S Sheltering recommended E Evacuation recommended DW Downwind plus 2 adjoining sectors AR All Remaining sectors ALL All Sectors F44412:5 Rev. 4 (O-EPIP-20134)

CAUTION Previously issued PARs, unless found to be less conservative, are to remain in effect until the source of the threat is clearly under control. FPL is required to provide county and state governmental authorities with recommendations for protective action to be taken by the public during radiological emergencies at the Turkey Point Nuclear Plant. The responsible authorities are the State Division of Emergency Management (DEM), Miami-Dade County Office of Emergency Management and Monroe County Office of Emergency Management. Protective Action Recommendations (PARs) should be made utilizing all of the available data. This includes plant status, off-site dose projections, and/or field monitoring data. The more conservative recommendations should be made. Beginning at the top left side, answer the General Emergency question. If yes, continue on, following the arrows, and answering the other question blocks. Record the PARs based on Plant Condition (A) in the Summary Block at the bottom of the page. From the PAR based on Plant Conditions block continue following arrow to next box, and determine PARs based on Off-site Dose Projections (B) Total Dose (TEDE) and Thyroid Dose (CDE). In determining PARs, both plant conditions AND off-site doses must be considered for all PARs. If a release has not occurred, then proceed with issuance of PARs from the plant condition determination. To determine PARS from off-site doses, find the blocks that correspond with the Total Dose (TEDE) and Thyroid Dose (CDE) at 1, 2 and 5 miles from the Dose Calculation Worksheet (O-EPIP-20126). Follow across to the colunm that indicates the distance where that dose was found i.e., first block for 1 mile, second block for 2 miles, or third block for 5 miles. (B) Record the PARs based on Off-site Doses in the Summary Block. Once PARs are determined for all mile sectors for both Total Dose (TEDE) and Thyroid Dose (CDE) (B), then a comparison with the Plant Condition PARs (A) is performed, and the most conservative PARs for ach mile sector is selected for issuance to off-site agencies. The following example is provided: EXAMPLE A release has occurred at the Turkey Point Plant. The wind direction is from the SSE and the projected off-site accumulated Thyroid Dose (CDE) is 5,000 mRem at I mile, 1,000 mRem at 2 miles, and less than 1,000 mRem at 5 miles. The plant is in a General Emergency with CHRRM at 100 R/hr, no core damage indicators, and no loss of physical control of the plant. F44413:5 Rev. 4 (O-EPP-2O134)

Using the PAR Worksheet, the following recommendations should be made: Based on our current assessment of all the information now available to use, Florida Power & Light Company ecommends that you consider taking the following protective actions. A. EVACUATE all people between 0 and 2 miles from the plant. B. SHELTER all people between a 2 and 5 mile radius form the plant who are in Sectors Q, R, and A (refer to Attachment 1). C. No protective actions is recommended between a 5 and 10 mile radius from the plant. Due to the large political and legal ramifications of these recommendations and the potential impact on FPL, the following guidelines, format, and content should be used. (1) If the emergency has not been classified as a GENERAL EMERGENCY and the off-site doses are LESS THAN 500 mRem Total Dose (TEDE) or 1,000 mRem Thyroid Dose (CDE) at 1 mile over the projected duration of the release, no protective action is recommended. When reporting to DEM and other off-site agencies who inquire, this should be reported in a manner similar to the following: Based on our urgent assessment of all the information now available to us, Florida Power & Light Company recommends that you consider taking the following protective actions - NONE. This recommendation may change in the ftiture, but we cannot now say when it may change or what the change may be. (2) When available, both plume calculation and off-site monitoring results should be evaluated when making protective action recommendations. If significant discrepancies exist between field monitoring results and plume dispersion calculations, then the discrepancy should be reviewed, and the appropriate value should be selected in the determination of protective action recommendations.

3) Thyroid Dose (CDE) Limits for PARs are based on adult thyroid. These limits are consistent with EPA Guidelines based on the following criteria:

a. Uncertainty and potential errors associated with age specific parameters, and

b. Level of conservatism in the adult values.

(4) Loss of physical control of the plant to intruders shall be determined by the Emergency Coordinator based on the current operating mode requirements of the unit / plant, and the availability of equipment required for continued safe operation. F44414:5 Rev. 4 (O-EPIP-201 34)

GUIDANCE FOR THE USE OF P0

1. The EOF RP Manager in consi dispense Potassium Iodide (KI) b (CDE) of greater than or equal to on the FDA recommended thresh

2. The TSC RP Supervisor and the for use has been determined.

3. The TSC RP Supervisor is respc Room and the TSC and Field Mo]

4. The OSC RP Supervisor is respor

5. KI should be administered and i:

CDE is greater than or equal to 5

6. When KI is issued, thyroid intake

7. Administering KI after an uptake

8. Caution emergency response per iodide. Emergency response pen of directing them to ingest KI.

9. All KI tablets are stored in the Monitoring Team Kits.

F44415:5 Rev. 4 (O-EPIP-20134)

Florida Power & Light Company Turkey Point Nuclear Plant

Title:

Offsite Notifications and Protective Action Recommendations (Information Use) Safety Related Procedure Responsible Department: Emergency Preparedness Revision Number: 1 Issue Date: 7/20/11 Revision Approval Date. 7/19/11 ARs 1667362 PCRs 08-4233, 08-3496, 08-4878, 08-48 79, 09-0698 09-2836, 10-0765, 1 0-0069, 10-1926 W2003:MEImr/cls/cls

Procedure No.: Procedure

Title:

Page: 2 Offsite Notifications and Protective Action Approval Date: O-EPLP-20 134 Recommendations 7/19/11 LIST OF EFFECTIVE PAGES (Rev. 1) Revision Revision Date Date 1 07/19/11 21 07/19/11 2 07/19/11 22 07/19/11 3 05/27/10 23 06/08/10 4 11/10/08 24 06/08/10 5 11/10/08 25 11/09/09 6 04/17/08 26 11/09/09 7 04/17/08 27 05/27/10 8 11/09/09 28 05/27/10 9 11/10/08 29 05/27/10 10 11/09/09 30 05/27/10 11 09/23/08 31 05/27/10 12 04/17/08 32 05/27/10 13 04/17/08 33 05/27/10 14 11/10/08 34 07/19/11 15 04/17/08 35 07/19/11 16 11/10/08 36 07/19/11 17 11/10/08 37 07/19/11 18 11/09/09 38 07/19/11 19 11/09/09 20 07/19/11

Procedure No.: Procedure

Title:

Page: 3 Offsite Notifications and Protective Action Approval Date: 0-EPIP-20 134 Recommendations 5/27/10 TABLE OF CONTENTS Section Page 1.0 PURPOSE 4

2.0 REFERENCES

/RECORDS REQUIRED/COMMITMENT DOCUMENTS 7 3.0 RESPONSIBILITIES 8 4.0 DEFINITIONS 9 5.0 PROCEDURE 5.1 General 11 5.2 OffSite Notifications During Security Related Events 13 5.3 Off-Site Notifications From Control Room, TSC or EOF 14 ATTACHMENTS Attachment I Florida Nuclear Plant Emergency Notification Form 18 Attachment 1A Florida Nuclear Plant Emergency Notification Form 19 Attachment lB Directions for Completing the Florida Nuclear Plant Emergency Notification Form 20 Attachment 1C EAL Descriptions for Florida Nuclear Plant Emergency Notification Form 27 Attachment 2 Event Notification Worksheet 30 Attachment 2A Directions for Completing The NRC Reactor Plant Event Notification Worksheet 32 Attachment 3 Guidance For Determining Protective Action Recommendations (PARs) 34

Procedure No. Procedure

Title:

Page: 4 Offsite Notifications and Protective Action Approval Date: 0-EPIP-20 134 Recommendations 11/10/08 LU PURPOSE 1.1 This procedure provides information and instructions for performing notification to the State of Florida and the Nuclear Regulatory Commission (NRC) and for determination of protective action recommendations (PARs). 1.2 This procedure is for use in the Control Room, Technical Support Center (TSC) and Emergency Operations Facility (EOF). 1.3 Upon declaration of an emergency classification the Shift Manager (SM) assumes the duties of the Emergency Coordinator (EC). The EC has initial responsibility for off-site notifications and PARs 1.4 Once the EOF is operational and proper turnover has been conducted, the Recovery Manager (RiM) assumes responsibility for off-site notifications and PARs from the EC 1.5 At an Alert or higher level emergency, communications with the NRC transition to an open phone line from the TSC and the EOF (at a Site Area Emergency or higher level emergency). 1 NOTE The State of Florida Department of Health (Bureau of Radiation Control) may not have their office staffed on a 24-hour basis. In the event that they do not answer the Hot Ring Down (HRD) telephone, the state assumes responsibility for notifying their duty officer. However the EC/RM shall verify that the Bureau of Radiation Control has been notified. I a a a a a a I 1.6 Who Shall Be Notified

State of Florida Division of Emergency Management
State of Florida Department of Health (Bureau of Radiation Control)
Miami-Dade County Emergency Operations Center
Monroe County Emergency Operations Center
NRC 1.6.1 State and County Notification

1. State and local agencies are notified by using the Hot Ring Down (HRD) telephone. The HRD rings the State. The state puts the other agencies on line and reduces the need for individual calls.

1.6.2 NRC Notification

1. The NRC is notified using the Emergency Notification System (ENS) telephone.

2. NRC notifications occur through an open line of communication in the TSC and, when operational, the EOF.

Procedure No.: Procedure

Title:

Page: Offsite Notifications and Protective Action Approval Date: 0-EPIP-20 134 Recommendations 11/10/08 1.6.3 Emergency Follow-up Information Requests from State and Local Agencies.

1. Incoming calls should come via the state over the HRD phone. If the HRD is inoperable, the state may use commercial telephone or ESATCOM (emergency satellite phone). If an off-site authority contacts the plant without going through the State, request that they contact the state. The state shall verif,i that the agency calling is a risk county or the Department of Health (DOH) and shall notify other county and state agencies of the updated information, thus reducing the number of calls that may be directed to the plant.

2. Long, detailed explanations of plant systems or reactor theory should be avoided. If prompted for this kind of information by the State Duty Officer, he / she should be referred to the Nuclear Division Duty Officer (NDDO).

3. If the State or one of the Counties provides either the TSC or EOF with new or pertinent information, Then bring that information to the attention of the EC or EC Assistant / Logkeeper in the TSC or the RM or the RM OPS Advisor / Logkeeper in the EOF.

1.7 Protective Action Recommendations 1.7.1 Protective actions for the general public are ordinarily NOT required prior to declaration of a General Emergency. It is possible however, that due to unusually stable and constant meteorological conditions, protective actions could be recommended at a Site Area Emergency based on projected doses. This is the exception rather than the rule. Protective actions for the general public are required to be recommended if a General Emergency is declared. Initial Protective Action Recommendations (PARs) are normally based on plant conditions. This would NOT be true if the General Emergency was declared based on off-site dose (either measured or projected) or a Security Emergency (per the Security Plan). The predetermined minimum PARs (based on plant conditions) are as given below. 1.7.2 General Emergency Minimum Pars

1. In any case where a GENERAL EMERGENCY has been declared, the minimum PAR shall be:

2. Shelter all people within a 2-mile radius and out to 5 miles in the sectors affected. The sectors affected are at least three, the downwind sector plus the two adjacent sectors.

1.7.3 If a GENERAL EMERGENCY has been declared due to actual or projected severe core damage, the minimum PAR shall be:

1. Evacuate all people within a 2-mile radius from the plant and out to 5 miles in the sectors affected. Shelter all people in the remaining sectors from 2 to 5 miles and from 5 to 10 miles from the plant.

W2003:ME/mr/cls/cls

Procedure No.: Procedure

Title:

Page: Offsite Notifications and Protective Action Approval Date: 0-EPIP-20 134 Recommendations 4/17/08 1.7.4 If a GENERAL EMERGENCY has been declared due to loss of physical control of the plant to intruders, including the Control Room or any other area(s) vital to the operation of the reactor system (as defined in the Security Plan), the minimum PAR shall be:

1. Evacuate all people within a 2-mile radius from the plant and out to 5 miles in the sectors affected. Shelter all people in the remaining sectors from 2 to 5 miles and from 5 to 10 miles from the plant.

1.7.5 Once a release of radioactive material occurs, dose assessment should be utilized when evaluating PARs. The final determination of the PAR should consider all available information including off-site dose projections, plant conditions and field monitoring data. The most conservative recommendation shall be made. 1.7.6 If it is anticipated that a PAR threshold will be exceeded, DO NOT wait until the threshold is exceeded to make that PAR. 1.7.8 Conditions (plant information, dose projections and field monitoring results) are to be continually assessed and PARs expanded, as necessary, to ensure that adequate (most conservative) PARs are issued. W2003:ME/mr/cls/cls

Procedure No.: Procedure

Title:

Page: 7 Offsite Notifications and Protective Action Approval Date: 0-EPIP-20 134 Recommendations 4/17/08

2.0 REFERENCES

/RECORDS REOUIRED/COMMITMENT DOCUMENTS 2.1 References 2.1.1 Plant Procedures

1. 0-EPIP-20101, Duties of the Emergency Coordinator

2. 0-EPIP-1212, Emergency Operations Facility (EOF) Activation and Operation

3. 0-EPIP-20 104, Emergency Response Organization Notifications/Staff Augmentation

4. 0-EPIP-20 132, Technical Support Center (TSC) Activation and Operation 2.1.2 Regulatory Guidelines

1. Turkey Point Radiological Emergency Plan.

2. 10 CFR 50.47, Emergency Plans 2.1.3 Miscellaneous Documents (i.e., PC/M, Correspondence)

1. PC/M 04-112, Emergency Response Data Acquisition and Display System (ERDADS) Replacement

2. Letter to Emergency Preparedness from State of Florida Division of Emergency dated October 12, 2007 2.2 Records Required 2.2.1 Completed originals of the below listed items constitute Quality Assurance records and shall be transmitted to QA Records for retention in accordance with Quality Assurance Records Program requirements:

1. Subsections of this procedure required to be completed during the performance of this procedure:

a. Forms similar to Attachment 1

b. Forms similar to Attachment 2

Procedure No.: Procedure

Title:

Page: 8 Offsite Notifications and Protective Action Approval Date: 0-EPIP-20 134 Recommendations 11/9/09 3.0 RESPONSIBILITIES 3.1 Emergency Coordinator 3.1.1 Emergency Coordinator (EC) Responsible for classifications, notifications and PARs. 3.1.2 Recovery Manager Responsible for notifications and PARs. When EOF is operational 3.1.3 TSC Supervisor Responsible for ensuring communication links are functional. Also responsible for ensuring initial and follow-up notifications to the State of Florida, Miami-Dade County, and Monroe County are provided. 3.1.4 The Technical Assist to the Emergency Coordinator Assists the EC in developing Protective Action Recommendations based on plant conditions and Off-site Dose Projections. 3.1.5 TSC Operations Manager Provides Protective Action Recommendations to the EC based on plant conditions. 3.1.6 TSC ENS Communicator Assists at the TSC with notification form preparations and makes the calls to complete notifications to the NRC. 3.1.7 EOF ENS Communicator Assists at the EOF with notification form preparations and makes the calls to complete notifications to the NRC. 3.1.8 EOF Radiation Protection Manager Assists the Recovery Manager with Radiological Dose Assessment Data and PARs. 3.1.9 EOF State and County Communicator Assists at the EOF with notification form preparations and makes the calls to complete notifications to the state. 3.1.10 TSC State and County Communicator Assists at the TSC with notification form preparations and makes the calls to complete notification to the state.

Procedure No.: Procedure

Title:

Page: 9 Offsite Notifications and Protective Action Approval Date: 0-EPIP-20134 Recommendations 11/10/08 4.0 DEFINITIONS 4.1 Emergency any off-normal event or condition which is classified into one of the four event categories in Enclosure 1 of this procedure. 4.2 Emergency Notification System (ENS) the circuit tying the NRC and Turkey point. 4.3 Emergency Response Directory (ERD) the directory containing names and phone numbers of Emergency Response Organization personnel. 4.4 ESATCOM Satellite based backup communications system for notifications to the state. 4.5 Florida Nuclear Plant Emergency Notification Form the form used to initiate, update, and terminate emergency notifications to State and Local Counties. 4.6 Hot Ring Down Telephone (HRD) the dedicated link between State/Counties and Turkey Point. 4.7 Local Government Radio (LGR) the communications network used as a backup to the NRD. 4.8 Off-site Power power supplied from the grid through the Startup or Auxiliary Transformers (backfeed), or power supplied by the Auxiliary Transformer during normal operation. 4.9 On site within the Protected Area. 4.10 Owner Controlled Area that portion of the FPL property surrounding and including the Turkey Point Plant, which is subject to limited access and control as deemed appropriate byFPL. 4.11 Power Block structures comprising all permanent nuclear, power generation, and cooling structures, systems, and components within the Protected Area and permanent safety related or quality related utilities (e.g., air, water and electric) both inside and outside the Protected Area. The Power Block does not include the switchyard (Reference CR-96-881). 4.12 Protective Action Recommendations (PARs) Recommendations, for action instructions to protect the public, made by the Emergency Coordinator or Recovery Manager to State and County officials. FPL may recommend No Action, Sheltering or Evacuation. 4.13 Recovery Manager (RM) A designated company officer or senior manager, who will have responsibility for the direction and control of the EOF. He / she has the authority to establish policy and to expend funds necessary to cope with emergency situations that trigger the implementation of the Emergency Plan. \AIflAI/rnrfr1/rI

Procedure No.: Procedure

Title:

Page: 10 Offsite Notifications and Protective Action Approval Date: O-EPIP-20134 Recommendations 11/9/09 4.0 DEFINITIONS (Contd) 4.14 Release 4.14.1 IF as a result of accident conditions ANY of the following is true: o A rise of (approximately) 10 times or one decade above pre-transient values is seen on one of the following accident assessment monitors:

Plant Vent (RAD 6304 or R-14)
Spent Fuel Pool Vent (RAD 6418)
Steam Jet Air Ejector (RAD 6417 or R-15)
Dam-i Main Steam (RAD 6426)
Radiation Protection detects unplanned elevated airborne radiation levels outside of plant buildings due to accident conditions.

o A Steam Generator, with primary to secondary leakage due to a tube leak or rupture is vented to atmosphere and/or feeding the (operating) steam driven AFW pump. THEN a RELEASE is in progress. 4.15 Shift Communicator A specific shiftly designated individual trained and qualified to assist the Shift Manager/Emergency Coordinator in the control room in making emergency off-site notifications, and performing other activities as directed. 4.16 State Notification Form (SNF) Less formal, more concise expression used in lieu of Florida Nuclear plant Emergency Notification Form W2flflMPImrfrIsIrls

Procedure No.: Procedure

Title:

Page: Offsite Notifications and Protective Action Approval Date: O-EPIP-20134 Recommendations 9/23/08 5.0 PROCEDURE 5.1 General 5.1.1 The Emergency Coordinator (EC) can delegate responsibilities to subordinates with the exception of classification, the decision to notifSi Federal, State, and Local authorities, and the issuing of Protective Action Recommendations (PARs). The actual notification can be done by the EC designee. Notification of off-site agencies and PARs become the responsibility of the Recovery Manager (RM) when the EOF is manned and operational. The EC documents the decision to notifi State and Local authorities and documents EC concurrence with PARs by signing a form similar to Attachment 1. 5.1.2 Procedural notification steps may be performed out of sequence in order to meet State of Florida andlor NRC notification time requirements. 5.1.3 During exercises, drills or tests, ALL MESSAGES shall begin and end with THIS IS A DRILL. 5.1.4 In any case where a General Emergency has been declared, the minimum protective action recommendation shall be: Shelter all people within a 2 mile radius from the plant and 5 miles in the down wind sectors. 5.1.5 The Emergency Coordinator responsibilities shall reside with the EC in the Control Room until they have been formally transferred to the EC in the TSC. 5.1.6 Emergency notification to State and Local Counties is required within 15 minutes of declaring an emergency. 5.1.7 Emergency notification to the NRC is required immediately following notification of State and Counties, but not later than 1 hour from the declaration of an emergency. 5.1.8 If, during the notification process, it becomes necessary to upgrade the emergency classification:

1. Update the notification to reflect the higher emergency classification and complete the update notifications within 15 minutes of the lesser emergency declaration.

2. If the notification cannot be updated and completed within 15 minutes of the lesser emergency declaration, the ERO should make the declaration of the lesser emergency within 15 minutes of its declaration. The notification can contain the caveat that a change in classification was forthcoming.

3. At no time will there be a restart of the notification clock.

AIflflflO.AClI,,I,.I.I.

Procedure No.: Procedure

Title:

Page: U. Offsite Notifications and Protective Action Approval Date: 0-EPIP-20 134 Recommendations 4/17/08 5.1.9 Plant conditions, plume dose projection calculations, (from 0-EPIP-20 126, Off-site Dose Calculations), and off-site monitoring results should be evaluated when making Protective Action Recommendations. If significant discrepancies exist between field monitoring results and plume dose projection calculations, an evaluation should be made, and the most conservative approach used in the determination of Protective Action Recommendations.

1. De-escalation of the event does not mean that protective actions for the General Public would be reduced or terminated.

2. Previously issued PARs, unless found to be less conservative, are to remain in effect until the source of the threat is clearly under control.

3. Only State and County officials can implement, change and/or terminate protective actions.

5.1.10 If a condition, which meets the Unusual Event or Alert criteria of Enclosure 1 is identified and subsequently rapidly resolved, the emergency classification shall be declared and immediately terminated. All required notifications shall be completed. Activation of the On-site Emergency Response Facilities is not required. 5.1.11 If a condition which meets the Site Area Emergency or General Emergency criteria of Enclosure 1 EPIP 20101 (Emergency Classification Table) is identified and subsequently rapidly resolved, the emergency shall be declared and all notifications completed. De-escalation from the Site Area Emergency and General Emergency classifications may only be authorized by the Recovery Manager. 5.1.12 Protective Action Recommendations based upon off-site dose calculations shall be determined by comparing projected off-site doses to the action levels in Attachment 3. If the period of exposure is expected to be less than 2 hours the doses should be projected for the expected duration of the exposure. For longer duration exposures, the off-site doses should be projected for 2 hours and PARs should be based upon the 2 hour projections. 5.1.14 Alternate commercial telephone numbers for State of Florida and NRC notification are listed in the Emergency Response Directory (ERD). 5.1.15 Collection of Release Rate Data shall not delay State of Florida and NRC notifications. If the data is not available, notification shall be made and followed up as soon as the information is available. W2flflMT!mr/cIs/cIs

Procedure No.: Procedure

Title:

Page:

               -                                                    -                                   13 Offsite Notifications and Protective Action              Approval Date:

0.EPIP 20134 Recommendations 4/17/08 5.1.16 One of the primary reasons for the declaration and notification process is to prompt Local, State, and Federal Government Agencies to initiate actions to assure the health and safety of the public. The Government Agency response is based on an event affecting either unit at a multiple unit site, such as PTN. Therefore, the Government Agency actions will address the most severe classification issued by the site, and having multiple classifications would only confuse the response. Examples regarding this issue are provided below.

1. If Unit 3 is in a classified event (an Alert, for example), and another event of the same of lesser classification (e.g., an Unusual Event or Alert) occurs on Unit 3 or Unit 4, then a new event classification should not be made, and the event notification should be issued as an update, at the earliest practical time.

2. If Unit 3 is in a classified event (an Alert, for example), and another event of higher classification (Site Area or General Emergency) occurs on either Unit 3 or Unit 4, then the new classification should be promptly issued to the State and NRC within the regulatory time requirements.

3. The Florida Nuclear Plant Emergency Notification Form (a form similar to Attachment 1) should indicate the unit for which the event is declared. If the event is common to both units, such as the approach of a hurricane, both PTN boxes should be checked.

5.2 Off-Site Notifications during Security Related Events 5.2.1. Make an accelerated notification to the NRC TIME Accelerated notification to the NRC Operations Center, ENS phone number 301-816-5100, shall be made within 15 minutes of authentication of the threat. 5.2.2. Airborne Threatabbreviated State Notification prepare a State TIME Notification Form by filling out lines 1 through 6 and 11. W2flfl:MP/mr/cIs/ds

Procedure No.: Procedure

Title:

Page: 14 Offsite Notifications and Protective Action Approval Date: 0-EPIP- 20134 Recommendations 11/10/08 5.3 Off-Site Notifications from Control Room, TSC or EOF CAUTI ONS

Notification to the State of Florida is required within 15 minutes of Emergency Classification.
Notification to the NRCOC is required to immediately follow the State Notification and no later than one hour.
Collection of Release Rate Data shall not delay State of Florida or NRC Notification.
If a transitory event has occurred, notifications are still required using this procedure.

NOTE If during the notification process it becomes necessaiy to upgrade the emergency classification:

Update the notification to reflect the higher emergency classification and complete the update notifications within 15 minutes of the lesser emergency declaration.
If the notification cannot be updated and completed within 15 minutes of the lesser emergency declaration, the ERO should make the notification for the lesser II emergency within 15 minutes of its declaration. The notification can contain the caveat that a change in classification was forthcoming.

At no time will there be a restart of the notification clock. 5.3.1 State and County Notification

1. Time Limits

a. Notification shall be initiated within 15 minutes of any of the following:

(1) Recognition of entry into the Emergency Plan (2) Escalation in Emergency Class. (3) De-escalation of the Emergency Class. (4) Protective Action Recommendation. (5) Change in Protective Action Recommendation W2003:ME/mr/cls/cls

Procedure No: Procedure

Title:

Page: 15 Offsite Notifications and Protective Action Approval Date: 0-EPJP- 20134 Recommendations 4/17/08 5.3.1 (Contd) a a a a Update notifications should occur about eveiy 60 minutes unless the clock has started for D 0 a regulatoiy-based 15 minute notification which takes precedence a I

                          =          a              a      a          a             a      a

2. Notification should be initiated within 60 minutes of any of the following:

a. At an Alert or higher Emergency Class, the time of the last update (unless a different frequency has been agreed to by the off-site agencies as during a hurricane).

b. A radiological release has been initiated.

c. A radiological release has been terminated.

d. A significant change in plant conditions has occurred (e.g., loss or restoration of off-site power or major plant equipment).

e. Termination of the emergency.

5.3.2 Florida Nuclear Plant Emergency Notification Form CAUTION

                 . Notifications require the use of a form similar to Attachment 1, Florida Nuclear Plant Emergency Notification Form.

1. Notifications with 15 minute or 60 minute time limit shall be made using a form similar to Attachment 1, Florida Nuclear Plant Emergency Notification Form.

a. In the Control Room, lines 1 through 11 of the Florida Nuclear Plant Emergency Notification Form shall be completed and the form shall be approved by the Emergency Coordinator prior to transmittal.

b. In the Technical Support Center, lines 1 through 15 of the Florida Nuclear Plant Emergency Notification Form shall be completed and the form shall be approved by the Emergency Coordinator prior to transmittal.

c. In the Emergency Operations Facility, lines 1 through 15 of the Florida Nuclear Plant Emergency Notification Form shall be completed and the form shall be approved by the Recovery Manager prior to transmittal 5.3.3. IF Off-site (State and County) notifications responsibilities are with the Emergency Coordinator on site, THEN complete the following steps:

1. Complete a form similar to Attachment 1.

TIME

2. Obtain the initials of the Emergency Coordinator or Recovery Manager TIME on the notification form prior to transmitting the information.

W2003:ME/mrlcls/cls

Procedure No.: Procedure

Title:

Page:

                                                                                       -                       16 Offsite Notifications and Protective Action                Approval Date:

0-EPIP- 20134 Recommendations 11/10/08 5.3.3 (Contd) NOTES I The state may request verification call back. If requestecJ the state will call in on the black bell phone (ringmaster) or cellular phone in the Control Room. I I . If either of the counties (Miami-Dade County, Monroe County) are not on line during the notification with the state, follow up with the state to ensure contact is made or directly contact the counties to convey the message form information. (10 CFR 50 I Appendix E, requires licensees to notify the State and Local Government) I 1

3. Notify the state in Tallahassee A.ND relay information from a form similar TIME to Attachment 1 within 15 minutes of classifying the event via one of the following:

(a) Hot Ring Down Telephone (b) Commercial Telephone (refer to ERD) (c) Cellular Phone (refer to ERD) (d) ESATCOM (e) Local Government Radio

4. Complete a form similar to Attachment 2.

TIME

5. Contact the NRCOC and relay the information from a form similar to TIME Attachment 2 immediately after the notification of the Event to State and Counties via one of the following:

(a) ENS (b) Commercial Telephone (refer to ERD) (c) Cellular Telephone (refer to ERD) W2flflMP/mr/tIIrIs

Procedure No.: Procedure

Title:

Page: 17 Offsite Notifications and Protective Action Approval Date: OEPIP- 20134 Recommendations 11/10/08 5.3.3 (Contd)

6. j[ notification responsibilities are with the Emergency Coordinator On-site, THEN provide notifications to the State and Counties every hour, unless less frequent updates are agreed to, upon termination, or as conditions change.

a. Complete a form similar to Attachment 1.

TIME

b. Obtain the initials of the Emergency Coordinator on the notification TIME form prior to transmitting the information.

c. Notifi the following of the new information:

(1) State of Florida TIME (2) Duty Call Supervisor TIME

d. Complete a form similar to Attachment 2.

TIME

e. Notif,i the NRCOC of the new information via one of the following:

TIME (1) ENS (2) Commercial telephone (refer to ERD) (3) Cellular telephone END OF TEXT W2flfltMP/mrIrIs/cls

Procedure No.: Procedure

Title:

Page: 18 Offsite Notifications and Protective Action Approval Date: 0EP1P 20134 Recommendations 11/9/09 ATTACHMENT 1 (Page 1 of 1) FLORIDA NuCLEAR PLANT EMERGENCY NOTIFICATION FORM FLORIDA NUCLEAR PLANT EMERGENCY NOTIFICATION FORM

             /OnlineVerifition:               LI STATE            LI MIAMI-DADE COUNTY                LI MONROE COUNTY A          Th is l A Drill    B. LI This Is An Actual Event 21 A. Dte.. I           I        *S. Contact Time:________           C. Reported by: Name____________________________
               -0. MessagelJumber:___________________                           E. Reported From: LI Control Room LI TSC LI EOF F LI nitiaiiPiew Classification OR            LI Update Notification

4. LI; CrjtaI Rivor UNITS B. LI St. Lucto UNIT 1 C. fl St. Lucio UNIT 2 D. G Turkey Pont UNl3 E. LI Turkey Point UNIT 4

         *4    EMERGENCY CLASSIFICAtIONf               Al  LI   Notification Of Unusual Event         B. LI  Alert
                                             !                  Site Area Emergency C.\LI                                          D. LI  General Emergency
         *5    A. LI   EMERGENCY DELARATlON:             B   LI    EMERGENCY TERMINATION                  Date:        I      I      Time:________
         *6. REASON FOR EMERGENCYDECLRATI0N:..A.L EAL Nunther                                             OR B. LI  Description_____________

7. ADDITIONAL INFORMATION OR UPDATE: A. LI Nfine Rf B. LI Decription_______________________________

         *8. WEATHER DATA:               A. Wind direction from                             B. Liownwind Sectors Affected
         *9 RELEASE STATUS: A.

LI None (Go to Item 11) B. In Progress . LI Has occurred, but stopped (go to Item 11)

10. RELEASE SIGNIFICANCE CATEGORY (at the Site Bui,darv)i A. LI Under evaluation B. ReIesei.with P Normal Operating Limits (Tech Specs)

C. LI Non-Significant (Fraction of PAG Range)D. LI PAG Range (Protecttve--Acticns required) E. LI Liquid release (no actions required)

         *11. UTILITY RECOMMENDED PROTECTIVE ACTIONS FOR THE PUBLIC:

A. LI No recommended actions at this time. B. LI The utility recommendsThEfolIowig protective actions: EVACUATE ZONES:NOT APPLICABLE OR Miles Evacuate Sectors Shelter Sstors No Action Sectors SHELTER ZONES:NOT APPLICABLE -2 0 2-5 5-10 AND consider issuance of potassium iodide (1<1) if form is completed in the Control Room, go to item 15. If completed in the TSC or EOIa, continue with item 12.

12. PLANT CONDITIONS:

A. Reactor Shutdown? LI YES LI NO B. Core Adequately Cooled? LI YES LI NO C. Containment Intact? LI YES LI NO D. Core Condition: [1 Stabl LI Degmding

13. WEATHER DATA: A. Wind Speed mph B. Stability Class______

14. ADDITIONAL RELEASE INFORMATION: A. LI Not applicable (Go to Item 15)

Distance Projected Thyroid Dose (CDE) for 1 Hour Projected TotalDose(TEDE) for 1 Hour I Mile (Site Boundary) B. mrem C. mrem 2 Miles D. E. mrem 5 Miles F. mrem G. mrem 10 Miles H. mrem I. mrem

15. (Do not read to State) EC or RM Approval Signature Date I I Time MESSAGE RECEIVED BY: Name Date I I Tinte______

IF EMERGENCY CLASS ESCALATION IS KNOWN TO EE NECESSARY AND A NEW NOTIFICATION FORM WILL BE TRPftSMITTED WITHIN 15 MINUTES, THEN YOU MAY GO TO EC/RM APPROVAL SIGNATURE LINE. ITEMS ARE EVALUATED FOR NRC PERFORMANCE INDICATORS (Pis) I F-43911:2 Rev9 (11/09/09) Ap)flnqtirnr/,I*I,I,*

Procedure No.: Procedure

Title:

I Page: I 19 Offsite Notifications and Protective Action I Approval Date: 0-EPIP- 20134 Recommendations 11/9/09 ATTACHMENT 1A (Page 1 of 1) FLORIDA NUCLEAR PLANT EMERGENCY NOTIFICATION FORM METEOROLOGICAL WORKSHEET NUCLEAR PLANT EMERGENCY NOTIFICATION FORM ( METEOROLOGICAL WORKSHEET NECTOR

REFERENCE:

Thochart bel&w can be used to determine sectors affected by a radiological release, through comparison with

       ..wind directionfrom the meteorological recorders in the Control Room.

Jf the wind dtrection is directl on the edge of two sectors (e g 11 33° 26° etc. ) an additional sector thould be a4ded to the pctectiv action recommendations. For example, if the wind direction is from 78°, théithenffected sectors for \Rs\should be L, M, N and P. SECTOR TNFORMA11N:/ WIND SECTOR W1NDFRDM DEGREES WIND TOWARD SECTORS AFFECTED [A] IN 348-11 5 HJX [B] I NN 11-33 SSW tEL [C] I NE 33-56 SW KLM [D] 5678 WSW LMN [F] E P8-101 1v1NP [F] ESE iOl-1P3 I WNW NPQ [G] SE 123-B46 / NW PQR [H] SSE 46-18 \. I I. NNW QRA [.1] S 68-1t \/ I N EAR [HI SSW ABC [L] SW 213-256k I: NE BCD [M] WSw 236-258k I EE CDE [13] w 58-2P1 / E* DEF [P] WNW 281.3b3 ESE EFG [Q] NW 303-326 SE FOR [R] NNW 326-348 SSE GHJ STABILITY CLASSIFICATION

REFERENCE:

Either ERDADS or the below chart can be used to determipe atriopherid stability classification for notification to the State of Florida. Primary method is from AT viii the South Lde (60 meter) tower. Backup method is from Sigma Theta via the Ten Meter Tower. If neitheri meteomFogical tower is available, Stability Classification shall be determined using data from National Wather Service (See 0-EPIP-20 126, Off- site Dose Calculations). CLASSIFICATION OF ATMOSPHERIC STABILITY: Primary . Bachup Stability Pasquill Delta T Sigma theta Classification Cateeories (F Ranee (Dearees) Extremely unstable A AT-1.7 ST25 Ivloderately unstable B -l.7T-1.5 22i5>St17.5 Slightly unstable C -1.5 AT -1.4 17.5> ST 12.5 Neutral 0 -1.4 AT -0.5 1.5> Sr 7.5 Slightly stable B -0.5 <AT +/-1.4 7.5> STa-38 Moderately stable F +/-14<AT-36 38>ST2.1 Extremely stable G +/-36<AT 2.1>ST Meteorological information needed to fill out the Florida Nuclear Plant Emergency Notification..Eorm...is available from the Dose Calculation Worksheet (0-EPIP-20 126). The Worksheet shall be filled out by Chemistry and given to the Emergency Coordinator. F-439f2:2 Rev 9(11109109) \Ai900qMp/mrfrlchIe

Procedure No.: Procedure

Title:

Page: 20 Offsite Notifications and Protective Action Approval Date: 0-EPIP- 20134 Recommendations 7/19/11 ATTACHMENT lB (Page 1 of 7) DIRECTIONS FOR COMPLETING THE FLORIDA NUCLEAR PLANT EMERGENCY NOTIFICATION FORM ITEM ENTRY ENOTE Online verification occurs when notification of the State Watch Office is initiated. a a a a a a a On-line Verification of Agencies on telephone call Check the appropriate boxes as the state (Florida Division of Emergency Management) requests that Miami-Dade County and Monroe County get on the line, prior to initiating the notification. All three agencies must be notified through the SWP or alternate means. If either/both of the counties (Miami-Dade County or Monroe County are not on the line, do not delay the notification: ensure the state will follow-up with contact to the counties or contact the counties directly after completing notification of the state. Prior to transmitting the completed notification form to the state, ensure that the RM has signed the approval section at the bottom of form.

1. Check appropriate box for drill or actual event as the case may be. During exercises, drills, or tests, each message shall be checked THIS IS A DRILL.

2A. Enter todays date. 2B. Enter the time (using the official time, normally synchronized with ERDADS) when contact is made with the State Warning Point or the start time of the RM PAR Briefing. For initial notification of classification, this shall be within 15 minutes of the Emergency Declaration time in item 5. 2C. Enter the name of the person making the notification call. 2D. Enter the message number beginning with #1 and following sequentially in all facilities (e.g., if the Control Room transmitted two messages the TSC would start with #3). 2E. Check the box for the facility from which the notification is being made. 2F. Check whether the notification is an initial/new classification or whether it is an hourly update notification. Criteria for 15 minute notification:

emergency declaration is the initial notification
classification in # 4 has changed
significant change-e.g., change in PARs C.

ite Check the box for the appropriate plant site for the emergency declaration (both PTN boxes might need to be checked for dual unit events such as approach of a hurricane). W2OflMPImr/nI/nls

Procedure No.: Procedure

Title:

Page: 21 Offsite Notifications and Protective Action Approval Date: 0EPIP 20134 Recommendations 7/19/11 ATTACHMENT lB (Page 2 of 7) DIRECTIONS FOR COMPLETING THE FLORIDA NUCLEAR PLANT EMERGENCY NOTIFICATION FORM NOTE FIRST LETTER of all EALs is SECOND LETTER of all EALs is Recognition Category EVENT Classification

R Abnormal Rad

U Unusual Event (UE)

Levels/Radiological Effluent

A Alert
C Cold ShutdownlRefueling

S Site Area Emergency (SAE)

System Malfunction

G General Emergency (GE)
F Fission Product Barrier
H Hazards and Other Conditions Affecting Plant Safety e S System Malfunction THIRD and FINAL NUMBER is the specific EAL in that group For example:

RG1 Abnormal Rad Levels/Radiological Effluent and a General Emergency SA4 System Malfunction and an Alert HS3 Hazards and a Site Area Emergency

4. Emergency Classification Check the box corresponding to current accident classification declared.

5. Emergency Declaration or Emergency Termination Enter the date and time when the current emergency classification was declared (A) or (B) when the emergency was terminated. This will be the actual time of declaration by the Emergency Coordinator, which may be slightly different from the time the (EOF) was notified. The time may be obtained from the official log.

6. Reason for Emergency Declaration Enter the Emergency Action Level (EAL) number (A) or (B) enter wording like that found in the EAL information in O-EPIP-20101, Duties of the Emergency Coordinator. Wording should be brief yet descriptive enough for the off-site agencies to gain an understanding of the event. It should be clear from the incident description which EAL has necessitated the emergency declaration. Wording should be as non-technical as possible with no acronyms or abbreviations.

This information should remain the same throughout update messages, unless there is a classification change.

          ** asterisk and instruction provided at the bottom of form If Emergency Class escalation is necessary due to rapidly degrading conditions, then provide the State and County authorities with the initial notification information by transmitting lines 1-6, at a minimum, on the State Notification Form (SNF) and terminate the call by stating that a new notification form will be provided within 15 minutes.

Procedure No.: Procedure

Title:

Page: 22 Offsite Notifications and Protective Action Approval Date: 0-EPIP- 20134 Recommendations 7/19/11 ATTACHMENT lB (Page 3 of 7) DIRECTIONS FOR COMPLETING THE FLORIDA NUCLEAR PLANT EMERGENCY NOTIFICATION FORM

7. Additional Information or Update Check None (A) or (B) Description and enter additional information, if necessary, or reason for update here. For example:

e Protective Action Recommendations (PARs) change o An occurrence that would otherwise result in a lower emergency classification, on other unit

Weather changes affecting public safety
Radiation level changes
Loss of off-site power, etc.

o Provide current status on any previous events that may have changed i.e., release status NOTE I If the Class Summary A Model (dose projection model) is being used, a State Notification Form Sheet is available which provides information for Items 8-11, 13 and 14. The i information is in a format similar to that found on the Florida Nuclear Plant Emergency I Notification Form. (Tis is normally refered to as the pink sheet a a = a a a a = a a

8. Weather Data

                =  =               a        a a                       a    a             a        a                    a NOTE If available, Primary data should be used.

qaa a a a a a a a a a Desired Data Source of the Met Data Primary Backup Wind Speed lOm Tower 60m Tower Wind (from) Direction 1 Om Tower 60m Tower Primary Stability Class Indicator (Delta-T) 60m Tower !l//III!IIIIlIIIIlIII Alternate Stability Class Indicator_(Sigma-Theta) iiiiiiiiiiiiiiiiiiiii 1 Om Tower Ambient Air Temperature 60m Tower 1 Om Tower! Airport A. Wind direction can be obtained from ERDADS. B. If the wind direction is greater than 360° the wind direction is determined by subtracting 360° from the indicated number. Wind direction should be rounded to the nearest whole number. C. Wind direction is always given as wind from (an easterly wind, or wind direction 90°, means that the wind is blowing from East to West). D. When determining the sectors affected, the adjacent sectors on both sides of the actual downwind sector are included. Three sectors will typically be listed. E. If the wind is located on the edge of a sector (i.e., 11°, 33°, etc.) an additional (fourth) sector should be added. F. Enter the wind direction (wind from) in degrees in item A. G. Enter the downwind sectors in item B. W2flfl MP/mr/,ls/nls

Procedure No.: Procedure Title I Page: OEPIP 20134 Offsite Notifications and Protective Action Recommendations I 23 Approval Date: 6/8/10 ATTACHMENT lB (Page 4 of 7) DIRECTIONS FOR COMPLETING THE FLORIDA NUCLEAR PLANT EMERGENCY NOTIFICATION FORM Wind Sectors Wind Sectors Wind Sectors From Affected From Affected From Affected 348-11 HJK 123-146 PQR 236-258 CDE 11-33 JKL 146-168 QRA 258-281 DEF 33-56 KLM 168-191 RAB 281-303 EFG 56-78 LMN 191-213 ABC 303-326 FGH 78-101 MNP 213-236 BCD 326-348 GHJ 10 1-123 NPQ There is no 0 sector There is no I sector

9. Release Status A. as a result of accident conditions ANY of the following is true:

A rise of (approximately) 10 times or one decade above pre-transient values is seen on one of the following accident assessment monitors:
Plant Vent (RAD 6304 or R-14)
Spent Fuel Pool Vent (RAD 6418)
Steam Jet Air Ejector (RAD 6417 or R-i5)
Dam-i Main Steam (RAD 6426)
Radiation Protection detects unplanned elevated airborne radiation levels outside of plant buildings due to accident conditions.
A Steam Generator, with primary to secondary leakage due to a tube leak or rupture is vented to atmosphere and/or feeding the (operating) steam driven AFW pump.

THEN a RELEASE is in progress, check Box B. IF this determination is made in the Control Room, THEN the Release Significance category on the State Notification Form is Under evaluation until Dose Assessment is performed.

Procedure No.: Procedure

Title:

Page: 24 Offsite Notifications and Protective Action Approval Date: 0-EPIP- 20134 Recommendations 6/8/10 ATTACHMENT lB (Page 5 of 7) DIRECTIONS FOR COMPLETING THE FLORIDA NUCLEAR PLANT EMERGENCY NOTIFICATION FORM

9. (Contd)

CAUTION The proper characterization of release status is critical for offsite decision makers. B. If a release has occurred as defined in 9A, but stopped, check Box C and go to Item 11. Dose Assessment personnel in the TSC or EOF will have this information. The TSC Chemistry Supervisor, TSC RP Supervisor, or EOF RP Manager should be contacted for the data. C. If there is no indication of a release of radioactive material, check Box A and go to Item 11.

10. Release Significance Category Do Not Check Any Box in Item 10 if you Checked Box 9 A No Release or if you checked Box 9C has occurred but stopped.

A. If a release is in progress, and dose information is not available at the time of notification, check Box A and follow up as soon as information becomes available. B. Check Box B if both noble gas and iodine release rates are within normal operating limits. C. Check Box C if either noble gas or iodine release rates exceed the normal operating limits but forecasted 1 mile doses are less than 500 mrem TEDE and 1000 mrem Thyroid CDE. These doses are less than the States Protective Action Guide (PAG) levels. D. Check Box D if forecasted 1-mile doses are greater than or equal to either 500 mrem TEDE or 1000 mrem Thyroid CDE. These PAG levels require State and County action. E. Check Box E if liquid release exceeds ODCM limits.

11. Utility Recommended Protective Actions A. If there are no Protective Action Recommendations (PARs), check Box A.

B. If PARs are necessary, check Box B. Two formats are provided to record PARs. Use the sector format and determine appropriate PARs using the guidance in Attachment 3 to this procedure. Copy the PARs into Item 11 B. Indicate PARs by using only the words NONE, ALL, or ALL REMAINING, or by listing the letters of the sectors affected. Protective Action Recommendations shall be approved by the Emergency Coordinator (EC) or the Recovery Manager (RM). The zone format is for Crystal River Unit 3 use only. W2003:ME/mr/cls/cls

Procedure No.: Procedure

Title:

Page: 2. Offsite Notifications and Protective Action Approval Date: 0-EPIP- 20134 Recommendations 11/9/09 ATTACHMENT lB (Page 6 of 7) DIRECTIONS FOR COMPLETING THE FLORIDA NUCLEAR PLANT EMERGENCY NOTIFICATION FORM

12. Plant Conditions Answer the three questions Yes or No by checking the appropriate box. The RM Ops advisor may be consulted for assistance.

NOTE I Critical Safety function status is available from the Control Room. a = a = = = a = I A. Is the reactor shut down? If the subcriticality safety function is being met, THEN check the yes box. B. Is the core adequately cooled? e If the core cooling critical safety functions are being met, THEN check the yes box. C. Is the containment intact? If the containment critical safety function is being met, THEN check the yes box. D. Is the condition of the core stable or degrading?

IfB above is yes, THEN check the stable box, OR
IfB above is NO, THEN check the degrading box.

13. Weather Data A. Temperature, wind speed, wind direction and stability class can be obtained from ERDADS.

B. Enter wind speed in Miles Per Hour (MPH) in item A. C. Stability Class Enter the stability class as determined by ERDADS or by using the figure below. The figure shows the relationship between the Delta T and Sigma-Theta displayed by ERDADS and the stability class. If using Delta-T, AT If using Sigma-Theta, aO Stability Class AT-1.7 aO22.5 A

                    -1.7<AT-1.5                                22.5>aO17.5                             B
                    -1.5 < AT -1.4                             17.5 > aO 12.5                          C
                    -1.4<AT-O.5                                 12.5>a87.5                             D
                    -O.5<AT+1.4                                 7.5>aS3.8                              E
                    +1.4<AT<÷3.6                                3.8>c82.1                              F
                       +3.6<T                                      2.1>cyO                            G

Procedure No.: Procedure

Title:

Page: 26 Offsite Notifications and Protective Action Approval Date: 0EPIP 20134 Recommendations 11/9/09 ATTACHMENT lB (Page 7 of 7) DIRECTIONS FOR COMPLETING THE FLORIDA NUCLEAR PLANT EMERGENCY NOTIFICATION FORM

14. Additional Release Information This section requires that a release be in progress and completed results of dose assessment be available. Check A Not Applicable box if no release is occurring and/or if dose information is not available. Otherwise, provide all information that applies.

Projected Dose Information Enter the projected Thyroid Dose (CDE) in mrem for 1 hour (EPIP-20126, Off-Site Dose Calculation, Line 5) and the projected Total Dose (TEDE) in mrem for 1 hour (EPIP-20 126, Off-Site Dose Calculation, Line 16) for the site boundary 2, 5, and 10 miles B through I. I I NOTE The upper line of Step 15 is:

For the approval signature, date and time.

I a Completed prior to contacting the State Watch Office. I I I

Notreadoverthe phone.

15. A. Obtain approval of the notification form and document on the upper line.

B. Message Received By Upon completion of reading the form, enter:

The name of the State Watch Office Duty Officer or the individual that receives the notification
Date of the phone call
Time at the State Watch Office (request it from the Duty Officer)

W2003:ME/mr/els/cls

Procedure No.: Procedure

Title:

Page:

                                                        *     ..               .          .            .                                   27 Offsite Notifications and Protective Action                                      Approval Date:

0-EP1P- 20134 Recommendations 5/27/10 ATTACHMENT 1C (Page 1 of 3) EAL DESCRIPTIONS FOR FLORIDA NUCLEAR PLANT EMERGENCY NOTIFICATION FORM General Emergency Site Area Emergency Alert Unusual Event RGI RSI RA1 RUt Off-site Dose Resulting from an Off-site Dose Resulting from Any Release of Gaseous or Any Release of Gaseous or Actual or IMMINENT Release of an Actual or IMMINENT Liquid Radioactivity to the Liquid Radioactivity to the Gaseous Radioactivity Greater Release of Gaseous Environment Greater Than Environment Greater Than 2 Than 1000 mrem TEDE or 5000 Radioactivity Greater Than 100 200 Times the ODCM for Times the ODCM for C mrem Thyroid CDE for the Actual mrem TEDE or 500 mrem 15 Minutes or Longer. 60 Minutcs or Longer. or Projected Duration of the Thyroid CDE for the Actual or Release Using Actual Projected Duration of the Meteoroloay. Release. RA2 RU2 Damage to Irradiated Fuel UNPLANNED Rise in Plant or Loss of Water Level Radiation Levels. that Has Resulted or Will Result in the Uncovering

        ,                                                                                of Irradiated Fuel Outside the Reactor Vessel.
                  -                                                                                  RA3 Rise in Radiation Levels Within the Facility That
       .e                                                                                    Impedes Operation of Systems Required to Ivlaintain Safe Plant Safety Functions.

CG1 CS1 CAl CU1 Loss of RCS Inventory Affecting Loss of RCS Inventory Loss of RCS Inventory. RCS Leakage. y Fuel Clad Intearity with Affecting Core Decay Heat Containment Challenged. Removal Capability. CU2 UNPLANNED Loss of RCS Inventory. CA3 CU3 Loss of All Off-site and AC Power Capability All On-site AC Power to To Emergency Busses Emergency Busses For 15 Reduced to a Single Power minutes Or Longer. Source for 15 Minutes or longer such that Any

                  .                                                                                                    Additional Single Failure Would Result in Unit Blackout.

CA4 CU4 Inability to Maintain Plant UNPLANNED Loss of Decay in Cold Shutdown. Heat Removal Capability with trradiated Fuel in the Reactor Vessel CU7 Z Loss of Required DC Power t_) for 15 Minutes Or Longer. c

                -                                                                                                                  CU8 cr                                                                                                              Inadvertent Criticality.
          -     .t Q     -

CU6 Loss of All On-site or Off-site Communications Capabilities.

W2003:ME/mr/cls/cls

Procedure No.: Procedure

Title:

Page: za Offsite Notifications and Protective Action Approval Date: 0-EPIP- 20134 Recommendations 5/27/10 ATTACHMENT 1C (Page 2 of 3) EAL DESCRIPTIONS FOR FLORIDA NuCLEAR PLANT EMERGENCY NOTIFICATION FORM E-ITU1 tCjD Damaee to a loaded cask r confinement BOUNDARY. c t

        çtif FG1                                FS1                              FA1                             FU1 Loss of ANY Two Barriers AND Loss or Potential Loss of ANY ANY Loss or ANY Potential ANY Loss or ANY Potential Loss or Potential Loss of the third           two barriers.          Loss of EITHER Fuel Clad OR         Loss of Containment.

barrier. RCS. HG1 HS4 HA4 HU4 HOSTILE ACTION Resulting in HOSTILE ACTION within the HOSTILE ACTION within the Confirmed SECURITY Loss of Physical Control of the PROTECTED AREA OWNER CONTROLLED CONDITION or Threat Which Facility. AREA or Airborne Attack Indicates a Potential a Threat Degradation in the Level of riD Safety of the Plant. HS2 HA5 c Control Room Evacuation Has Control Room Evacuation has Been Initiated and Plant Control been Initiated. Cannot be Established. U CI)

      *st HAl                             HU1 j                                                                                      Natural or Destructive        Natural or Destructive Phenomena Affecting VITAL        Phenomena Affecting the AREAS.                  PROTECTED AREA.

CI) HA2 HU2 FIRE or EXPLOSION FIRE Within the PROTECTEI Affecting the Operability of AREA Not Extinguished Z Plant Safety Systems Required Within 15 Minutes of E to Establish or Maintain Safe Detection OR EXPLOSION Shutdown, within the PROTECTED AREA. HA3 HU3 Access to a VITAL AREA Is Release of Toxic, Corrosive, Z Prohibited Due To Release of Asphyxiant, or Flammable Toxic, Corrosive, Asphyxiant Oases Deemed Detrimental to

            ><.<                                                                          or Flammable Gases Which            NORMAL PLANT Jeopardize Operation of             OPERATIONS.

Systems Required to Maintain Safe Operations or Safely Shutdown the Reactor. HG2 HS3 HA6 HU5 Other Conditions Existing Which Other Conditions Existing Other Conditions Existing Other Conditions Existing Z in the Judgment of the Which in the Judgment of the Which in the Judgment of the Which in the Judgment of the Emergency Coordinator Warrant Emergency Coordinator Warrant Emergency Coordinator Emergency Coordinator

                 >      Declaration of General             Declaration of Site Area        Warrant Declaration of an       Warrant Declaration of a Emergency.                         Emergency.                          Alert.            Notification of Unusual Event (NOUE).

W20fltMFimrIrlsInhs

Procedure No.: Procedure

Title:

Page: 29 Offsite Notifications and Protective Action Approval Date: 0-EPIP- 20134 Recommendations 5/27/10 ATTACHMENT 1C (Page 3 of 3) EAL DESCRIPTIONS FOR FLORIDA NUCLEAR PLANT EMERGENCY NOTIFICATION FORM SG1 ss1 SA5 sul Prolonged Loss of All Off-site Loss of All Off-site and All AC Power Capability To Loss of All Off-site and All On-Site AC Power to On-site AC Power to Emergency Busses Reduced To AC Power to Emergency C Emergency Busses. Emergency Busses for 15 A Single Power Source For 15 Busses for 15 Minutes or U minutes or longer. Minutes or Longer Such That Longer. Any Additional Single Failure Would Result In Unit Blackout. SG2 SS2 SA2 SU8 Automatic Trip and All Manual Automatic Trip Fails to Automatic Trip Fails to Inadvertent Criticality. Actions Fail to Shutdown the Shutdown the Reactor AND Shutdown the Reactor AND the Reactor AND Indication of an Manual Actions Taken in the Manual Actions Taken in the Extreme Challenge to the Ability Control Room are NOT Control Room are Successful in to Cool the Core Exists. Successful in Shutting Down Shutting Down the Reactor. U the Reactor. SS3 Loss of All Vital DC Power for 15 Minutes or Longer. cj SS6 SA4 SU3 C Inability to Monitor a UNPLANNED Loss of Safety UNPLANNED Loss of Significant Transient in System Annunciation or Safety System Annunciation Progress. Indication in the Control Room or Indication in the Control With Either (1) a Significant Room for 15 Minutes or Transient in Progress, or Longer. Z (2) Compensatory Indicators Unavailable. SU5 RCS Leakage. rJ, SU4 Fuel Clad Degradation. U SU2 Inability to Reach Required Shutdown Within Technical Specification Limits. SU6 Loss of All On-site or Off-site Communications C Capabilities. U TABLE OF ACRYROMS TEDE TOTAL EFFECTIVE DOSE EQUIVALENT CDE COMMITTED DOSE EQUIVALENT RCS REACTOR COOLANT SYSTEM AC ALTERNATING CURRENT DC DIRECT CURRENT ODCM OFFSITE DOSE CALCULATION MANUAL w2nnM/mr/.-IcIntr

Procedure No.: Procedure

Title:

Page: 311 Offsite Notifications and Protective Action Approval Date: 0-EPIP- 20134 Recommendations 5/27/10 ATTACHMENT 2 (Page 1 of 2) S ENT NOTIFICATION WORKSHEET

NRC FORM 361 NRC FORM 361 US NUCLEAR REGULATORY COMMISSION (12-2000 REACTOR PLANT OPERATIONS CENTER EVENT NOTIFICATION WORKSH EET EN#

NRC OPRATIOiITELEPi-1ONE NUMBER: PRINARY 301-816-5100 OR 8005323469*, BACKUPS -(1st) 301-951-0550 or 800449.3694*, l2ndl 301 -415.0550ANó I3rdl 0 301-415-5 53r Licensees who maintain their own ETS are Drovided these teleDhone numbers. NOTIFICATION TIME FACILItY OROTtGAIIIZATION UNIT NAME OF CALLER CALL BACK EVENT TIME & ZONE EVENT DATE POWER/MODE BEFORE POWER/MODE AFTER EVENT CLASSIFICATIONS 1-Hr. Non-Emergcncyilo CFR 50.72(b)(1) (v)(A) Safe S/ID Caoaldldy PJNA ENERAL EMERGENCY GEN/AAEC TS Desiaon 1 4 P0EV (v)(B( RHR Capabitly PiNE SITE AIR BA EMERGENCY SIT/APEC 4-Hr. Non-Emergency 10 CFR 50.72(b)(2) (vff C) Control of Rail Raleasa AINC LENT ALE)AAEC (t TS Rquiral1 SIC ASHU (v)(D) Accident Mitigation AJND UNUSUAL EVENT UNUIAAEC (I(A) ECCS Diochange Ia I1CS ACCS (xh) Off-site Medical AMED 50.72 NON-EMERGENCY (see text colunms( (1aXB) fOPS Actjjatioh (scrath) ARPS (a/i) Lass Comart/Asmt/Resp ACOM PHYSICAL SECURITY (73.71) DODD (id) dffxtite.Notlfi4aIiux...i APRE 60-Day Optional 10 CFR 50.73(a)(1) MATERIAL/EXPOSURE B?? 8-Hr. Non-Emergency 10 CFR 50.7(b)(3) I.1d Specilied System Actuation AJNV FITNESS FOR DUTY HFIT (li)(A) Degraded Condition ADEG Other Unspecified Requirement (identity) OTHER UNSPECIFIED REOMT. (see last cdorrar) (II)(B( Unanalyzed Con/Son AUI(IA NONR INFORMATION ONLY NNF (moP) Specilied System ActuatiOn AESF . NONR DESCRIPTION . i Include: Systems affected, actuations and their initialing signals, causes, effect of eveht on plant, actions or planned, etc. (Continue on back) NOTIFICATIONS YES NO WILL BE ANYTHING UNUSUAL OR NOT YES (Explain abooe) NO NRC RESIDENT Q Q UNDERSTOOD? STATE(s) D D D DID.SLLSYSTEMSFUNCTIONAS LOCAL Q Q REQUIRED? LI YES NO (Explainabose) OTHER GOV AGENCIES Q Q MODE OF OPERATION UNTIL I ESTIMATED ADDITIONAL INFO ON BACK MEDINPRESS RELEASE Q CORRECTED:: RESTART DATE:: YES NO NRC FORM 361 (12-200) F-443/1:2 Rev. 0(1/10/03) W2flfl-MFImrIcls/cls

Procedure No.: Procedure

Title:

Page: 31 Offsite Notifications and Protective Action Approval Date: 0-EPIP- 20134 Recommendations 5/27/10 ATTACHMENT 2 (Page 2 of 2) EVENT NOTIFICATION WORKSHEET NRC FORM 361 ADDITIONAL INFORMATION PAGE 2 OF 2 RAb1OLQGICAL RtLEASES: CHECK OR FiLL IN APPLICABLE ITEMS (specific detaUathapiarrntlans 5500000s covereif (It event csscniptlon) Lt0UIdiRELEA$E GASEOUS RELEASE UNPI.ANNED RELEASE PLANNED RELEASE ONGOING TERMINATED

MONl1ORED I UNMONITORED OFF-SITE RELEASE T.S. EXCEEDED RM ALARMS AREAS EVACUATED PERSONNELEXPOSED OR CONTAMINATES OFF-SITE PROTECTIVE ACONS RECOMMENDED Slate release path ii (ascription IReleasa Rate (0/sac) T.S. LIMIT HOO GUIDE Total AWait5 (Ci) % T.S. LIMIT HOO GUIDE NobleGas 1 0.1 Cilsec 10000 Iodine S lOoCVsec 0,01 CI Particulate I ad/sec 1 Liquid (enciuding 1,/titan and 0//Soloed

                                                         ,                                      10 uCUtthn                                                                0.lCi noble pears)                    ,1 Uquid (IrillUm)                                                                         IL2ClIiran                                                                5 Ci Total ActhoIy PLANT STACK           COWbENSRh/IR EJECTOR                 MAIN STEAM LINE                SO SLOWDOWN                             OTHER RAD MONITOR READINGS:

ALARM SETPOtNTS:

       % T.S. LIMIT (ttaWrI/aable)

RCS OR SG TUBE LEAKS: CHECK OR FILL INAPPUCABLEITEMS pecific details/explanations should be covered in event description) LOCATION OF THE LEAK (e.g., SG #, valve, pipe, etc) LEAK RATE: UNITS: gptn/gpd T.S. LIMITS: SUDDEN OR LONG TERM DEVELOPMENT: LEAK START DATE: TIME: COOLANT ACTIVITY PRIMARY [1 SECONDARY AND UNITS: LIST OF SAFETY RELATED EQUIPMENT NOT OPERATIONAL: EVENT DESCRIPTION (Continued from front) F-443/2:2 Rev. 0 (1/10/03) sAtOrrno-eAITl/,-I,,I,.I.

Procedure No.: Procedure

Title:

Page: Offsite Notifications and Protective Action Approval Date: 0-EPIP- 20134 Recommendations 5/27/10 ATTACHMENT 2A (Page 1 of 2) DIRECTIONS FOR COMPLETING THE NRC REACTOR PLANT EVENT NOTIFICATION WORKSHEET A. Contact information to be completed following contact.

1. Name of the person contacting the NRC or other designated FPL contact.

2. NRC Contacts Name will be provided upon contact. Also obtain the event number and notification time as received from the HOO (Headquarters Operation Officer) should be recorded on the top of the worksheet.

B. Reactor Plant Event Notification Worksheet, Page 1

I The EN # is provided by the NRC.

1. Notification Time enter the time contact is made.

2. Facility Organization enter Turkey Point Nuclear station.

3. Unit enter the appropriate unit number: Enter 00 for a classification common to both units.

4. Callers Name enter the name of the person making the call.

5. Call back # enter the number of the ENS phone that you are calling from and the commercial phone number as which you can be reached.

6. Event time and Zone enter the military time, the zone will be EST for Eastern Standard Time or EDT for Eastern Daylight-savings Time.

7. Event Date enter the date the event is occurring.

8. Power/Mode Before & Power/Mode After enter the power in percent and the mode number (1-6) before and after the event.

NOTE Abbreviations/acronyms (e.g., UNU/AAEC, SIT/AAEC, etc.) are for NRC use only. I

9. Event Classifications check one of the four blocks for General Emergency, Site Area Emergency, Alert, or Notification of Unusual Event.

W2003:ME/mr/cls/cls

Procedure No.: Procedure

Title:

Page: 33 Offsite Notifications and Protective Action Approval Date: 0-EPIP- 20134 Recommendations 5/27/10 ATTACHMENT 2A (Page 2 of 2) DIRECTIONS FOR COMPLETING THE NRC REACTOR PLANT EVENT NOTIFICATION WORKSHEET B. (Contd) a a a an Iii CT ; No other blocks in the upper half of the form are required. I a a a a a al

10. Description provide a written description of the event.

NOTE I Check the blocks in the lower portion of the form based on current conditions. I a a a a a a a a

11. Mode of operation until corrected provide if known.

12. Estimate for restart date enter unknown.

13. Additional info on Page 2 enter yes or no.

C. Reactor Plant Event Notification Worksheet, Page 2

1. Fill in as much of the information on the form as is immediately available do -

not create undue delay in making the notification. This information can be gained once the open line of communication is established. D. Approval

1. Information entered on the worksheet shall be reviewed and approved by the EC or RM (if used in the EOF), prior to transmission.

2. The EC/RM may initial on the worksheet to indicate approval. There is no formal sign-off location on the worksheet.

W2003:MEImr/cls/cls

Procedure No.: Procedure

Title:

I Page:

                                                                                                    .1 Offsite Notifications and Protective Action              I  Approval Date:

0-EPIP- 20134 Recommendations ATTACHMENT 3 (Page 1 of 5) GUIDANCE FOR DETERMINING PROTECTIVE ACTION RECOMMENDATIONS (PARs) BASED ON PLANT CONDITIONS Continue to Assess Conditions and Evaluate 0-2 ALL further Protective Action 2-5 (sectors affected) ALL REMAINING NONE I Recommendations based on 5-10 NONE ALL NONE Off-Site Dose Prcecticns (Note 3) NOTES: (1) Severe core damage is indicated by any of the following

               - Loss of critical functions required for core protection (g:liss of injection with LOCA)
               - High Core temperatures (Valid CET > 700°F)
               - CHRRIvI Reading of greater than or equal to l.3E4 R!hr (2)       Loss of physical control of Control Room or reactor operating areas, required for continued safe plant operation to intruders.

(3) See additional Guidance for Determining PARs in Emergency Plan Implementing Procedures. F444/1:5 -. Rev. 4 (0-EPIP-20134) kAJflfl5AIl,-k,Ii,

ATTACHMENT 3 (Page 2 of 5) GUIDANCE FOR DETER1vIINING PROTECTIVE ACTION RECOMMENDATIONS (PARs) BASED ON MANUAL DOSE CALCULATIONS RELEASE DURATION LESS TITAN 2 HOURS (PUFF RELEASE) Beyond 10 miles use this column and the 10 mile dose value. Total Dose Thyroid Dose 0-2 Miles 2-5 Miles 5-10 Miles ThDE. OR DE Dose mRem) (mRem) Use 1 Mi. value Use 2 Mi. Value Use 5 Mi. Value

                  <500 mRem          <1000 mRem           None             None            None 500inRem           1000 mRem         S(ALL) but                but                             S(DW)           S(DW)
                  <1000 mRem         <5000 niRem 1000 mRern        -5000 mRem          S(ALL) but                but                            S(ALL)          S(ALL)
                  <5000 mRem        < 25000 mRem 5000 mReni         25000 mRem         E(ALL        E(DW)+S(AR     E(DW)+S(AR)

RELEASE DURATION GREATER THAN OR EQUAL TO 2 HOURS

Beyond 10 miles use this column and the 10 mile dose value.

Total Dose Thyroid Dose 0-2 Miles 2-5 Miles 1540 Miles TEDE OR CDE Dose (mRem) (mRem) Use 1 Mi. value Use 2 Mi. Value Use 5 Nfl. Value

                  < 500 mRem         <1000 mRem           None             None            None 500 mRem           1000 mRern but                but            S(ALL)           S(DW)           S(D\V)
                  <1000 mRem         <5000 mRem 1000 mRcm            5000 mRein but                but            E(ALL)       EçDW)+S(AR)    E(DW)+S(AR)
                  <5000 mRem        <25000 mRem 5000 mRem         25000 mRem         E(ALL)          E(ALL)       E(DW)+S(AR)

SUMNIARY 0-2ML 25M1. 5lOMI. PARs based on Plant Conditions PARs based on Total Dose (TEDE) PARs based onThyroidDose (CDE) Most Conservative PARs based on Plant Conditions and Dose Projections LEGEND OF ABBREVIATIONS S Sheltering recommended E Evacuation recommended DW Downwind plus 2 adjoining sectors AR All Remaining sectors ALL All Sectors r444)2:5 Rev. 4 (O-EPIP-20134)

Procedure No.: Procedure

Title:

I Page: I. 36 0-EPIP- 20134 Offsite Notifications and Protective Action I Approval Date: 7/19/11 Recommendations ATTACHMENT 3 (Page 3 of 5) GUIDANCE FOR DETERMINING PROTECTIVE ACTION RECOMMENDATIONS (PARs) FPL is required to provide county and state governmental authorities with recommendations for protective action to be taken by the public during radiological emergencies at the Turkey Point Nuclear Plant. The responsible authorities are the State Division of Emergency Management (DEM), Miami-Dade County Office of Emergency Management and Monroe County Office of Emergency Management. Protective Action Recommendations (PARs) should be made utilizing all of the available data. This includes plant status, off-site dose projections, and/or field monitoring data. The more conservative recommendations should be made. Beginning at the top left side, answer the General Emergency question. If yes, continue on, following the arrows, and answering theother questim blockRecord the PARs based on Plant Condition (A) in the Summary Block at the bottom of the page. From the PAR based on Plant Conditions block continue following arrow to next box, and determine PARs based on Off-site Dose Projections (B) Total Dose (TEDE) and Thyroid Dose (CDE). In determining PARs, both plant conditions AND off-site doses must be considered for all PARs. If a release has not occurred, then proceed with issuance of PARs from the plant condition determination. To determine PARS from off-site doses, find the blocks that correspond with the Total Dose (TEDE) and Thyroid Dose (CDE) at 1, 2 and 5 miles from the Dose Calculation Worksheet (O-EPIP-20126). Follow across to the column that indicates the distance where that dose was found i.e., first block for 1 mile, second block for 2 miles, or third block for 5 miles. (B) Record--the PARs based on Off-site Doses in the Summary Block. Once PARs are determined for all mile sectors for both Total Dose (TEDE) and Thyroid Dose (CDE) (B), then a comparison with the Plant Condition PARs (A) is performed, and the most conservative PARs for each mile sector is selected for issuance to off-site agencies. The following example is provided: EXAMPLE A release has occurred at the Turkey Point PlanL The wind direction is from the SSE and

                       -   the projected off-site accumulated Thyroid Dose (CDE) is 5,000 mRem at I mile, 1,000 mRem at 2 miles, and less than 1,000 mRem at 5 miles. The plant is in a General Emergency with CHRRM at 100 Rnit no core damage indicators, and no loss of physical control of the plant.

F444/3:5 Rev. 4 (O-EPIP-201 34)

Procedure No.: Procedure

Title:

Page: 37 Offsite Notifications and Protective Action Approval Date: 0-EPIP- 20134 Recommendations 7/19/11 ATTACHMENT 3 (Page 4 of 5) GUIDANCE FOR DETERMINING PROTECTIVE ACTION RECOMMENDATIONS (PARs) Using the PAR Worksheet, the following recommendations should be made: Banid on our current assessment of all the information now available to use, Florida Power & Light Company recommends that you consider taking the following protective actions. A. EVACUATE all people between 0 and 2 miles from the plant. B. SHELTER all people between a 2 and 5 mile radius form the plant who are in Sectors Q, R, and A (refer to Attachment 1). C. No protective actions is recommended between a 5 and 10 mile radius from the plant. Due to the large political and legal ramifications of these recommendations and the potential impact on FPL, the following guidelines, format, and content should be used. (1) If the emergency has noLbeen_classified as a GENERAL EMERGENCY and the off-site doses are LESS THAN 500 mRem Total Dose (TEDE) or 1,000 mRem Thyroid Dose (CDE) at 1 mile over the projected duration of the release, no protective action is recommended. When reporting to DEM and other off-site agencies who inquire, this should be reported in a manner similar to the following: Based on our urgent assessment of all the information now available to us, Florida Power & Light Company recommends that you consider taking the following protective actions - NONE. This recommendation may change in the future, but we cannot now say when it may change or what the change may be. (2) When available, both plume calculation and off-site monitoring results should be evaluated when making protective action recommendions. If siguificant discrepancies exist between field monitoring results and plume dispersion calculations, then the discrepancy should be reviewed, and the appropriate value should be selected in the determThation of protective action recommendations. (3) Thyroid Dose (CDE) Limits for PARs are based on adult thyroid. These limits are consistent with EPA Guidelines based on the following criteria:

a. Uncertainty and potential errors associated with age specific parameters, and

b. Level of conservatism in the adult values.

(4) Loss of physical control of the plant to intruders shall be determined by the Emergency Coordinator based on the current operating mode requirements of the unit / plant, and the availability of equipment required for continued safe operation. F444/4:5 Rev, 4 (O-EPIP.20134)

Procedure No.: Procedure

Title:

Page: 38 Offsite Notifications and Protective Action Approval Date: 0-EPIP- 20134 Recommendations 7/19/11 ATTACHMENT 3 (Page 5 of 5) GIJIDANCE FOR DETERMINING PROTECTIVE ACTION RECOMMEN]ATIONS (PARs) GUIDANCE FOR THE USE OF POTASSIUM IODIDE (KI - A THYROID BLOCKING AGENT

1. The EOF RP Manager in consultation with the TSC RP Supervisor will determine the need to dipense Potassium Iodide (KI) based upon a projected or actual thyroid Committed Dose Equivalent (CDE) of greater than or equal to 5 rem. (The thyroid CDE of greater than or equal to 5 rem is based on the FDA recommended threshold for ingestion of KI by pregnant and lactating women).

2. The TSC RP Supervisor and the OSC RP Supervisor will coordinate KI distribution once a decision for use has been determined.

3. The TSC RP Supervisor is responsible for XI distribution to personnel in the Unit 3 and 4 Control Room and the TSC and Field Monitoring Teams and to Security personnel not assigned to the OSC.

4. The OSC RP Supervisor is responsible for distribution in the OSC.

5. KI should be administered and ingested within 2 hours after the determination is made that thyroid CDE is greaterthan oqpal toirem.

6. When XI is issued, thyroid intakes will be estimated by whole body counts.

7. Administering KI after an uptake may limit thyroid CDE depending on time after exposure.

8. Caution emergency response personnel of potential KI side effects if they are allergic to shelifish or iodide. Emergency response personnel who know they have such allergies should be replaced in lieu of directing them to ingest KI.

9. All KI tablets are stored in the RP kits in the Unit 3 and4 Control Room, TSC, OSC. and Field Monitoring Team Kits.

F44415:5 Rev. 4 (O-EPIP-20134) FINAL PAGE

Appendix C Job Performance Measure Form ES-C-I Worksheet Facility: Turkey Point Determine Contingency Task No: 1 02023013300 Task

Title:

Actions JPM No: 02023013301 K/A

Reference:

2.1.2 SRO 4.4 Examinee: NRC Examiner: Facility Evaluator: Date: Method of testing: Simulated Actual Performance X Performance Classroom X Simulator Plant Read to the examinee: I 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:

Unit 3 was shutdown 12 days ago.
RCS is depressurized with Temperature is at 105 °F.
The RCS level on LIS-3-6421 and LIS-3-6423 indicate 50%.
Unit 3 is in normal electrical alignment. Maintenance is scheduled for the 3H LC.

3A Charging Pump is OOS for Maintenance.

Both Unit 3 HHSI pumps are available and Unit 3 RWST level is 40,000 gallons.

Initiating Cue: The 3B Charging Pump has just tripped. You have been directed by the Shift Manager to identify any contingency actions that are required by 0-ADM-051, Outage Risk Assessment and Control. HAND JPM BRIEFING SHEET TO EXAMINEE AT THIS TIME! NUREG 1021 Rev 9 Appendix C

Appendix C Page 2 of 8 Form ES-C-I TaskStandard: Examinee correctly identifies that

Initiate action to repair the unavailable charging pumps.
Verify the availability of two HHSI pumps with at least 20,000 gallons in the RWST.
Take action to maximize RCS inventory.
Maintain RCS temperature as low as possible.
Suspend the repair activities on the 3H LC.

Time Critical Task: NO Validation Time: 20 minutes Required Materials:

0-ADM-051, Outage Risk Assessment and Control (hardcopy)
Unit 3 Plant Curve Book Section 5 Figure 9 and Figure 12 A (hardcopy)

General

References:

0-ADM-051, Outage Risk Assessment and Control
Unit 3 Plant Curve Book NUREG 1021 Rev 9 Appendix C

Appendix C Page 3 of 8 Form ES-C-I SIMULATOR SETUP ResettolC# N/A Load Lesson N/A Ensure Simulator Operator Checklist is complete N/A NUREG 1021 Rev9AppendixC

Appendix C Page 4 of 8 Form ES-C-I Denote critical steps with an explanation point (I) StartTime STEP 1 SAT Obtain O-ADM-051, Outage Risk Assessment and Control. (From the initiating cue.) UNSAT Standard: O-ADM-051, Outage Risk Assessment and Control is obtained. Cue Give applicant a copy of procedure or require the candidate to obtain the procedure. Comment NOTE: NUREG 1021 Rev 9 Appendix C

rAppendix C Page 5 of 8 Form ES-C-I STEP 2 Identify the correct enclosure of ADM-051 to implement based SAT on plant conditions. UNSAT Examinee identifies Enclosure 5 as the correct enclosure to implement based on the following:

Phase II is applicable due to the time following unit shutdown Standard: given in the initiating cue.

RCS temperature <200°F given RCS Loops not available. Cue Comment 412 Phase II 412J The later staaes of an outage in which the decay heat load is reduced and NOTE: relaxations of Functional ecuipment requirements are allowed. It is defined as Ereater than 240 hours following unit shutdown, or start of fisel reload to the eactor vessel as part of a frill core offload whichever occurs first. 4.13 Reduced Inventory 4iIl A condition with fuel in the reactor vessel and the Reactor Coolant System drained down lower than three feet below the vessel flange. NUREG 1021 Rev 9 Appendix C

Appendix C Page 6 of 8 Form ES-C-I STEP 3 : SAT q Review Enclosure 5 requirements. UNSAT Examinee reviews Enclosure 5 determines the contingency action required when the 3B Charging Pump trips. 0 Initiate action to repair the unavailable charging pumps. o Verify the availability of two HHSI pumps with at least 20,000 gallons in the RWST. Standard: o Take action to maximize RCS inventory.

             . Maintain RCS temperature as low as possible.

o Suspend the repair activities on the 3H LC. Cue Terminating The task is complete when the Examinee returns the cue Cue: sheet to the examiner. STOP Stop Time NUREG 1021 Rev 9 Appendix C

Appendix C Page 7 of 8 Form ES-C-I VnfictiQn Qf CQmpIQtiQfl Job Performance Measure No. 02023013301- Determine Contingency Actions Examinees Name: Examiners Name: Date Performed: Facility Evaluator: Number of Attempts: Time to Complete: Question Documentation: Question:

Response

Result Satisfactory/Unsatisfactory Examiners signature and date: NUREG 1021 Rev9AppendixC

JPM BRIEFING SHEET The examiner will explain the initial conditions, which steps tu simuiate ordiscuss, and provide initiating cues. When you complete the task successfully, the objective for this job performance measure will be satisfied. Initial Conditions:

Unit 3 was shutdown 12 days ago.

o RCS is depressurized with Temperature is at 105 °F.

The RCS level on LIS-3-6421 and LIS-3-6423 indicate 50%.
Unit 3 is in normal electrical alignment. Maintenance is scheduled for the 3H LC.
3A Charging Pump is OOS for Maintenance.

o Both Unit 3 HHSI pumps are available and Unit 3 RWST level is 40,000 gallons. Initiating Cue: The 3B Charging Pump has just tripped. You have been directed by the Shift Manager to identify contingency actions that are required by 0-ADM-051, Outage Risk Assessment and Control. Acknowledge to the examiner when you are ready to begin. HAND THIS PAPER BACK AND YOUR CIRCLED ACTIONS, IF ANY, FROM O-ADM-051 TO YOUR EVALUATOR WHEN YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK. NUREG 1021 Rev9AppendixC

JPM BRIEFING SHEET The examiner will explain the inftial conditions, which steps to simulate or discuss, nd provide initiating cues. When you complete the task successfully, the objective for this job performance measure will be satisfied. Initial Conditions:

Unit 3 was shutdown 12 days ago.
RCS is depressurized with Temperature is at 105 F.
The RCS level on LIS-3-6421 and LIS-3-6423 indicate 50%.

o Unit 3 is in normal electrical alignment. Maintenance is scheduled for the Hotel Bus.

3A Charging Pump is OOS for Maintenance.
Both Unit 3 HHSI pumps are available and Unit 3 RWST level is 40,000 gallons.

Initiating Cue: The 3B Charging Pump has just tripped. You have been directed by the Shift manager to identify contingency actions that are required by 0-ADM-051, Outage Risk Assessment and Control. Acknowledge to the examiner when you are ready to begin. HAND THIS PAPER BACK AND YOUR CIRCLED ACTIONS, IF ANY, FROM O-ADM-051 TO YOUR EVALUATOR WHEN YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK. NUREG 1021 Rev 9 Appendix C

Florida Power & Light Company Turkey Point Nuclear Plant I cj H p L

Title:

Outage Risk Assessment and Control (Information Use) Responsible Department: Operations Revision Number: 4 Issue Date: 7/25/1 1 Revision Approval Date: 7/22/1 1 AR 565731, 589071, 591906,1668955 PCRs 09-0220, 09-023 1, 08-3909, 09-0660, 09-0664, 09-2314, 09-3 139, 09-3321, 09-3334, 09-3412, 10-0718, 10-1220 PC/Ms 94-059, 95-060 W97:DJT/cls/mr/emc

Procedure No.; Procedure

Title:

Page: 2 Approval Date; O-ADM-051 Outage Risk Assessment and Control 7/22/11 LIST OF EFFECTIVE PAGES (Rev. 4) Revision Revision Revision Paae Date Pace Date Paae Date 1 07/22/11 36 07/22/11 71 07/22/11 2 07/22/11 37 07/22/11 72 07/22/11 3 07/22/11 38 07/22/11 73 07/22/11 4 07/22/11 07/22/11 07/22/11 5 07/22/11 40 07/22/11 07/22/11 6 07/22/11 41 07/22/11 76 07/22/11 7 07/22/11 42 07/22/11 07/22/11 8 07/22/11 43 07/22/11 78 07/22/11 9 07/22/11 44 07/22/11 79 07/22/11 10 07/22/11 45 07/22/11 80 07/22/11 ii 07/22/11 46 07/22/11 81 07/22/11 12 07/22/11 4 07/22/11 82 07/22/11 13 07/22/11 48 07/22/11 83 07/22/11 14 07/22/11 49 07/22/11 84 07/22/11 15 07/22/11 50 07/22/11 85 07/22/11 16 07/22/11 51 07/22/11 86 07/22/11 17 07/22/11 52 07/22/11 87 07/22/11 18 07/22/11 53 07/22/11 88 07/22/11 19 07/22/11 54 07/22/11 89 07/22/11 20 07/22/11 55 07/22/11 90 07/22/11 21 07/22/11 56 07/22/11 91 07/22/11 22 07/22/11 07/22/11 92 07/22/11 23 07/22/11 58 07/22/11 93 07/22/11 24 07/22/11 07/22/11 94 07/22/11 25 07/22/11 60 07/22/11 95 07/22/11 26 07/22/11 61 07/22/11 96 07/22/11 27 07/22/11 62 07/22/11 07/22/11 28 07/22/11 63 07/22/11 98 07/22/11 29 07/22/11 64 07/22/11 99 07/22/11 30 07/22/11 65 07/22/11 100 07/22/11 31 07/22/11 66 07/22/11 101 07/22/11 32 07/22/11 67 07/22/11 102 07/22/11 33 07/22/11 68 07/22/11 103 07/22/11 34 07/22/11 69 07/22/11 104 07/22/11 35 07/22/11 70 07/22/11 105 07/22/11 W97:DJT/cls/mrlemc

Procedure No.: Procedure

Title:

I Page: O-ADM-051 Outage Risk Assessment and Control I 3 Approval Date: 7/22/11 LIST OF EFFECTIVE PAGES (Rev. 4) Revision Revision Revision Date Date Date 106 07/22/11 141 07/22/11 176 07/22/11 107 07/22/11 142 07/22/11 177 07/22/11 108 07/22/11 143 07/22/11 178 07/22/11 109 07/22/11 144 07/22/11 179 07/22/11 110 07/22/11 145 07/22/11 180 07/22/11 iii 07/22/11 146 07/22/11 181 07/22/11 112 07/22/11 147 07/22/11 182 07/22/11 113 07/22/11 148 07/22/11 183 07/22/11 114 07/22/11 149 07/22/11 184 07/22/11 115 07/22/11 150 07/22/11 185 07/22/11 116 07/22/11 151 07/22/11 186 07/22/11 117 07/22/11 152 07/22/11 187 07/22/11 118 07/22/11 153 07/22/11 188 07/22/11 119 07/22/11 154 07/22/11 189 07/22/11 120 07/22/11 155 07/22/11 190 07/22/11 121 07/22/11 156 07/22/11 191 07/22/11 122 07/22/11 157 07/22/11 192 07/22/11 123 07/22/11 158 07/22/11 193 07/22/11 124 07/22/11 159 07/22/11 194 07/22/11 125 07/22/11 160 07/22/11 195 07/22/11 126 07/22/11 161 07/22/11 196 07/22/11 127 07/22/11 162 07/22/11 197 07/22/11 128 07/22/11 163 07/22/11 198 07/22/11 129 07/22/11 164 07/22/11 199 07/22/11 130 07/22/11 165 07/22/11 200 07/22/11 131 07/22/11 166 07/22/11 201 07/22/11 132 07/22/11 167 07/22/11 202 07/22/11 07/22/11 168 07/22/11 203 07/22/11 134 07/22/11 169 07/22/11 204 07/22/11 135 07/22/11 170 07/22/11 205 07/22/11 136 07/22/11 171 07/22/11 206 07/22/11 137 07/22/11 172 07/22/11 207 07/22/11 138 07/22/11 173 07/22/11 208 07/22/11 139 07/22/11 174 07/22/11 140 07/22/11 175 07/22/11 W97:DJT/cls/mr/emc

TABLE OF CONTENTS Section Page 1.0 PURPOSE 8

2.0 REFERENCES

/RECORDS REOUIRED/COMMITMENT DOCUMENTS 8 3.0 RESPONSIBILITIES 12 4.0 DEFINITIONS 19 5.0 PROCEDURE 24 FIGURES/ENCLOSURES/ATTACHMENTS Figure 1 Typical Heat Up Rates w/Vessel Full 39 Figure 2 Time to Saturation w/Loss of RI-IR with RCS Level 2 Feet Below RX Vessel Flange 40 Figure 3 Typical RCS Heat Up Rates for Reduced Inventory 44 Figure 4 Typical Heat Up Rates in SFP w/Full Offload 45 Figure 5 Time to Core Uncovery from Mid-Loop 46 Enclosure I Minimum Required Equipment, Phase I, Large Decay Heat Load and RCS Temp Less Than 200 Degrees with RCS Loops Filled 47 Enclosure 2 Minimum Required Equipment, Phase I, Large Decay Heat Load and RCS Temp Less Than 200 Degrees without RCS Loops Available 56 Enclosure 3 Minimum Required Equipment, Phase I, Large Decay Heat Load and Reactor Cavity Flooded Greater Than 23 Feet Above the Vessel Flange 65 W97: DJT/ds/mr/m

TABLE OF CONTENTS Section Pa2e Enclosure 4 Minimum Required Equipment, Phase II, Reduced Decay Heat Load and Reactor Cavity Flooded Greater Than 23 Feet Above the Vessel Flange 73 Enclosure 5 Minimum Required Equipment, Phase II, Reduced Decay Heat Load and RCS Temp Less Than 200 Degrees without RCS Loops Available 81 Enclosure 6 Minimum Required Equipment, Phase II, Reduced Decay Heat Load and RCS Temp Less Than 200 Degrees with RCS Loops Filled 90 Enclosure 7 Minimum Required Equipment Spent Fuel Pool During Refueling Outages 99 Enclosure 8 Unit 4 2000 Refueling Outage Overview 101 Enclosure 9 Sample Outage Communications Tool 102 Enclosure 10 Modes 5, 6, and Defueled Active Shutdown Cooling Equipment Protected Train Concept 104 Enclosure 11 Outage Activity Review Checklist 108 Enclosure 12 Component Availability Screening Checklist 109 Enclosure 13 Containment Closure Time Limits 110 W97DJT!cs/mr/emc

TABLE OF CONTENTS Section Attachment 1 Intentionally Left Blank 111 Attachment 2 Temporary Change Notification 112 Attachment 3 Containment Penetration Exceptions 114 Attachment 4 Outage Risk Assessment and Protected Train Posting Verification 117 Attachment 5 Temporary Change Index 129 Attachment 6 Approval of Work on Protected/Operating Train 130 Attachment 7 Risk Significant Schedule Change (RSSC) 132 Attachment 8 Unit 3 Protected Equipment Postings During Enclosure 1 134 Attachment 9 Unit 3 Protected Equipment Postings During Enclosure 2 and 5 (Pressurizer Drained <10%) 139 Attachment 10 Unit 3 Protected Equipment Postings During Enclosure 3 and 4 Cavity Flooded >23 Above the Vessel Flange 143 Attachment 11 Unit 3 Protected Equipment Postings During Enclosure 5 (Pressurizer Filled >10%) 150 W97:DJT/cls/mr/emc

TABLE OF CONTENTS Section Attachment 12 Unit 3 Protected Equipment Postings During Enclosure 6 156 Attachment 13 Unit 3 Protected Equipment Postings During Enclosure 7 RCS Defueled 161 Attachment 14 Unit 4 Protected Equipment Postings During Enclosure 1 167 Attachment 15 Unit 4 Protected Equipment Posting During Enclosure 2 and 5 (Pressurizer Drained <10%) 173 Attachment 16 Unit 4 Protected Equipment Postings During Enclosure 3 and 4 Cavity Flooded >23 Above the Vessel Flange 177 Attachment 17 Unit 4 Protected Equipment Postings During Enclosure 5 (Pressurizer Filled >10%) 185 Attachment 18 Unit 4 Protected Equipment Postings During Enclosure 6 190 Attachment 19 Unit 4 Protected Equipment Postings During Enclosure 7 RCS Defueled 195 Attachment 20 Unit 3 Protected Equipment Postings Restoration 201 Attachment 21 Unit 4 Protected Equipment Postings Restoration 205 WQ7 Ii IT/nI/mr/pmr

1.0 PURPOSE 1.1 This procedure provides the recommended equipment to be maintained when in Modes 5, 6 and defueled. The objective is to maintain the following Key Safe Shutdown Functions: Decay Heat Removal, Inventory Control, Power Availability, Reactivity Control, Containment Integrity Control, and Instrumentation. 1.2 This procedure provides a Defense-In-Depth approach for those planned situations and equipment outages that are identified as high risk to maintaining the Key Safe Shutdown Functions. Emergency response by the Operations staff on shift does not require the use of this procedure. 1.3 This procedure provides the method of and direction for notification to the Operations staff on changes to the plant configuration that would affect the Key Safe Shutdown Functions. 1.4 This procedure provides the shutdown risk assessments which shall be performed when planning and conducting shutdown activities. The goal of these reviews and planning is to minimize undue risk and to maintain Key Safe Shutdown Functions thereby enhancing shutdown safety. 1.5 This procedure provides for qualitative assessments to balance unavailability of equipment against reliability of the key Safe Shutdown Functions to meet Maintenance Rule requirements.

2.0 REFERENCES

/RECORDS REQUTRED/COMMITMENT DOCUMENTS 2.1

References:

2.1.1 FSAR

1. Section 9.3, Appendix 14D, High Density Spent Fuel Storage Racks 2.1.2 Plant Procedures

1. 0-ADM-003, Outage Management

2. 0-ADM-068, Work Week Management

3. 0-ADM-217, Conduct of Infrequently Performed Tests or Evolutions

4. 0-ADM-225, On Line Risk Assessment and Management

5. 0-GMM-05 1.2, Containment Equipment Hatch

6. 3/4-GOP-305, Hot Standby to Cold Shutdown

7. 3/4-GOP-503, Cold Shutdown to Hot Standby

8. 3/4-ONOP-004, Loss of Off-site Power

9. 3/4-ONOP-004.2, Loss of A 4KV Bus

10. 3/4-ONOP-004.3, Loss of B 4KV Bus

11. 3/4-ONOP-004.4, Loss of C 4KV Bus W97DJT/cIs/mr/mc

2.1.2 (Confd)

12. 3/4-ONOP-004.5, Loss of D 4KV Bus

13. 3/4-ONOP-004.l0, Loss Of Offsite Power While On Backfeed

14. 3/4-ONOP-004.11, System Restoration Following Loss Of Offsite Power While On Backfeed

15. 3/4-ONOP-004.12, Loss Of *A 4KV Bus While On Backfeed

16. 3/4-ONOP-004.13, Loss Of *B 4KV Bus While On Backfeed

17. 3/4-ONOP-019, Intake Cooling Water Malfunction

18. 3/4-ONOP-030, Component Cooling Water Malfunction

19. 3/4-ONOP-.033.1, Spent Fuel Pit Cooling System Malfunction

20. 3/4-ONOP-092.3, Startup Transformer Malfunction

21. 3/4-ONOP-092.4, C Bus Transformer Malfunction

22. 0-ONOP-105, Control Room Evacuation

23. 3/4-OP-038.9, Refueling Activities Checkoff List

24. 3/4-OP-041.8, Filling and Venting the Reactor Coolant System

25. 3/4-OP-04 1.9, Reduced Inventory Operations

26. 3/4-OP-050, Residual Heat Removal System

27. 3/4-OP092.l, Main/Auxiliary Transformer Backfeed

28. 3/4-OSP-201.1, RO Daily Logs

29. NP-909, Shutdown Risk

30. AD-AA-101-1004, Work Hour Controls

31. NAP-4 15, Maintenance Rule Program Administration

32. WM-AA-200, Work Management Process Overview

\A107fl IT! !n,rkrv,r

2.1.3 Miscellaneous Documents (i.e., PC/M, Correspondence)

1. NUMARC 91-06, Guidelines for Industry Actions to Assess Shutdown Management

2. NIJREG-1410, Loss of Vital AC Power and RHR During Mid-Loop Operation at Vogtle Unit I

3. NRC Information Notice 93-72, Observations From Recent Shutdown Risk and Outage Management Pilot Team Inspections

4. JPN-PTN-SEMS-94-049

5. PC/M 94-059, Diesel Engine Driver for Standby Steam Gen Feedwater Pp P82B

6. PC/M 95-060, Blackstart Diesel Generator Elimination

7. JPN-NR 96-009, Dated February 9, 1996

8. PTN-BFSM-97-0 18, Spent Fuel Pool and Reactor Coolant System Heatup Following Loss of Cooling

9. INPO SER 1-98, Recurring Inadvertent Reductions of RCS Inventory

10. CR 98-127, OEF 98-005 for INPO SER 1-98

11. CR 98-13 73, Containment Closure Requirements of 0-ADM-05 1

12. CR 98-1657, Less than Adequate Compliance with Requirements and Responsibilities Contained in 0-ADM-05 1.

13. Calculation PTN-BFJF-99-041, Time to Reach Boiling Conditions after a Loss of RHR

14. CR 02-0608, Curves included in this procedure not accurate

15. Evaluation PTN-ENG-SEMS-03-003, Rev. 0

16. L-2003-021, Dated 2/1/03

17. CR 04-1947, Incorrect Volume used in SFP Time to Boil Calculation

18. CR 2006-7472, Loss of Shutdown Cooling During Restoration of 3C 480V Load Center

19. Evaluation PTN-ENG-SEFJ-07-003, Rev 0, Time to Core Uncovery from Mid Loop RCS after EOC with Loss of RHR

20. CR 2006-10277, CA #9, Add a Curve to 0-ADM-051 for Time to Core Uncovery

21. PTN-ENG-SEMS-03-003 Rev. 3, Implementation of Core Offload to 72 hours.

22. PTN-ENG-SENS-07-032, Rev 0, RHR System Operation with the reactor cavity filled and the vessel upper internals in place.

W97: DJT/cIs/mr/mc

2.1.3 (Contd)

23. Engineering Calculation PTN-3FJF-11-153. Rev 0, Turkey Point Unit 3 Spent Fuel Pool Heat Up and Time to 200°F on Loss of Cooling During and After Cycle 25.

24. Engineering Calculation PTN-4FJF-1l-154, Rev 0, Turkey Point Unit 4 Spent Fuel Pool Heat Up and Time to 200°F on Loss of Cooling During and After Cycle 26.

25. INPO Event Report, Level 1, 11-2, Fukushima Daiichi Nuclear Station Spent Fuel Pool Loss of Cooling and Makeup, April 25, 2011.

2.2 Records Required 2.2.1 Advanced notification shall be provided to the Shift Manager for Temporary Changes to the system alignments of Key Safe Shutdown Systems/Components when the minimum required equipment of Enclosures 1 through 7 will not be met. This includes scheduled equipment outages of equipment for maintenance or modification. 2.2.2 A log of all active Temporary Change Notices shall be maintained on Forms 368, similar to Attachment 5. 2.2.3 A mark up of plant operating drawings shall be provided to the Shift Manager whenever Temporary Changes are made on Key Safe Shutdown Systems. 2.2.4 Copies of forms similar to Attachments 1 through 21 shall be maintained in an Outage Risk Assessment Notebook. Two copies of this notebook should be provided, one in the Unit 3 and 4 Control Room; and one in the Work Control Center (WCC) or designated Electronic Risk Assessment Notebook folder. 2.2.5 Completed copies of the below listed items constitute Quality Assurance records, they shall be transmitted to QA Records for retention in accordance with the Quality Assurance Records Program requirements:

1. None 2.3 Commitment Documents 2.3.1 NRC Generic Letter 88-017, Loss of Decay Heat Removal, Dated October 17, 1988 2.3.2 L-2001-201, FPL & NRC, Proposed License Amendments; Response to Request for Additional Selective Implementation of Alternate Source Term; Containment Equipment Door Open During Core Alterations, August 30, 2001 WQ7flJT/n!s/mr/mr

3.0 RESPONSIBILITIES 3.1 Work Controls Manager Organization 3.1.1 The Work Controls Manager is responsible for the following:

1. Overall management of the outage organization.

2. Development of Outage Activities such that the interaction with all involved departments and the planning, scheduling, and execution of the outage schedule provides for Defense In Depth throughout the outage.

3. Obtaining Risk Assessment Team review and Plant Manager approval for all schedule changes that may occur before and during the outage when these changes may impact the Key Safe Shutdown Functions as follows:

a. During the outage, when daily schedule changes affect risk ties (R Logic), obtaining prior approvals as required using a form similar to Attachment 7.

b. Before the outage, after freeze of the schedule from a risk perspective, when schedule changes affect risk ties (R Logic), obtaining prior approvals as required using a form similar to Attachment 7.

4. Communication of current plant status and Safety System availability to plant personnel during the course of the outage. Higher Risk Evolutions and any Contingency Plans should also be conveyed to all appropriate plant personnel.

a. This information should be disseminated via a form similar to Enclosure 9 at least once each 0CC shift.

5. Ensuring that the schedule is sufficiently detailed to convey the impact on Key Safe Shutdown Equipment availability.

6. Ensuring that activities scheduled during Higher Risk Evolutions are limited and strictly controlled.

7. Establishing an outage overtime policy, in accordance with AD-AA-10l-1004, Work Hour Controls, that ensures personnel involved in Higher Risk Evolutions are alert.

8. Scheduling to maximize Key Safe Shutdown System availability.

9. Assigning and tracking corrective action items from the post outage critique.

10. Assigning personnel to be responsible for closure of the equipment and personnel hatches.

W97:DJT/cls/mr/emc

3.1.1 (Confd)

11. Obtaining a list of outage clearance boundaries which affect equipment related to the operating unit and assessing the risk associated with that effect using PSA Development, or other means as appropriate.

12. Providing a page in the Plan of the Day that identifies upcoming TCNs for both the shutdown unit and the operating unit. This page should also include TSAs and LCOs for both units. (N/A if 0CC is utilized)

13. Provide in writing the names if any, of individuals who have been delegated signature authority for the approval of TCNs and Protected Train Work, Attachment 6.

3.1.2 Risk Assessment Team The Risk Assessment Team Leader is responsible for the following: a a a a a H Enclosure 11 should be used as an aid in determining higher risk activities. a a a a S

a. Reviewing the outage schedule to ensure that Key Safe Shutdown Functions are optimized and that Key Safe Shutdown Equipment availability is being maintained as follows:

(1) Prior to the outage, reviewing the outage schedule for higher risk activities, and ensuring those activities are clearly identified in the schedule (R Logic). (2) Prior to the outage, ensuring the higher risk activities are properly tied to maximize Defense In Depth. (3) Prior to the outage, ensuring the outage schedule and higher risk activities are to be developed so as to minimize or eliminate work on protected/operating shutdown cooling equipment. (4) During the outage, reviewing schedule updates when R Logic risk ties are changed or broken for impact on risk using a form similar to Attachment 7.

b. Reviewing proposed switchyard work to assure that the reliability of the off-site power source is maintained. Go to O-ADM-216 for Shared Systems and Switchyard Access Controls.

c. Reviewing of all Contingency Plans for Higher Risk Evolutions and for those periods when Defense In Depth as defined in this procedure is not met. Request a discretionary TCN when minimum equipment for defense-in-depth is met; however, heightened awareness and contingencies are needed to permit a higher risk activity.

d. Assigning and tracking Action Items that are required to implement approved Contingency Plans.

W97:DJT/c!s/mr/emc

3.1.2 (Contd

e. Reviewing the non-outage unit activities and combination of activities that may affect Key Safe Shutdown Functions on the shutdown unit.

f. Conducting a weekly audit of the Outage Risk Assessment Notebook in the Control Room and the Work Control Center.

g. Within 72 hours of the start of a planned outage, review emergent issues of equipment unavailability and ensure TCNs written if required out-of-service equipment will not be returned to service by the planned outage start date.

h. When unavoidable, prior to, and during, the outage, reviewing, approving, and making recommendations to the senior management team for work on protected/operating train using a form similar to Attachment 6.

Schedule meetings and assemble risk assessment team members to review the shutdown risk plan prior to the review and approval by senior management. The team members are those delegated by department managers, knowledgeable of the requirements of this procedure and independent from those who developed the risk logic and shutdown risk plan.

2. The Risk Assessment Team is responsible for the following:

a. Reviewing the outage schedule to ensure that Key Safe Shutdown Functions are optimized and that Key Safe Shutdown Equipment availability is being maintained as follows:

1. Prior to the outage, ensuring the higher risk activities are properly tied to maximize Defense In Depth.

2. Prior to the outage, ensuring the outage schedule is developed so as to minimize or eliminate work on protected/operating shutdown cooling equipment.

3. Review proposed switchyard work to assure that the reliability of the off-site power source is maintained.

4. Reviewing of all Contingency Plans for Higher Risk Evolutions and for those periods when Defense In Depth as defined in this procedure is not met.

5. Review the shutdown risk plan to ensure the periods the plant has reduced defenses is kept as short as possible and contingency plans are clearly established.

b. During the outage, attend team meetings to review the outage schedule to ensure the risk profile is maintained in order to maximize availability of key safe shutdown functions. Review revisions to the shutdown safety plan that result from risk significant schedule changes or emergent work when needed.

Wq7fl. IT/rI/mr/mr

3.2 Operations Management Organization 3.2.1 The Operations Manager is responsible for the following:

1. Providing the Work Controls organization input and oversight in the development of Outage Activities such that the execution of the outage schedule provides for Defense In Depth throughout the outage.

2. Conducting a post outage critique that assesses the outage from a safety perspective.

3. Ensuring the Risk Assessment Team Chairperson submits an annual report to the Chief Nuclear Officer in accordance with NP-909, Shutdown Risk.

4. Approving the performance of all Higher Risk Evolutions.

5. Assuring that all Operations personnel are cognizant of the configuration of Key Safe Shutdown Systems.

6. Assuring that Operations personnel are knowledgeable of the requirement to operate in a conservative manner when conducting shutdown and infrequent evolutions. Tailboard Meetings should normally be utilized for these evolutions.

7. Supervising activities of the Risk Assessment Team.

8. Requesting Contingency Plans from the System Engineers when the minimum equipment recommendations will not be met.

9. Provide in writing the names if any, of individuals who have been delegated signature authority for the approval of TCNs and Protected Train Work, Attachment 6.

3.2.2 Shift Manager

1. The Shift Manager is responsible for the following:

a. Maintaining the Minimum Required Equipment configuration as identified in Enclosures 1 through 7.

b. Assuring that all shift operating personnel are cognizant of the current plant configuration, Key Safe Shutdown Equipment availability, Contingency Plans in affect, and times to core boiling.

c. Maintaining control of plant switchyard access.

d. Assuring compliance with plant Technical Specifications.

e. Ensuring that the Control Room copy of the Outage Risk Assessment Notebook is being properly maintained.

f. Ensuring that Key Safe Shutdown System availability is maximized and that equipment outages are kept to minimum duration. Ensure all required conditions are met to consider a shutdown safety system available when a system work window is closed.

WQ7fl. IT/cI/mr/mr

3.2.1 (Contd

g. Controlling activities on Containment penetrations to be able to close all open penetrations in the event of a loss of RHR cooling in accordance with Enclosure 13. [Commitment Step 2.3.1]

h. Shut down cooling and plant control. Control Room evacuation may be necessary at any time. Procedure O-ONOP-105, Control Room Evacuation, is written for the plant initially in Mode 1, 2, 3. When one or both units are in Mode 4, 5, or 6 only those steps to restore shutdown cooling and stabilize the plant systems after evacuation are necessary.

Enclosure 12 may be used as an aid in determining component availability. a a a

i. When the availability of a component is in question, assessing component availability.

j. Ensure protected equipment signs are installed and removed, as required, when entering/exiting Enclosures 1 through 7, in accordance with Attachments 8 through 21 as applicable.

k. the outage unit experiences an unplanned entry into orange or red risk, THEN refer to O-ADM-2 16 and re-evaluate the need to suspend work in the Switchyard.

3.2.3 Shift Technical Advisor (STA) Each on-shift STA is responsible for the following:

a. Review plant status and provide Attachment 4 to Work Controls for update of Risk Status of the POD.

b. Review plant status to identify the color code of safe shutdown functions and update the Risk Assessment Notebooks.

c. Look ahead on the schedule for planned changes in risk and planned changes in the applicable enclosure. Update and distribute Attachment 4 at the time of the planned change.

3.3 Engineering Manager Organization 3.3.1 Engineering Manager The Engineering Manager is responsible for the following:

a. Assuring that appropriate department personnel are well informed of Higher Risk Evolutions and reduced safe shutdown equipment availability.

b. Reviewing all Contingency Plans for Higher Risk Evolutions.

W97:DJT/cis/mr/emc

3.3.1 t (Cont d )

c. Conducting a weekly audit of the Outage Risk Assessment Notebook in the Control Room and the WCC.

d. Provide in writing the names if any, of individuals who have been delegated signature authority for the approval of TCNs and Protected Train Work, Attachment 6.

3.3.2 System Engineer Each plant System Engineer whose system is associated with the minimum Required Equipment is responsible for the following:

a. Notifiing the Shift Manager in writing of all Temporary Changes in configuration to Key Safe Shutdown Equipment.

b. Providing evaluations as required by the Risk Assessment Team.

c. Taking the lead in resolution of problems and conflicts pertaining to maintaining an acceptable configuration of their system.

d. Performing a periodic (minimum of weekly) walkdowns to verify system configuration and condition prior to Higher Risk Evolutions and prior to update of the Outage Risk Assessment Notebook.

e. Developing Contingency Plans as requested by the Work Controls Manager or the Shift Manager. These plans shall be documented on a form similar to Attachment 2 and filed in the Outage Risk Assessment Notebooks.

f. Ensuring that personnel involved with Contingency Plans have been identified and are familiar with the plan.

g. Ensuring the inclusion of contingency plan actions are incorporated into PWOs as necessary and presenting these plans to the Risk Assessment Team.

h. Ensuring that work plans for their system minimize equipment unavailability to the maximum extent practical.

i. Ensuring that the Defense In Depth concept is maintained for their system.

j. Checking EOOS Book and equipment clearances for the systems they are responsible for.

k. Removal of Temporary Change Notices from the Outage Risk Assessment Notebook in the Control Room and the WCC when they no longer are applicable. Temporary Change Notices shall be retained for the post outage critique.

1. Performing a qualitative assessment of total equipment out of service when preparing a Temporary Change Notice. The assessment compares unavailability of equipment versus reliability of maintaining the Key Safe Shutdown Functions.

W97:DJT/cls/mr/emc

3.4 Training Manager Oraanization 3.4.1 Training Manager

1. The Training Manager is responsible for the following:

a. Providing training briefs, special training, etc., as required to support Operations and Maintenance in Higher Risk Evolutions. This training should emphasize maintenance of the Key Safe Shutdown Functions and Equipment.

b. Ensuring that operator training provides knowledge of the Key Safe Shutdown Functions.

3.5 Maintenance Manager 3.5.1 The Maintenance Manager is responsible for the following:

1. Ensuring that resources are allocated in such a fashion as to minimize the duration of unavailability of Key Safe Shutdown Equipment.

2. Controlling and pre-approving all overtime for personnel involved in work that could affect Key Safe Shutdown Functions.

3. Ensuring that material, documentation, and tooling for work being performed during Higher Risk Evolutions is pre-staged in order to minimize the duration of the evolution.

4. Ensuring that equipment is promptly returned to Operations on the completion of maintenance activities.

5. Ensuring that applicable maintenance personnel and any temporary contractors are adequately trained and knowledgeable of activities that could affect Key Safe Shutdown Functions and that controls are adequate to ensure that work activities do not affect in-service equipment.

6. Ensuring that emergent outage work added to the schedule per O-ADM-003, OUTAGE MANAGEMENT, is reviewed for impact on the Key Safe Shutdown Functions.

7. Provide and maintain personnel at the equipment hatch and airlocks of the containment building to be able to close the equipment hatch with a minimum of 4 bolts, and the personnel hatch as follows: (Ref. Plant procedure O-GMM-05 1.2, Containment Equipment Hatch.)

a. In accordance with Enclosure 13.

b. Provide for the potential unavailability of AC power and the environmental conditions expected.

8. Assigning personnel to monitor the number of lines and hoses that block closure of the containment hatch and airlocks and assuring quick disconnect devices are utilized.

W97:DJT/cls/mrtemc

4.0 DEFINITIONS 4.1 Available a a a a a a a a a a a a a Enclosure 12 may be used as an aid in determining component availability. 4.1 .1 The status of a system, required support systems, structure or component that is in service or can be placed in service in a Functional or Operable state by immediate manual, local-manual, or automatic action. 4.2 Containment Closure 4.2.1 The action to secure containment and its associated structures, systems, and components as a Functional barrier to fission product release. 4.3 Contingency Plan 4.3.1 An approved plan of compensatory actions or measures:

1. To maintain Defense In Depth by alternate means when pre-outage planning reveals that specified systems, structures, or components will not be available, or have significant potential to be lost.

2. To restore Defense In Depth when planned system, structure, or component availability drops below the planned level.

3. To minimize the likelihood of loss of Key Safe Shutdown Functions during Higher Risk Evolutions.

Ai(r7.r

4.4 Decay Heat Removal Capability 4.4.1 The ability to maintain Reactor Coolant System temperature and pressure, and Spent Fuel Pool (SFP) temperature below the specified limits following plant shutdown. 4.5 Defense In Depth 4.5.1 For the purpose of managing risk during unit shutdown, Defense In Depth is the concept of:

1. Providing systems, structures and components to ensure backup of Key Safe Shutdown Functions using redundant, alternate or diverse methods;

2. Planning and scheduling outage activities in a manner that optimizes safety system availability;

3. Providing administrative controls and Contingency Plans that support and/or supplement the above elements.

4.6 Functional 4.6.1 A system, and required support systems, or component is capable of performing the function for which it is intended to be used for to maintain the Key Safe Shutdown Function. The component or system may not have all of its associated support equipment available and temporary supporting systems may be used. 4.7 Higher Risk Evolutions 4.7.1 Outage activities, plant configurations or conditions during shutdown where the plant is more susceptible to an event causing the loss of a Key Safe Shutdown Function. These are defined as activities that can affect the minimum required equipment of Enclosures 1 through 7. 4.8 Key Safe Shutdown Function 4.8.1 Decay heat removal, inventory control, on-site and off-site power availability, reactivity control, Containment Closure, and shutdown monitoring instrumentation. 4.9 Key Safe Shutdown Systems 4.9.1 Those systems, and required support systems, necessary to maintain the plant in a safe condition while in cold or refueling shutdown conditions. This includes systems necessary to maintain spent fuel cooling, Decay Heat Removal Capability, inventory control, off-site and on-site power capability, reactivity control, and containment integrity instrumentation. 4.10 Partial Draindown 4.10.1 The Reactor Coolant System level is lower than 10 percent in the Pressurizer. W97DJT/cIs/mr/emc

Procedure No.: Procedure

Title:

Page: 21. Approval Date: O-ADM-051 Outage Risk Assessment and Control 7/22/11 4.11 Phasel 4.11.1 The initial portion of an outage in which the decay heat load is high and additional equipment is maintained Functional. This provides for a better Defense In Depth. It is defined as the first 240 hours following unit shutdown or completion of fuel offload to the Spent Fuel Pit, whichever occurs first. 4.12 Phase II 4.12.1 The later stages of an outage in which the decay heat load is reduced and relaxations of Functional equipment requirements are allowed. It is defined as greater than 240 hours following unit shutdown, or start of fuel reload to the reactor vessel as part of a full core offload, whichever occurs first. 4.13 Reduced Inventory 4.13.1 A condition with fuel in the reactor vessel and the Reactor Coolant System drained down lower than three feet below the vessel flange. 4.14 Probabilistic Safety Assessment (PSA): 4.14.1 An organized methodology for determining and establishing the likelihood of what combination of system and component failures will lead to a catastrophic event resulting in undue risk to the public. Probabilistic Safety Assessments are performed in the Risk and Reliability Assessment Group (RRAG). 4.15 Risk Assessment Team 4.15.1 A team whose charter is to review the outage plan, revisions to the outage plan and Higher Risk Activities to ensure that Key Safe Shutdown Functions are being maintained at the highest practical levels. The Team is composed of managers or senior designees from the following departments:

Work Controls
Operations Department
Maintenance Department
Engineering Department
Site Licensing
On-Line Scheduling Supervisor
RRAG (Juno Beach via Telcon)

AIn-7.r ITh-.I..i....-1.-..,....

4.15.2 The chairperson is appointed by the Operations Manager. The chairman determines the minimum quorum required to hold a meeting. This determination considers the subject matter to be reviewed and may include additional experts brought in to review specific items. 4.15.3 The Chairperson is responsible for submitting an annual report to the Chief Nuclear Officer in accordance with NP-909, Shutdown Risk. 4.16 Risk Significant Support Equipment 4.16.1 The term applied to equipment necessary to support Key Safe Shutdown Equipment Functions. 4.16.2 This equipment may affect the opposite unit if it is operating. 4.17 Tailboard Meeting 4.17.1 The common term applied to a pre-job briefing held with the personnel involved in an evolution. 4.18 Temporary Change 4.18.1 A change to the system, and required support systems, alignments of the Key Safe Shutdown Systems when this change results in the following condition:

1. The minimum equipment requirements of Enclosures 1 through 7 not being met. This includes equipment outages for maintenance, testing, or modifications.

4.19 Safe Shutdown Function Color Code 4.19.1 Each Safe Shutdown Function is assigned a color code based on the decrease of our defense in depth as noted on Enclosures 1 through 7. A reduction in equipment availability is graded on a critical function that is supported by that equipment, a color code is assigned. 4.19.2 Each key safe shutdown function shall be assigned with a color code based on the equipment available to support that function. Although it may be acceptable to issue a TCN to cover a condition where reduced equipment is available, color coding of key safe shutdown functions is completed on an absolute basis. W97:DJT/cls/mr/emc

4.19.3 Color coding is completed on a daily basis for the following key safe shutdown functions, systems, and support equipment:

1. Decay Heat Removal

2. Inventory Control

3. Power Availability

4. Containment Integrity

5. Instrumentation

6. Risk Significant Equipment

7. SFP Cooling 4.19.4 As part of the daily outage meeting discussion of Outage Risk Assessment, identification of plant conditions and defense in depth plans will be related to a color code based on effect on safe shutdown function equipment status.

4.20 Color Code Definitions GREEN: Acceptable levels of performance of key safe shutdown functions are being maintained. There is no adverse affect on outage risk. WHITE: Acceptable levels of performance of key safe shutdown functions are being maintained. Shutdown monitoring instrumentation is less than listed in the required equipment column; however, our defense-in-depth strategy is not compromised. YELLOW: A degradation of a key safe shutdown function has occurred. The level of degradation may affect our defense in depth strategy. Heightened awareness is desired for this condition. Additional degrees of defense remain and operation at this condition is acceptable considering the risk and scheduler considerations. ORANGE: A significant degradation of a key safe shutdown function has occurred. Our defense in depth strategy has been compromised. Heightened management awareness is required for the duration of the configuration. RED: All barriers of our defense in depth strategy have been broken. Equipment is in an unacceptable condition. All efforts are to be focused on the restoration. AIO7fl TI,k,In,rI.r.,,.

5.0 PROCEDURE. In the event of Control Room evacuation during refueling activities, 0-ONOP- 105 Control Room Evacuation, shall be followed in accordance with notations addressing unit mode (see note prior to Section 4.0 in 0-ONOP-105, Control Room Evacuation, for example). 5.1 General Precautions and Instructions 5.1.1 The following items are general precautions and limitations that should be observed when operating either unit in a shutdown condition:

1. The figures and notes provided by this procedure in the Outage Risk Assessment Notebook are not to be used by Operations or any other plant personnel in lieu of controlled plant procedures, design documents and Technical Specifications. The purpose of this information is to provide adequate information to assist Operations in recognizing and responding to abnormal configurations that may impact the Key Safe Shutdown Functions and Equipment. They may be used also as a guideline for outage planning.

CAUTION The RCS loops can not be considered a valid coolant loop once RCS pressure has been decreased below 100 psig until Substep 5.1.1.2 has been completed.

2. The RCS loops shall not be considered filled per Tech Spec 3.4.1.4.1 unless the following conditions are met:

a. The RCS has been filled and vented with no intervening evolutions that could introduce air into the steam generators (e.g., RCS level has remained above the reactor vessel nozzles)

AND

b. The RCS is pressurized (either water solid or with a pressurizer steam bubble) and above 100 psig.

AND

c. At least two steam generators are filled to greater than 10 percent Narrow Range Level.

3. Entering a Reduced Inventory condition shall be prior approved by the Operations Manager and Plant Manager.

W97:DJT/cls/mr/emc

5.1.1 (Contd)

4. The activities described herein need only be performed for those systems required to maintain the Key Safe Shutdown Functions. Activities described that impact Spent Fuel Pool cooling need only be performed for the first 100 days after unit shutdown for refueling.

5. To support Spent Fuel Pool Cooling heat removal system the following systems shall be monitored and supported by their individual System Engineers:

a. Spent Fuel Pool Cooling (SFP Cooling)

b. Spent Fuel Storage System (SFP Storage)

c. Component Cooling Water System (CCW)

d. Intake Cooling Water System (ICW)

e. Emergency Diesel Generators (EDG)

f. Spent Fuel Building Ventilation (SFP HVAC)

g. On-site and Off-site Power Availability Functions (ref. Substep 5.1.1.8).

(1) When the Reactor is defueled, System Engineers shall monitor the requirements of Enclosure 7 for On-site AND Off-site Power.

6. To support the Decay Heat Removal Capability function the following systems shall be monitored and supported by their individual System Engineers.

a. Residual Heat Removal (RI-fR)

b. Steam Generator (SG)

c. Reactor Coolant System (RCS)

d. Component Cooling Water (CCW)

e. Intake Cooling Water (ICW)

f. Chemical and Volume Control System (CVCS)

g. Safety Injection and RWST (SI)

h. Spent Fuel Pool Cooling (SFP Cooling) See Substep 5.1.1.4.

i. On-site and Off-site Power Availability Functions (ref. Substep 5.1.1.8).

(1) When the Reactor is defueled, System Engineers shall monitor the requirements of Enclosure 7 for On-site AND Off-site Power and Decay Heat Removal. W97:DJT/eIs/mr!mc

5.L1 (Contd)

7. To support the Inventory control capability function the following systems shall be monitored and supported by their individual System Engineers:

a. Chemical and Volume Control System (CVCS)

b. Primary Water System (PW)

c. CVCS Boric Acid Storage System (BAST)

d. Safety Injection and RWST (SI)

e. Reactor Coolant System (RCS)

f. Residual Heat Removal (RHR)

8. To support the On-site and Off-site Power Availability Function the following systems shall be monitored and supported by their individual System Engineers:

a. Switchyard (SWYD)

b. Startup Transformer (SU)

c. Main and Aux Transformer (MAIN & AUX XFMR)

d. C Bus Transformer (C BUS XFMR)

e. 4160 Volt Busses, including Station Blackout Tie (4KV Dist)

f. Emergency Diesel Generators (EDG)

g. 480 Volt Distribution (480V Dist)

h. 125 Volt DC System (125 VDC Dist)

i. 120 Volt Vital AC System (120VAC Dist)

9. To support the Reactivity Control Function the following systems shall be monitored and supported by their individual System Engineers:

a. Rod Control System (CRDM)

b. Chemical and Volume Control System (CVCS)

c. CVCS Boric Acid Storage System (BAST)

W97:DJT/cls/mrlemc

5.LL9 (Contd)

d. Primary Water System (PW)

e. Safety Injection and RWST (SI)

f. Reactor Coolant System (RCS)

g. Residual Heat Removal (RHR)

h. Steam Generator System (SG)

10. To support the Shutdown Monitoring Instrumentation Function the following systems and components shall be monitored and supported by their individual System/Component Engineers:

a. Nuclear Instrumentation (NIS)

b. Area Radiation Monitoring System (ARMS)

c. Process Radiation Monitoring System (PRMS)

d. Core Exit Thermocouples (CET)

e. Reactor Vessel Level System (QSPDS HJTC)

f. RCS Draindown Level System (RCSDDLIS)

g. Containment Water Level System (Wide Range)

h. Containment Sump level Systems (Narrow Range and Pneumatic)

i. Pressurizer Level System (PZR LVL)

j. RCS Pressure Instrumentation (RCS PRES)

k. RCS Wide Range Temperature Instrument (RCS TEMP)

1. OMS Actuation circuits (OMS)

m. RCS Pressure Control Instruments (RCS PRES CONT)

n. Fire Detection Instrumentation (FIRE DET)

o. Containment Pressure System W97:DJT/cls/mr/ernc

5.1.1 (Confd)

11. To support Fire Protection Systems the following systems shall be monitored by their individual System Engineers:

a. Raw Water Storage Tanks (RWT)

b. Fire Water pumps and Water Distribution Systems (FIRE DIST)

c. Automatic and Manual Deluge Systems (FIRE SUPPRESSION)

d. Halon Systems (HALON SYS)

e. Fire Extinguishers (FIRE EXT)

f. Fire Detection Systems (FIRE DET)

g. Fire Barriers and Doors (FIRE BARRIERS)

12. To support Risk Significant Support Equipment, the following systems and components shall be monitored and supported by their individual System Engineers/Component Engineers:

a. Auxiliary Building HVAC

b. Instrument Air

c. DC Equipment Room HVAC

d. Service Water

e. Load Center/Switchgear Room HVAC

13. Refueling outages are performed with some consistency of activities.

Enclosure 8 contains a typical refueling outage overview. Also shown is the relationship of the outage chronology to the specific enclosures of this procedure.

14. When the unit is depressurized in Enclosure 2 of the outage, work should not be permitted on the Units 3 and 4 side of the switchyard or in the Cable Spreading Room Generator Lockout Panels until the water level in the refueling cavity is 23 feet or greater than the Reactor Vessel Flange. If work is required during this time, Attachment 6 must be completed.

15. In Enclosure 5, work should not be permitted on the Unit 3 and 4 side of the switchyard or in the Cable Spreading Room Generator Lockout Panels until water level is 1O% in the pressurizer following reactor head installation. If work is required during this time, Attachment 6 must be completed.

W97:DJT/cls/mrlemc

5.1.1 (Contd

16. When restoring power to the Startup Transformer from a backfeed alignment, work (restoration) should not be permitted until the refueling cavity is greater than or equal to 23 ft above the reactor vessel flange, and the core is reloaded to avoid challenging SFP cooling with the core offloaded unless an alternate means of SFP cooling is available.

17. During Enclosures 2 and 5, the secondary side of at least two steam generator levels should be maintained above 10% NR to support reflux cooling in the event of a loss of RHR.

18. The alternate RHR flow path through MOV*872 should be maintained available during Enclosures 1, 2, 5, and 6 to provide additional defense in depth and support the contingencies used in off normal operating procedures.

19. When entering a Partial Draindown condition the following shall apply:

a. During Phase 1 of an outage, both Emergency Diesel Generators on the affected unit shall remain available until the water level in the refueling cavity is 23 feet or greater than the Reactor Vessel Flange.

b. Two RHR, two CCW, and two ICW pumps shall remain available until the water level in the refueling cavity is 23 feet or greater than the Reactor Vessel Flange.

c. The RCS vent path shall be at least the area equivalent to the removal of a pressurizer safety.

d. At least 2 CETs shall be available. CETs may be rendered unavailable when reactor vessel head detensioning has commenced.

20. It is permissible for only one train of RHR to be operable and in operation in Mode 6 with the refueling cavity flooded to greater than or equal to 23 feet, without regard to whether the reactor vessel upper internals assembly is in place or removed provided the reactor has been subcritical for at least 72 hours. (Ref: PTN-ENG-SENS-07-032)

W7fl. IT/rIc/mr/pmr

5.1.1 (Contd)

21. Hoses and equipment which prevents closure of the equipment hatch and personnel airlock doors should be kept to a minimum when fuel is in the reactor vessel.

a. The Work Controls Manager shall assign personnel to periodically monitor the number of lines.

b. Lines and hoses should be equipped with quick disconnects at the hatch or airlock.

c. When large equipment is fouling the hatches a specific plan shall be in place to clear the hatch in the event Containment Closure needs to be established. The equipment hatch (with a minimum of four bolts) and the personnel hatch shall be capable of closure following a loss of RHR cooling as follows:

(1) In accordance with Enclosure 13. (2) Figures 1, 2 and 3 provide RCS heat-up rate information for planning purposes. Personnel required should be in place and dressed out, but may be assigned other duties that would not interfere with their ability to close the hatch. (3) The capability for containment closure includes provisions for unavailability of AC power, and the environmental conditions expected. (4) Activities which would prevent equipment hatch closure within the required time, will be included in the R-logic to ensure the ability to meet containment closure is maintained.

22. At least one process valve in each penetration that is NOT pressurized should be kept closed or capable of being closed whenever fuel is in the Reactor Vessel. Exceptions may be taken under administrative controls for testing, surveillance, and maintenance.

a. If an exception is taken, and at least one valve in the penetration is capable of closure either manually from the Control Room or locally, the penetration shall be logged on a form similar to Attachment 3. The log entry shall identify the actions necessary to close the penetration.

b. If an exception is taken, and the penetration is NOT capable of being closed by at least one valve, a TCN with a contingency plan to achieve closure is required PRIOR to authorizing work on the penetration.

c. If an exception is taken while RCS level is lower than 3 feet below the vessel flange, and the penetration is NOT capable of being closed by at least one valve, a TCN with a contingency plan to achieve closure and meet 20 psi containment pressure is required PRIOR to authorizing work on the penetration. [Commitment Step 2.3.1]

W97:DJT/cls/mr/emc

5.1.1 (Contd)

23. IF the Containment Equipment Hatch is maintained open, THEN the individual responsible for Fast Closure of the Equipment Hatch shall sign Part B of Attachment 3 The Equipment Hatch is required to be closed and held in place with a minimum of four bolts upon direction from the Shift Manager as follows: [Commitment Step 2.3.1]

a. In accordance with Enclosure 13.

b. The capability for containment closure includes provisions for unavailability of AC power, and the environmental conditions expected.

24. IF the Personnel Airlock Door is maintained open, THEN the individual responsible to close at least one Containment Personnel Airlock Door shall sign Part C of Attachment 3. This individual is required to close at least one airlock door if directed by the Shift Manager in accordance with Enclosure 13. [Commitment Step 2.3.1]

25. For U3 Cycle 22 Offload during U3RF023, Engineering concurrence is required prior to commencing full core offload (minimum 72 hrs after shutdown) to the spent fuel pooi. Once fuel unload to the SFP has commenced, unload SHALL be suspended if Spent Fuel Pool temperature is greater than or equal to 145°F.

For Unit 4, a minimum of 72 hours after shutdown is required prior to commencing full core offload to the Spent Fuel Pool. Engineering concurrence should be obtained prior to commencing full core offload to the spent fuel pool based on actual core power history, canal temperature etc. Additionally, there is an administrative limit of 140°F SFP temperature for fuel offload to occur.

26. ANYTIME the Reactor Coolant System is to be drained to less than 70%

Pressurizer Level (Cold Cal. LT*462) INSTALL a Reactor Vessel Head Vent path AND a Pressurizer Vessel Vent path using *..op..o41.7, Draining the Reactor Coolant System, Subsection 5.1. (Refer to Substeps 2.1.3.10 and 2.1.3.11.)

27. If the Reactor Coolant System is to be drained lower than 3 feet below the Reactor Vessel Flange with fuel in the reactor vessel, the following requirements are applicable: [Commitment Step 2.3.1]

a. All prerequisites are met in accordance with 3 (4)-OP-041.9, Reduced Inventory Operations.

b. Two CETs are in operation with continuous Control Room read out if the reactor head is on the flange.

c. Both RC5 level indications are available in the Control Room with continuous readout and the level hose is in service with an operator stationed locally in containment or monitoring from the Control Room via a camera and monitor with an Uninterruptible Power Supply (UPS).

WQ7 ft IT!rLImr/cmc

5.1.1.27 (Contd)

d. Containment Closure will meet the requirements listed in the Precautions and Limitations of 3 (4)-OP-041.9, Reduced Inventory Operations.

e. One train of RHR in service and the other train of RHR operable.

f. O-ADM-2 17, Conduct of Infrequently Performed Tests or Evolutions, Brief

g. Sufficient, non-hand held lighting available on L1-3-6422.

h. 2 of 4 Source Range NI with one audible count rate.

28. The requirements of Enclosures 1 through 7 are verified shiftly using 3/4-OSP-201.1, RO Daily Logs. If revisions are made to Enclosures 1 through 7, then 3/4-OSP-20 1.1 should be reviewed to determine if it also needs to be revised.

29. During A OR B 4kv Bus outages, grounds may be installed at *AC13 cubicle. The following requirements must be satisfied:

a. The specific steps for removal of grounds, and restoration of the

                                  *AC13 cubicle shall be provided in the associated A      ,    B 4kv Bus TCN.

b. The time that grounds are installed should be minimized.

5.2 Advanced Notification of Temporary Changes 5.2.1 The System Engineer should communicate and interact with cognizant and responsible Projects Supervisor, Operations, Maintenance, and Scheduling personnel to determine those upcoming (24 hours to 7 Days) activities which may effect the configuration of systems included in this procedure. 5.2.2 When the minimum equipment requirements of Enclosures 1 through 7 will not be met and results in a yellow, orange, or red risk color, or a discretionary TCN is requested by the Risk Assessment Team, the System Engineer shall complete a Temporary Change Notification along with a markup of applicable plant operating drawings. This notice shall also address any special notes, precautions, training briefs, procedural references, or Contingency Plans as necessary to adequately address the proposed change and maintain the Defense In Depth approach. Wq7fl. IT/cI/mrImr

5.2.3 The System Engineer shall review the Temporary Change Notice with the Shift Manager to determine if sufficient detail is provided to adequately control the change and to inform the operations staff of the change. 5.2.4 The Shift Manager shall approve the change in plant status. 5.2.5 Temporary change notifications shall be approved/accepted by Plant Management as defined by the scope of the change. If a department is unaffected by the temporary change, it is acceptable to mark N/A on their respective signature line. 5.2.6 A Risk Assessment Team Member shall update the Outage Risk Assessment Notebook in the Control Room and the Work Control Center. 5.2.7 The Shift Manager is responsible through the shift turnover process to notify the oncoming shift of all new Temporary Changes received since the last time they stood shift. 5.2.8 A Risk Assessment Team Member shall notify the Shift Manager and revise the Outage Risk Assessment Notebook to reflect restoration of all Temporary Changes. This should be done within one working day of restoration. The Temporary Change Notice shall be removed from the Outage Risk Assessment Notebook in the Control Room and the WCC and a copy be retained for the post outage critique. 5.2.9 Emergent evolutions shall be performed as directed by the Shift Manager with follow up RSSC forms or TCNs, if required, completed and recorded in the Outage Risk Assessment Notebook in the Control Room and the WCC within 72 hours. 5.2.10 The Temporary Change Notice shall include a qualitative or quantitative (PSA Evaluation) of the total equipment that is out of service during the evolution. Equipment unavailability should be assessed against the reliability of maintaining the Key Safe Shutdown Functions. 5.2.11 The TCN will include recovery guidelines and procedure mark-ups, if applicable, to any off normal response procedure designed to mitigate the loss of a key safe shutdown function that is challenged by the system or equipment configuration. (Ref SOER 09-01) 5.3 Outage Schedule Risk Assessment 5.3.1 During development of the outage schedule, the Work Controls Manager shall perform the following activities:

1. Using input from Operations, Higher Risk Evolutions shall be identified.

2. Key Safe Shutdown Equipment maintenance windows should be kept to a minimum practical duration.

3. Obtain Risk Assessment Team review of the schedule.

4. Ensure that activities scheduled during Higher Risk Evolutions are kept to a minimum.

5. Establish the outage work schedules.

Wg7fl.IT/nI/mr/m

5.3.1 (Contd)

6. Obtain a thorough independent review of the schedule with emphasis on maintaining Key Safe Shutdown Functions.

7. Ensure that the schedule is distributed to all plant personnel who are required to perform or support activities in the schedule.

8. Identify activities that could result in open containment penetrations with fuel in the Reactor Vessel.

9. When it is determined that work on the protected/operating train is unavoidable, ensuring that prior approval is obtained using a form similar to Attachment 6.

5.3.2 During the outage the Work Controls Manager/OCC Outage Manager shall perform the following risk assessment activities:

1. Obtain prior risk review and prior approval as required for schedule changes that affect the Key Safe Shutdown Functions (R Logic) using a form similar to Attachment 7.

2. Risk Assessment Team meetings should be held at least weekly.

3. Contingency Plans for Higher Risk Evolutions shall be communicated to appropriate plant personnel.

4. Unavailability of Key Safe Shutdown Equipment shall be conveyed to appropriate plant personnel. An individual responsible for returning the equipment to Available status should normally be assigned. Means which should be used to communicate status include any of the following:

a. Plant television monitors

b. The Plan of the Day

c. Weekly site newsletter

d. Outage Communications Tool (see Enclosure 9)

5. The Work Controls 0CC Outage Manager shall obtain Operations Manager, Maintenance Manager, Engineering Manager, and Plant Manager review and approval of all Contingency Plans developed. This shall be done when minimum equipment is not available or when Higher Risk Evolutions are planned.

6. Ensure that the Fire Protection Department performed a weekly overall assessment of impaired fire protection features and transient combustibles.

5.3.2 (Contd

7. Ensure that activities are scheduled and performed in a manner in which Containment Closure can be achieved following a loss of cooling as follows:

a. In accordance with Enclosure 13

b. The capability for containment closure includes provisions for unavailability of AC power, and the environmental conditions expected.

c. Figures 1, 2 and 3 provide RCS heat-up rate information for planning purposes.

8. When fuel is in the reactor vessel and RCS inventory will be lower than 3 feet below the vessel flange, equipment requirements will be controlled via plant procedure 3/4-OP-04 1.9, Reduced Inventory Operations. If minimum equipment requirements cannot be met, evolutions will be stopped or secured by the most expedient actions and RCS level will be restored to higher than 3 feet below the vessel flange.

[Commitment Step 2.3.1] 5.4 Minimum Required Equipment 5.4.1 Typical post shutdown unit heat up rates following a loss of cooling are shown in Figures 1, 2 and 3. The time frames for operator action prior to heating above 200°F at the core outlet can be derived from these curves. NOTES I I

Enclosures I through 7 contain suggested preplanned contingency actions which the Shift Manager can evaluate for implementation when minimum equipment requirements are not met. The Shift Manager shall determine which contingencies are to be implemented for any given situation. I Steps 5.4.2 through 5.4.4 only apply when fuel is in the Containment Building. When the reactor is defueled spent fuel pool status and required support systems should be as specified in the RO logs and Enclosure 7 and monitored by the System Engineers.

I

If a loss of Spent Fuel Pit Cooling occurs when the reactor is defueled take actions to I restore the required systems as specified in 3/4-ONOP-033. I, Spent Fuel Pit Cooling System Malfunction, 3/4-ONOP-030, Component Cooling Water System Malfunction, 3/4-ONOP-019, Intake Cooling Water System Malfunction, and/or applicable TCNs. I reactor dofueled Spent Fuel Pit heat up rates are provided in Figure 4, and can Typical be utilized to estimate available repair/action time.

5.4.2 During Phase I of an outage, the equipment listed in Enclosures 1 through 3 should be maintained Available. When the minimum equipment recommendations are not met, the Shift Manager shall determine the appropriate contingencies to be implemented. Wg7fl.lT/nI/mr/mc

5.4.3 During Phase II of an outage, the Equipment listed in Enclosures 4 through 6 should be maintained Available. When the minimum equipment recommendations are not met, the Shift Manager shall determine the appropriate contingencies to be implemented. 5.4.4 Except for approved testing, surveillances, and operating evolutions, which are screened per Enclosure 12, to reduce equipment below levels required in Enclosures 1 through 7, the following shall be accomplished:

1. The time of the equipment outage shall be minimized.

2. A Contingency Plan shall be developed and approved by the Work Controls Manager, Operations Manager, Maintenance Manager, Engineering Manager, and Plant Manager when work on the equipment results in yellow, orange or red color code. An exception to this is RCS level yellow condition in Enclosures 2 and 5; a TCN is not required.

3. The Risk Assessment Team shall review the deviation and any Contingency Plan.

4. A form similar to Attachment 2 shall be completed and filed in the Outage Risk Assessment Notebook in the Control Room and the WCC.

5. The Shift Manager may waive the above requirements for emergency problems arising on shift, however the Operations Manager and Plant Manager shall be notified as soon as practical, and the above requirements shall be performed within 72 working hours.

5.4.5 When the containment penetration status is reduced below that required in Substep 5.1.1.22, the deviation shall be recorded by the Unit Supervisor on a form similar Attachment 3 in the Outage Risk Assessment Notebook in the WCC. 5.5 Protection of Required Equipment NOTES I

Enclosure 10 depicts the general concept for protection of required equipment in active support of shutdown cooling.

I I

Specific guidance for placement and removal of signs and/or physical barriers is provided in Attachments 8 through 21.

I I

All postings are not intended to provide physical barriers, rather to provide information I and heightened awareness.

a a a I 5.5.1 The strategy for protection of shutdown cooling includes the concept that the designated operating shutdown cooling train, and its power supplies, shall always be protected. 5.5.2 In addition, when a single train of shutdown cooling is protected, it shall also be in operation. In cases where both shutdown cooling trains are protected, only one train is required to be operating. 5.5.3 Required equipment that actively supports shutdown cooling shall be protected by means of signs and/or physical barriers. Wq7fl. IT/I/mr/mr

5.5.4 Required equipment not in active support of shutdown cooling should be protected by other administrative means which includes the following:

1. Schedule logic ties

2. Outage communication tools

3. Shift turnovers and turnover meetings

4. Periodic required equipment verifications performed by operations personnel NOTES For the purposes of this procedure, the following activities are not considered work:

I

Non-intrusive activities (e.g., walk-downs, Routine Security and Firewatch roves, etc.)

that do not involve component manipulations I

I Emergency response actions
Chemistiy sampling of the SFP in the SFP Heat Exchanger room
Routine operator rounds I I

Verbal permission to entet as specified on the posted sign or barrie, is still required for the non-routine walkdowns. I _ i 5.5.5 In the attachments that post the protected train barriers, the D 4kv Bus Room is protected when the C ICW or CCW Pump is required to support operability on the protected RHR Train or SFP Cooling Train (i.e., B RHR train in service and protected with the B ICW Pump unavailable and C ICW Pump running with the D 4kv Bus aligned to the B 4kv Bus). 5.5.6 To maximize effectiveness of protected equipment signs and/or barriers work should not be scheduled or allowed on required equipment that is posted as protected unless plant design or emergent conditions make the work unavoidable. 5.5.7 When work on required equipment that is posted as protected is unavoidable due to plant design or emergent conditions, then the activity shall be reviewed by the Risk Assessment Team, and approved by the Senior Management Team. A form similar to Attachment 6 shall be used to document the deviation and approval. 5.5.8 A copy of the approved Attachment 6 shall be in hand at the job site prior to commencing work. WQ7fl. IT/c/mr/tm

5.6 Outage Emergent Work Review 5.6.1 Emergent work shall be evaluated for addition to the outage per O-ADM-003, Outage Planning, Scheduling and Implementation. 5.6.2 When emergent work and/or changing conditions impacts the outage schedule the Work Controls Manager, or 0CC Outage Manager on shift, shall determine if the Key Safe Shutdown Functions are affected.

1. The Work Controls Manager shall use Operations Department input to make this determination.

2. A Temporary Change Notice is processed as required by Subsection 5.2 and 5.4.

NOTE A minor change to a R flagged activity is when NO adverse risk significant change occurs due to the requested change having obvious inconsequential degradation to outage or shutdown safety risk. Review of Enclosure I through 7 and II should be considered to verify no adverse impact to risk. Ensure the basis is adequately documented. S a a a I

3. If R Logic ties are impacted and the changes are not deemed as minor by the Risk Assessment Team leader, prior approval to break R Logic ties shall be obtained using a form similar to Attachment 7.

4. If R Logic ties are impacted, and the changes are deemed as minor by the Risk Assessment Team Leader, breaking R Logic ties may be done with the verbal approval of the Risk Assessment Team Leader provided such approval is documented using a form similar to Attachment 7.

5. If emergent conditions require work on protected/operating shutdown cooling train, approvals shall be obtained using a form similar to Attachment 6.

5.7 Post Outage Critique 5.7.1 The Operations Manager shall conduct a post outage critique of the outage activities from a risk perspective. 5.7.2 The post outage critique shall be approved by the Plant Manager. 5.7.3 Corrective action items from the critique shall be assigned to the responsible department head and tracked until closure. END OF TEXT W97fl.IThI/mr/mn

Procedure No.: Procedure

Title:

Page: 39 Approval Date: O-ADM-051 Outage Risk Assessment and Control 7/22/11 FIGURE 1 (Page 1 of 1) TYPICAL HEAT UP RATES W/VESSEL FULL 10 I I I I I I I I I I I I - L I

0 I I I I I I _I_.__ I I I oi I I I I -- I I

                                           -----I                                                  ______i__-

I I I I I I I I I I I I I I I I I I I I I I I 0 5 10 15 20 25 30 35 40 45 50 55 60 Time Since Shutdown (Odjs) B/U - ig MWD/MTU

                                                                                                          -  B/U     7ø@ MWD/MTU B/U     16,5O MWO/MTU W97:DJT/cls)mr/emc

ID - C) 0) (1) 0),- 0 ID CD 0) N C) (0 0) (I

             -cccr                        C)IC                         UCSj                                   c(
             @4 (N C) C)                 LDCD(ON-                     c00)D)0]                       v-      C (N (N C)

(4 (4 (4 (4 (4 @4 c4 CN (4 (4

0) U) C) (N 00) 4 0) 0) CD N 010 0U0 0)c.ICD -0C G CD CD CDN-CD CCC, c5C. U) 10(1) CD

                                           ,--,-,-*-.                                                         (4 (4 @4 (4              (1 (4 (4 @4 CD CC            CN C) CD         C0(4(00U)                                                          (0  CD a]                      0) (0 J N. C N. (

0 (10 (10(9Uc qN C) .t 10 (0 (0 0)0)0) CN U) [010 N N N

                                                          --                       ((((SIC)                           (-INN                   (((4 (C)      N. 0        1- 0                          CDC                 CD0)0)0)0)N                                CDC)N

0) C) CD C) C Ccc --0) -:*t cc L 00 C1(NC)

(4 @4 C) CD ci (DNN cc (((SIC) (NC4C4 (N 0)0) CD.C4(4@4 c0C.- rcOcoc)C.. CD

           )0)           C0(JNC)CDCD                                                                                        ()N0)N CDN(-0)cD0)                       -.-NcJ                       U)I1)(0CDCD.                      cccdcdc

(((SIN C(C)CNC\ICJ (4 (4 (4 (4 0 0)0)100) 0) U) C) N

0) (DCD 0)CDNCI(D0 L1)C)(NU)CD

        . 4)                 0)0)00                        cc5                                                        0)0) 000

(.1 (4 (N(SIC)(N @4CSlC(CSI (1 C) CD C) CID (2 U)) CDCDC4 0)00 CJ Cc 4a-C CD CDCD 0)0)0)0)0 - ,- (4 (SI (N (N CS( (N (N (N C) CD CD Cu I C a) t N C) (4 CD C) 0) 0) .-C)C)C( 0)NC) (00) 0) - (q.-cq o(qo 2 . (0 N 0) cc

                                       . -v--- C) (SI CD )

C) C) C) C) C) (N LflCD(ONN N((C)CJ(N (]C)CD., C) CD CD CD CD U) 0). 0 CDNL1) cc,)

         -    roa]0)0C                              CD(U)                          0)0)0)0)00                          CNC4CDCD

NC)C5)C) N(SJCNCJCDCD CDC)C)C) C) C)

                                                                                    .ctL0c4tCD                                                   r N@4C)U)@4C)CD                                      c0C                     (F                                     00                       cI(D (00)0)00.C4                                                        0)0)00.-.--                                                    CD (0
              .C4NNN                                      CSINC)                 C) (I CD C) C) C)                     C) CD                C)CD CDCD<00)a-N(-C                                    00)0)11)                    0)C)4LC)(Dc0.                        0(00 (0) 0) 11) (40) (0 C) 0 N- C)                       C) 0) U)                                    (0) 0)0CNCDC)ct                                  (D(NcO                     4CSICDCD                              10(0<0 C) (4 (4 C) (4 (4 (4               C) C) (SI C)                 ()CDCDCDC)C]                    C)C)CD 0 C)           0 C)     CD  N (I U)                    (4 C) CD                 CD0)0)C)-0                        0)10(5(0)

(0(1 Nc 010)0 i-c(

0) -CDCD0L0[DCD <00)0 NCDCDU)10CD Ni-0)<0 (N(NC4(NCS) CDC)CDCDC)CDC) C)CDCDCD

             ;                                                     CDCSI                             l(0Q4ccC)                  0)(N(0 c                                                      aZa0)p)                    0C4(Slc)                           ci,)11)(0
          -                  +/-
                            .&                                      L                                                           i.:

(slnoH) UMOP4flI4S ee ewil 0 2 11)

                                                                                                                                                             -E I

(-4 I

-)

CD N C)

Procedure No.: I Procedure

Title:

Page: 41 Approval Date: O-ADM-051 Outage Risk Assessment and Control 7/22/11 FIGURE 2 (Page 2 of 4) TIME TO SATURATION W/LOSS OF RHR WITH RCS LEVEL 2 FEET BELOW RX VESSEL FLANGE RCS Temperature (°F) 60 frr:9O 1OQ 4:Q5 11O 168 3957 3826 3695 3564 3432 3301 3170 3039 2907 2777 2646 2515 I72 3994 3861 3729 3596 3464 3331 3199 3066 2934 2802 2670 2538 176 4030 3896 3763 3629 3495 3362 3228 3094 2961 2828 2694 2561

                               -18O       4066  3932      3797      3662     3527     3392    3257        3122    2987  2853  2719      2584
                  .                       41.03 39.67     38.31     36.95    35.58    34.22   32.86   . 31.50   30.14 28.79 27,43     26.07 I

41.39 40.02 38.65 37.27 35.90 34.53 33.15 31.78 30.41 29.04 27.67 26.30

                      .--....1.8.8I     I 41.76 40.37     38.99     37.60    36.22    34.83   33.45       32.06   30.68 29.30 27.92     26.54
                      .--. 192I
                                 --       42.12 40.72     39.32     37.93    36.53    35.13   33.74       32.34   30.94 29.55 28.16     26.77 196I :   I j
                  .g ;---20OI             42.48 41.07     39.66     38.26    36.85    35.44   34.03     - 32.62   31.21 29.81 28.40     27.00
                        .--             I
                                 -2041    42,86 41.43     40.00     38.58    37.16    35.74   34.32       32.90   31.48 30.06 28.64     27.23 c   :-..-2Qt            43.21 41.78     40.34  -  38.91    37.48    36.04   34.61       33.18   31.74 30.32 28.8      27.46

-212 43.57 42.13 1 40.68 39.24 37.79 36.35 34.90 33.46 32.01 30.57 29.13 27.69

                       .-216I             43.94 42.48     41.02     39.57    38.11    3665    35.19       33.74   32.28 30.83 29.37     27.92

:N 44.30 42.83 41.36 39.89 38.42 36.95 35.48 34:01 32.54 31.08 29.6 28.15 I:.*224I 44.67 43.18 41.70 40.22 38.74 37.26 - 35.78 34.29 32.81 31.34 29.86 28.38 4503 4354 4204 4055 3905 3756 3607 3457 3308 3159 3010 2861 1 -228 3636 3485 3335 3185 3034 2884

[ 232 4539 4389 4238 4088 3937 3786 236 4576 4424 4272 4120 3968 3817 3665 3513 3361 3210 3059 2907 240 4612 44 59 43 06 41 53 40 00 38 47 36 94 35 41 33 88 32 36 30 83 29 31 W97:DJT/cls/mr/emc

0 CD 0 -I 0 C 0 C,, CD 3 Time after Shutdown (Hours) 0 C

                                                                                      -                    .-                                         0 0.

0) )i) (1) UI . .. C) C.O N N - 000 C CD 02.0202 -. 0) ) 0)02 U) J iJ C D0)02.00)C002.0 (C I I I I I I WI

lWl I I I I I I I N I I I S I WI 1 S H

Co

   ) F.) F) I) F.) F.) F) F) I.) F) F) F.) F.) F) -       - - - - -z .4 .4                ..D   .4 .4.4 - - - -    -

000(02020)0))C)FJr.) .4 CJ)Cfl0)0202CDCD-F.) F.) F.) F) F) F) F) F) F) F) - - - - - .4 - - - - - - - - .4 - - - -S - - - - - - Q00CD0202020)0>0)UI02--- C iD

   -0poQoCD020>02-0>0)0>Fz-zoo Q020)02bbLz00>F) 0)0)0)0002020J)4sCi0) 02

(*)

                                                                                                                                     -I S -                   - i - - -                    -                    -                                                    CD     )) 
                  ---                            - -           -----                  ---        - -    -  - S  -  - - .4 - .4 CD020)0>0)0)UI--OOO(D                                                                                                             3           z V

020 O0)()02C)D020)CJ1CøC,)0)0(.) CD

                                                                                                                                     -S
         .4 .4                           .4. .4 .4         .4 .4 .4    .4  .4.       .4  .4.   .4       .4 CD Ii 0)MCDb020>F)02U!-
             .4020)C02UI 00)QUICD                                                                                    (fl-S4Cj)CD SQ             0) 0)
   .4   ----              - -S    -   -   -   .4 -    -    -   -   - -    - .4 - - .4     - -    -  -   .4 .43 .4.4
                                        .4pppCDp2p2 002CD020)30)Q.402(fl-z02UI
     -)F)0)0..02Cn4z.F)CD                                                 UI0.s0)023FJ0CDiU) C
    .3                  C. .4   -  .4                  .4 .3 .4 .4     .4 .4    ..C.    .4 0pPpD02p4 .t 02J0)4z()-.-(D 0-UI0)CD0)C02FCD 01 CDUIOUICOr-.J 02CDCDCDQ020)02(s02(n -S2F-0. 02(DCDO-M c.
    .4.          .4 .4 .4. .5 .4 ..S .4 .4 .4 .4 .4 .4 ..4 .5 .3 .4 .4 .4 .3 .4. .4 .3 000Q4

0) C.) I.) 0 CD -1 UI F) 0 020) F) 0 02 0) F C bi C.) b 020) C) -i 0)0) <.) 00202 )

C0)CD0)UIo0)cncCD0>F0)OCDF)0>0)F)Cfl0) Di 5 - - - -- - 5 - - - - .4 ._z opppo)) (C QCD02lUI)0CDC3i 0020) 002Oi.. 02C)-020)C)-020) ) 0)C4z4-z0) 02 (flU) 020)C)-0)C)CD. z) IseI

FIGURE 2 (Page 4 of 4) TIME TO SATURATION W/LOSS OF RHR WITH RCS LEVEL 2 FEET BELOW RX VESSEL FLANGE RCS Temperature (°F) 1O 12 130 13& 140 145 150 155 160

168 23.84 22.54 21.24 19.93 18.63 17.33 16.04 14.75 13.45 2406 172 22 75 21 43 20 11 18 80 17 49 16 19 1488 13 58
176 24.28 22.95 21.63 20.30 18.97 17.65 16.34 15.02 13.70 180 24.50 23.16 21.82 20.48 19.14 17.81 16A8 15.15 13.82 184 24.72 23.37 22.02 20.66 19.31 17.97 16.63 15.29 13.95 0 188 244 23.57 22.21 20.85 19.48 18.13 16.78 15.42 14.07 192 25.16 23.78 22,41 21,03 19.66 18.29 16.93 15.56 14.20

                              . 196 0                       25.37     23.99   22.60     21.21     19.83 18.45   17.07   15,70 14.32 4-

200 25.59 - 24.19 22.80 21.40 20.00 18.61 - 17.22 15.83 14.44

.. 204 25.81 24.40 22.99 21.58 20.17 18.77 17.37 15.97 14.57 Cl) r.,,.

208 - 26.03 24.61 *f 23.19 21.76 20.34 18.93 17.52 16.10 14.69 212 2625 2481 2338 2195 2051 1909 1766 1624 1481 a) E .216 26,47 25.02

23.58 22.13 20.68 19.25 17.81 16.37 14.94 I

2O 26.69 25.23 23.77 22.31 20.85 19.41 17.96 16.51 15.06 224 2691 2544 2397 2250 2103 1957 1811 1665 1519 228 27.12 25.64 24,16 22.68 21.20 19.72 18.25 16.78 15.31 232 27.34 25.85 24.36 22.86 - 21.37 19.88 18.40 16.92 15.43

                                 .?36   27,56    26.06    24.55     23.04           20.04   18.55   17.05 15.56 240   27 78    2626     24 75     23 23     21 71 2020    18 70 - 17 19 15 68 W97:DJT/cls/mr/emc

C) Co C) C) C) C) C) RCS Heal Up (Deg- /min) 0-10 20-30 -

             --                        ;;;7f
                                             -/-

3 CD 70 - -- 1 E:E: : I

                             -I
                                    -y----

I, I I I (#D ? 80 D - - CD C 90 I: CD CD 100 -r----- - -_.

                                                         -1 iio -        --i-/-------i-            -              -

. 120 - -/ 130 - -I- - D 140 - D I L___.L 1 150 - z::ztz::jzzz:[zzt::zzz !:.!2, 180 ------+--- - ------ 190 - -----I- -- 200 -H--H----H - - -H--H- - z1z::iz:f1z::tz:ztz:t:z1zz1 230 21-0 J C) C)

FIGURE 4 (Page 1 of 1) TYPICAL HEAT UP RATES IN SFP 14 prom 100°F _From 120°F 12 From 149fJ 10 8 Heat Up Time (hours) 6 4 2 0 3 5 7 9 11 13 15 17 19 21 23 25 27 29 31 33 35 37 39 41 43 45 47 49 51 53 55 57 59 Days After Shutdown (Assumes Full Core Offload Starting at 72 Hours After Shutdown) W/FULL OFFLOAD NOTE: Heat Up Curves to 200°F are Found in the Plant Curve Book, Section 8 W97:DJT/cls/mr/emc

FIGURE 5 (Page 1 of 1) TIME TO CORE UNCOVERY FROM MID-LOOP (Assuming Adequate Vent to Atmospheric Pressure) Time to Core Uncovery from Mid-Loop (Assuming Adequate Vent To Atmosoheric Pressure) 350 hfltial RCS Temperature

                                                                                                                                                                          -  IOOF 300 120 F
                                                                                                                                                                      -    -140F 200F

250

                                     -             -j                  -                                                             -

0 C.) .

                                              -,. -. [       -.

200 -r L ... - .L

                     -       ..           -.--+                   .--           .I--.-    -.-   --.---     -              - - ----  -     -

I -

_ __---:- --z -

                                       --       zI_

150 ---- 100 zz: zz 50 0 72 144 216 288 360 432 504 576 648 720 Time after Shutdown at OC (hrs) W97:DJT/cls/mr/emc

Procedure No.: Procedure

Title:

Page:

                                              -                                                             47 Approval Date:

O-ADM-051 Outage Risk Assessment and Control 7/22/11 ENCLOSURE 1 (Page 1 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AND RCS TEMP LESS THAN 200 DEGREES WITH RCS LOOPS FILLED Required Function Equipment Contingency Action Color Code Decay Heat Two RHR Pumps 1. Take immediate action to repair the failed pump. 1 ORANGE Removal 2. Go to 3/4-ONOP-050, LOSS OF RHR, for loss of 0 RED RHR.

3. Maximize RCS inventory as much as is achievable.

4. Maintain RCS pressurized to 100 psig to meet ioops filled criteria.

5. Maintain RCS temperature as low as possible.

6. Ensure Feed and Bleed Decay Heat Removal capability, using the HHSI pumps, is available.

7. Maintain Decay Heat Removal capability with at least two Steam Generators, including a source of feedwater.

8. Suspend any activities that would risk the remaining RHR, ICW, or CCW Pumps; EDG; and 4KV Bus.

9. Upon loss of both pumps, initiate actions to establish Containment Closure except for the equipment hatch.

10. Verify that the equipment hatch can be closed within the time frame to heat up to Mode 4 following a loss of shutdown cooling as predicted using the heatup rates of Figure 1. Station the necessary personnel at the hatch with direct communications to the RO.

Two RHR Heat 1. Take action as described for RHR Pumps. 1 ORANGE Exchangers 0 RED Two CCW Pumps 1. Go to 3/4-ONOP-030, COMPONENT 1 ORANGE COOLING WATER MALFUNCTION, for loss 0 RED of CCW.

2. Carry out other actions per RHR pumps above.

W97:DJT/cls/mr/emc

ENCLOSURE 1 (Page 2 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD A1T) RCS TEMP LESS THAN 200 DEGREES WITH RCS LOOPS FILLED Required Function Equipment Contingency Action Color Code Decay Heat Two CCW Heat 1. Go to 3/4-ONOP-030, COMPONENT 1 Hx - Removal Exchangers COOLING WATER MALFUNCTION, for loss ORANGE (Contd) of CCW. o - RED

2. Take action to restore the unavailable component to service.

3. Take other actions as described for RHR Pumps.

Two ICW Pumps 1. Go to 3/4-ONOP-019, INTAKE COOLING 1 ORANGE WATER MALFUNCTION, for loss of ICW. 0 RED

2. Suspend activities that may risk the remaining ICW pumps.

3. CCW cross-tie to the other unit may be appropriate.

4. Notify the Work Controls Manager, Operations Manager, Maintenance Manager, and Plant Manager.

Two ICW Headers 1. Verify that at least two ICW pumps and two 1 YELLOW CCW heat exchangers are aligned to the 0 RED remaining ICW header.

2. Prior to removing an ICW header from service, verify that the basket strainer associated with the remaining header is clean.

3. Have a contingency plan, with responsible individuals designated, in place to restore the header to service.

Source of 1. Take action to restore the unavailable component. 0 YELLOW feedwater and a 2. Restrict Activities that could potentially threaten flowpath from one RHR of the following: SGFP SSGFP Condensate PP Condensate Transfer PP SGWL PP 2 Steam Dump to 1. Take action to restore the unavailable component. 0YELLOW Atmosphere 2. Restrict Activities that could potentially threaten Valves RHR W97:DJT/cls/mr/emc

ENCLOSURE 1 (Page 3 of 9) MINIMIJM REQUiRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AN]) RCS TEMP LESS THAN 200 DEGREES WITH RCS LOOPS FILLED Required Function Equipment Contingency Action Color Code Inventory Two Charging 1. Initiate action to repair the unavailable charging 1-YELLOW control Pumps pump. 0- ORANGE (one with an 2. Notify the Operations, Work Controls, available EDG Maintenance and Plant Managers. power source to 3. Verify the availability of at least two HHSI meet the Pumps with suction aligned to an RWST with at requirement least 20,000 gallons of water AND an available below). flowpath to the RCS.

4. Do not reduce RCS inventory, if possible take action to maximize RCS inventory.

5. Maintain RCS temperature as low as possible.

6. Suspend activities that would place any remaining charging pump and its power supply at risk.

Flowpath from 1. Initiate action to repair the unavailable 0 ORANGE the Charging components. 0 RED, if no Pumps to the 2. Notify the Operations, Work Controls, HHSI RCS (Regen Hx Maintenance, and Plant Managers. flowpath or RCP seals) 3. Verify the availability of two HHSI Pumps with and suction suction aligned to an RWST with at least 20,000 capability from gallons of water AND a flowpath available to BAST or RWST the RCS. Two of four 1. Initiate action to repair the unavailable 1 YELLOW Primary Water components. 0 ORANGE Pumps 2. Notify Operations, Work Controls, Maintenance, and Plant Managers.

3. Verify capability to cross connect Primary Water from the opposite unit.

4. Verify the availability of the charging pump suction_from the_RWST.

Iwo of tour 1. Initiate action to repair the unavailable 1-YELLOW Boric Acid components. 0- ORANGE Pumps 2. Notify Operations, Work Controls, Maintenance, and Plant Managers.

3. Verify the availability of the charging pump suction from the RWST.

4. Verify the availability of two HHSI pumps with suction aligned to an RWST with at least 20,000 gallons of water AND an available flowpath to the RCS.

W97:DJT/cls/mr/emc

ENCLOSURE 1 (Page 4 of 9) MIKIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD ANI RCS TEMP LESS THAN 200 DEGREES WITH RCS LOOPS FILLED Required Function Equipment Contingency Action Color Code Inventory Two of four HHSI 1. Initiate action to restore the unavailable 1 YELLOW Control Pumps each with components. 0 ORANGE (Contd) an emergency 2. Verify the availability of at least two power supply and charging pumps. suction capability 3. Maximize RCS inventory. from an RWST 4. Maintain RCS temperature as low as with at least possible. 20,000 gallons of 5. Notify the Operations, Work Controls, water AND an Maintenance, and Plant Managers. available flowpath totheRCS. On-site and Two Transformers 1. Go to 3/4-ONOP-004, LOSS OF OFF-SITE 1 xfmr with Off-site capable of the POWER, for loss of off-site power. SBO tie - Power below powering A 2. Go to 3/4-ONOP-092.3, STARTUP YELLOW or B 4KV Bus

TRANSFORMER MALFUNCTION, for S/U transformer malfunction. 1 xfmr without

                 . Startup          3. Initiate actions to return the required          SBO tie  -

transformer to service. ORANGE

                 . AUX on           4. Verify the availability of both EDGs.

backfeed 5. Verify the availability of the station blackout 0 xfrm RED tie.

                 . Opposite unit    6. Suspend activities that would risk the startup             remaining power supplies.

transformer to 7. Verify the availability of one C Bus to power A Bus A or B 4KV Bus.

8. Notify the Operations, Work Controls,

One C Bus Maintenance, and Plant Managers.

transformer to A or B Bus Reference Step 5.1.1.29 AI(v7.r

ENCLOSURE 1 (Page 5 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AND RCS TEMP LESS THAN 200 DEGREES WITH RCS LOOPS FILLED Required Function Equipment Contingency Action Color Code On-site and A B and D 1. Take action to restore the out-of-service Loss of D Bus Off-site 41V Busses components. Go to appropriate procedure - YELLOW Power below: 3/4-ONOP-004.2, LOSS OF A 4KV BUS Loss of A or B 3/4-ONOP-004.3, LOSS OF B 4KV BUS Bus 3/4-ONOP-004.5, LOSS OF D 4KV BUS - ORANGE

2. Verif,i at least two on-site sources of AC power are available. I - RED

3. For loss of Off-site power go to 3/4-ONOP-004. LGSS OF OFF-SITE POWER.

4. With A B, or P 4KV Busses unavailable, verify the ability to power A or B Bus from one C Bus transformer.

5. With D 4KV Bus unavailable maintain both associated unit EDGs availabe.

Two Emergency 1. Take action to restore the unavailable EDG to 1 YELLOW Diesel Generators service. 0 ORANGE on the Associated 2. Suspend activities that may risk the Off-site Unit power sources.

3. Verify availability of the station blackout tie.

4. Verity the ability to power A or B Bus from one C Bus transformer.

Station Blackout 1. Verify availability of both associated unit 0 wI C bus tie Tie EDGs. YELLOW

2. Suspend activities that may risk the Off-site power supplies. 0 w/o:

3. Verify the ability to power A or B Bus from

C Bus tie one C Bus transformer.

AND Opposite unit SU Xfmr - ORANGE W97: DJT/cls/mr/mc

ENCLOSURE 1 (Page 6 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AND RCS TEMP LESS THAN 200 DEGREES WITH RCS LOOPS FILLED Required Function Equipment Contingency Action Color Code Reactivity CB> 0-OP-028.2 1. Take action to restore boron concentration RED if C< Control SDM Calculation (CB) to> 0-OP-028.2 SDM Calculation. 1ation

2. Verifv NO primary water additions in progress.

Shutdown Two of four 1. Take action to restore the failed 1 WHITE 0-YELLOW Monitoring Source Range components. Instrumentation Instruments 2. Suspend activities that could reduce the available Shutdown Margin.

3. Notifi the Operations, Work Controls, Maintenance,_and Plant_Managers.

ARIVIS Channels: 1. Take action to restore the failed Loss of 1 or Three Inside components. WHITE Containment # 2. Install temporary monitoring equipment in the affected area.

3. Suspend activities that may increase radiation levels in the affected area.

PRMS Channels: 1. Take action to secure releases via the Loss of 1 or R-ll, R-12, R-14, unmonitored pathway OR take action to R-19 continue releases as allowed by Technical Specifications.

2. Consider installation of temporary monitoring_equipment.

2 Core Exit 1. Arrange with I&C for alternate readouts or 0 YELLOW Thermocouples monitoring of CETs if possible.

2. Verifi that two channels of wide range TH0T are available.

3. Maintain RCS greater than 10 percent Wide Range Pressurizer Level.

One at a time may be OOS for calibration.

W97:DJT/cls/mr/emc

ENCLOSURE 1 (Page 7 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AND RCS TEMP LESS THAN 200 DEGREES WITH RCS LOOPS FILLED Required Function Equipment Contingency Action Color Code Shutdown One Channel of 1. Take action to restore at least one channel 0 WHITE Monitoring Reactor Vessel as soon as possible. Instrumentation Level HJTC 2. Maximize RCS inventory as much as is (Contd) (QSPDS) allowed by plant conditions.

3. Maintain RCS greater than 10 percent Wide Range Pressurizer Level.

One Channel of 1. Take action to restore one channel to 0 WHITE Containment service as soon as possible. Water Level Indication Two Channels of 1. Restore two channels to service as soon as 1 WHITE Containment possible. 0 YELLOW Sump Level 2. Suspend activities that may result in Indication increased sump level.

3. Verify that any temporary drain hoses are not resulting in loss of RCS inventory at least_once_per_shift.

One of Four 1. Suspend activities which may result in 0 WHITE Channels of RCS inventory loss. Pressurizer Level Indication RCS Pressure 1. Verify sufficient OMS trains are still 0 WHITE Instruments available. PT-402, PT-403, 2. Secure power to any MOV which could and PT-405 result in RHR loss due to unwanted action from the unavailable pressure channel. (N/A if interlocks defeated.)

3. Notify the Operations, Work Controls, Maintenance,_and_Plant_Managers.

RCS Wide Range 1. Verify the availability of two CETs. Per ioop, only TH0T and TCOLD: 2. Verify that OMS controls are not affected THOT or At least one by the unavailable channel. TCOLD channel per loop WHITE W97:DJT/cls/mr/emc

ENCLOSURE 1 (Page 8 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY hEAT LOAD AN]) RCS TEMP LESS THAN 200 DEGREES WITH RCS LOOPS FILLED Function / Support Required Equipment Equipment Contingency Action Color Code Containment Equipment Hatch 1. Suspend activities that risk required Required Time Met - Closure (capable of being Decay Heat Removal Equipment. GREEN closed with four 2. Initiate action to restore the capability bolts in to close the hatch in the required time accordance with frame. Required Time Not Enclosure 13.)

3. Notify the Maintenance, Operations, Met (TCN Required)

Work Controls, and Plant Managers. - YELLOW Personnel Hatch 1. Suspend activities that risk required (capable of being Decay Heat Removal Equipment. closed in 2. Initiate action to restore the capability accordance with to close the hatch in the required time Enclosure 13.)

frame.

3. Notify the Maintenance, Operations, Work Controls, and Plant Managers.

Containment 1. If an exception is taken, and at least one Penetrations (At valve in the penetration is capable of least one valve in closure, either manually from the each penetration Control Room or locally, the that is NOT penetration shall be logged on pressurized should Attachment 3. The log entry shall be kept closed, or identify the actions necessary to close capable of being the penetration. closed in 2. If an exception is taken, and the accordance with penetration is NOT capable of being Enclosure 13.) closed by at least one valve, a TCN Exceptions may with a contingency plan to achieve be taken under closure is required PRIOR to administrative authorizing work on the penetration. controls for 3. Initiate action to restore closure testing, capability. surveillance, and 4. Suspend activities that would risk maintenance, required Decay Heat Removal Equipment.

5. Notify the Maintenance, Operations, Work_Controls,_and_Plant_Managers.

Risk One Auxiliary 1. out-of-service time is to exceed 119 0 YELLOW Significant Building Exhaust hours, THEN notify the Work Controls Equipment Fan Manager and Plant Manager.

2. Assess the impact on the operating unit.

3. Assess the impact on the running RHR Pump.

Capability includes provisions for the unavailability of AC power and environmental conditions expected. W97:DJT/cls/mr/emc

ENCLOSURE 1 (Page 9 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AND RCS TEMP LESS THAN 200 DEGREES WITH RCS LOOPS FILLED Support Required Equipment Equipment Contingency Action Color Code Risk One Diesel Driven 1. Verify the availability of a portable 0 YELLOW Significant Instrument Air Instrument Air Compressor. Equipment Compressor AND 2. Verify the availability of the Instrument Air (Contd) the Instrument Air Cross Tie. Cross Tie Lines 3. IF out-of-service time is to exceed 548 hours, THEN notify the Work Controls Manager and Plant Manager.

4. Assess the impact on the operating unit.

Vital DC Room 1. Monitor temperature in the Inverter and DC 1 WHITE HVAC two of

                           -             Equipment Rooms.                                0 YELLOW three units        2. Install portable fans 2J verify availability of required E16D,        portable fans.

E16E, EI6F 3. Assess the impact on the operating unit. Service Water 1. Assess the impact on the operating unit. Loss of 1 or Pumps One more WHITE Electric pump AND one Diesel driven pump WQ7fl. IT/ri/mrImr

ENCLOSURE 2 (Page 1 of 9) M1MMUM REQUiRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AN]) RCS TEMP LESS THAN 200 DEGREES WITHOUT RCS LOOPS AVAILABLE Required Function Equipment Contingency Action Color Code Decay Heat Iwo RHR Pumps 1. Take immediate action to repair the failed 1 -ORANGE Removal pump. 0- RED

2. Go to 3/4-ONOP-050, LOSS OF RHR, for loss of RHR.

3. Establish or maintain Reactor Vessel level higher than three feet below the vessel flange.

Maximize RCS inventory as much as is achievable.

4. Maintain RCS temperature as low as possible.

5. Ensure Feed and Bleed decay heat removal capability, using the HHSI pumps, is available.

6. Suspend any activities that would risk the remaining RHR, ICW, or CCW Pumps; EDG; AND 4KV Bus.

7. Upon loss of both pumps, initiate actions to establish Containment Closure except for the equipment hatch.

8. Verifi that the equipment hatch can be closed within the time frame to heat up to Mode 4 following a loss of shutdown cooling as time to saturation predicted using the Figure 2.

Station the necessary personnel at the hatch with direct communications to the RO.

9. Investigate the possibility of flooding the Reactor Cavity to a height of 23 feet above the Reactor Vessel Flange.

10. If RCS inventory is at Mid-Loop, then refer to Figure 5, Time to Core Uncovery from Mid-Loop.

Two RHR Heat 1. Take action as described for RHR Pumps. 1 Hx Exchangers ORANGE OHx RED Two CCW 1. Go to 3/4-ONOP-030, COMPONENT 1- ORANGE Pump s* COOLING WATER MALFUNCTION, for 0- RED loss of CCW.

2. Carry out other actions as described per RHR pumps above.

Powered from independent power sources if RCS level lower than 3 feet below the vessel flange. [Commitment Step 2.3.1] NQ7fl, IT//mr/m

ENCLOSURE 2 (Page 2 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AN]) RCS TEMP LESS THAN 200 DEGREES WITHOUT RCS LOOPS AVAILABLE Required Function Equipment Contingency Action Color Code Decay Heat Two CCW Heat 1. Go to 3/4-ONOP-030, COMPONENT 1 Hx - Removal Exchangers COOLING WATER MALFUNCTION, for ORANGE (Contd) loss of CCW.

2. Take action to restore the unavailable component to service.

3. Take other actions as described for RHR Pumps.

Two ICW 1. Go to 3/4-ONOP-019, INTAKE COOLING 1 -ORANGE Pumps* WATER MALFUNCTION, for loss of ICW. - RED

2. Suspend activities that may risk the remaining ICW Pumps.

3. CCW cross-tie to the other unit may be appropriate.

4. Notify the Work Controls Manager, Operations Manager, Maintenance Manager, and_Plant_Manager.

Two ICW 1. Verify at least two ICW pumps AND two 1 YELLOW Headers CCW heat exchangers are aligned to the 0 RED remaining ICW header.

2. Prior to removing an ICW header from service, verify that the basket strainer associated with the remaining header is clean.

3. Have a contingency plan, with responsible individuals designated, in place to restore the header_to_service.

Powered from independent power sources if RCS level lower than 3 feet below the vessel flange. [Commitment Step 2.3.1] W97:DJT/cls/mr/emc

ENCLOSURE 2 (Page 3 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AND RCS TEMP LESS THAN 200 DEGREES WITHOUT RCS LOOPS AVAILABLE Required Function Equipment Contingency Action Color Code Inventory Two Charging 1. Initiate action to repair the unavailable 1- ORANGE Control Pumps (One with charging pump. 0- RED an available EDG 2. Notify the Operations, Work Controls, power source. Maintenance and Plant Managers. Both with an 3. Verify the availability of two HHSI Pumps available EDG to with suction aligned to an RWST with at least meet the 20,000 gallons of water AND an available requirement flowpath to the RCS. below.*) 4. Do not reduce RCS inventory; if possible, take action to maximize RCS inventory.

5. Maintain RCS temperature as low as possible.

6. Suspend activities that would place any remaining charging pump and its power supply at risk.

Flowpath from the 1. Initiate action to repair the unavailable 0 ORANGE charging pump to components. 0 RED if no the RCS (Regen 2. Notify the Operations, Work Controls, HSIh Hx or RCP seals) Maintenance, and Plant Managers. and suction 3. Verify the availability of two HHSI Pumps capability from with suction aligned to an RWST with at least BAST or RWST 20,000 gallons of water AND an available flowpath to the_RCS. Two of four 1. Initiate action to repair the unavailable 1 YELLOW Primary Water components. 0 ORANGE Pumps 2. Notify Operations, Work Controls, Maintenance, and Plant Managers.

3. Verify capability to cross connect Primary Water from opposite unit.

4. Verify the availability of the charging pump suction_from_the_RWST.

Two of four Boric 1. Initiate action to repair the unavailable 1- YELLOW Acid Pumps components. 0- ORANGE

2. Notify Operations, Work Controls, Maintenance, and Plant Managers.

3. Verify the availability of the charging pump suction from the RWST.

4. Verify the availability of two HHSI pumps with suction aligned to an RWST with at least 20,000 gallons of water AND an available flowpath to the RCS.

Two charging pumps are required with available EDG power source, if RCS level is lower than 3 feet below the vessel flange. [Commitment Step 2.3.1] WQ7fl. ITIrI/mr/pm

ENCLOSURE 2 (Page 4 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AINI) RCS TEMP LESS THAN 200 DEGREES WITHOUT RCS LOOPS AVAILABLE Required Function Equipment Contingency Action Color Code Inventory Two of four HHSI 1. Initiate action to restore the unavailable components 1YELLOW Control Pumps each with an 2. Verify the availability of at least two charging pumps. 0-ORANGE (Contd) emergency power 3. Maximize RCS inventory. supply and suction 4. Maintain RCS temperature as low as possible. capability from an 5. Notify the Operations, Work Controls, Maintenance, RWST with at least and Plant Managers. 20,000 gallons of water AND an available flowpath to the RCS* RCS Inventory at or N/A YELLOW above 5% level in drained to

                            .                                                                        higher than 3 pressurizer. (Color feet below code determination                                                                flange only)

ORANGE Drained hot leg mid nozzle On-site and Two of the below 1. Go to 3/4-ONOP-004, LOSS OF OFF-SITE POWER, 1 trf Off-site Power listed Transformers for loss of off-site power. ORANGE capable of powering 2. Go to 3/4-ONOP-092.3, STARTUP TRANSFORMER A OR B 4KV Bus MALFUNCTION, for S/U transformer malfunction.

                   . Startup          3. Initiate actions to return the required transformer to
                   . AUX on backfeed      service.

Opposite unit 4. Verify the availability of both EDGs.

startup 5. Verify the availability of the station blackout tie. transformer to A 6. Suspend activities that would risk the remaining power Bus supplies.

Either units C 7. Verify the ability of one C Bus to power A , B 4KV Bus transformer Bus.

to A OR B Bus 8. Notify the Operations, Work Controls, Maintenance, and Plant_Managers. Both hot and cold leg injection path are required if RCS level is lower than 3 feet below the vessel flange. [Commitment Step 2.3.1] W97:D.JT/cls/mr/emc

ENCLOSURE 2 (Page 5 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AN]) RCS TEMP LESS THAN 200 DEGREES WITHOUT RCS LOOPS AVAILABLE Required Function Equipment Contingency Action Color Code On-site and A, B AND D 4KV 1. Take action to restore the out-of-service Loss of D bus Off-site Busses components. Go to appropriate procedure YELLOW below: Loss of A or B ower Bus 3/4-ONOP-004.2, LOSS OF A 4KV BUS - 3/4-ONOP-004.3, LOSS OF B 4KV BUS ORANGE 1 3/4-ONOP-004.5, LOSS OF D 4KV BUS -

2. Verify at least two on-site sources of AC power are available.

3. For loss of Off-site power go to 3/4-ONOP-004, LOSS OF OFF-SITE POWER.

4. With A, B, or D 4KV Busses unavailable, verify the ability to power A or B Bus from one C Bus transformer.

5. With D 4KV Bus unavailable, maintain both associated_unit_EDGs_available.

Two Emergency 1. Take action to restore the unavailable EDG to 1 YELLOW Diesel Generators service. 0 ORANGE on the Associated 2. Suspend activities that may risk the Off-site Unit power sources.

3. Verify availability of the station blackout tie.

4. Verify the ability to power A j3 B Bus from one_C_Bus_transformer.

Station Blackout 1. Verify availability of both associated unit 0 wI C bus tie Tie EDGs. YELLOW

2. Suspend activities that may risk the Off-site power supplies. 0 w/o:

3. Verify the ability to power A OR B Bus from C Bus tie one C Bus transformer.

Opposite unit SU Xfmr - ORANGE Wq7fl. IT/Is/mrImr

ENCLOSURE 2 (Page 6 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AN]) RCS TEMP LESS THAN 200 DEGREES WITHOUT RCS LOOPS AVAILABLE Required Function Equipment Contingency Action Color Code Reactivity CB> 0-OP-028.2 1. Take action to restore boron concentration (CB) to RED if CB < Control SDM Calculation > 0-OP-028.2 SDM Calculation, or for Mode 5, or > Required Refueling CB as applicable.

                   > Required          2. Verif, NO primary water additions in progress.

Refueling CB for Mode 6 Shutdown Two of Four Source 1. Take action to restore the failed components. 1/4 WHITE Monitoring Range Instruments 2. Suspend activities that could reduce the available 0/4 YELLOW Instrumentation (1 with Audible Shutdown Margin. Count Rate in Mode 3. Notify the Operations, Work Controls,

6) Maintenance, and Plant Managers.

ARMS Channels: 1. Take action to restore the failed components. Loss of 1 or Three Inside 2. Install temporary monitoring equipment in the more WHITE Containment # affected area.

3. Suspend activities that may increase radiation levels in the affected area.

PRMS Channels: 1. Take action to secure releases via the unmonitored Loss of 1 or R-l 1, R-12, R-14 pathway OR take action to continue releases as more WHITE allowed by Technical Specifications.

2. Consider installation of temporary monitoring.

equipment. 2 Core Exit 1. Arrange with I&C for alternate readouts or 0 YELLOW Thermocouples monitoring of CETs if possible. ( Required when 2. Verify that two channels of wide range THOT are the reactor vessel available. head is fully 3. Maintain RCS greater than 10 percent Wide tensioned.)* Range Pressurizer Level. One Channel of 1. Take action to restore at least one channel as soon 0 WHITE Reactor Vessel as possible. Level HJTC 2. Maximize RCS inventory as much as is allowed (QSPDS) by plant conditions. (Required when 3. Maintain RCS greater than 10 percent Wide the reactor vessel Range Pressurizer Level. head is fully 4. If OOS as part of reactor disassembly, verify two tensioned.) channels of the reactor vessel draindown level indication available, one with control room readout. IF <2 channels available, maintain RCS level_higher_than_3_feet_below_the_vessel_flange. A minimum of two (2) CETs are required whenever RCS level is lower than 3 feet below the vessel flange. [Commitment Step 2.3.1]

In containment, one at a time may be OOS for calibration, if RCS level is NOT lower than 3 feet below the vessel flange.

[Commitment Step 2.3.1] W97:DJT/cls/mr/emc

ENCLOSURE 2 (Page 7 of 9) MI1[IM1JM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AND RCS TEMP LESS THAN 200 DEGREES WITHOUT RCS LOOPS AVAILABLE Required Function Equipment Contingency Action Color Code Shutdown One Channel of 1. Take action to restore one channel to service 0 WHITE Monitoring Containment as soon as possible. Instrumentation Water Level (Contd) Indication Two Channels of 1. Restore two channels to service as soon as 1 WHITE Containment possible. o - YELLOW Sump Level 2. Suspend activities that may result in increased Indication* sump level.

3. Verify that any temporary drain hoses are not resulting in loss of RCS inventory at least once_per_shift.

One Pressurizer 1. Suspend activities which may result in RCS 0 WHITE Cold Calibrated inventory loss. Level Indication 2. Monitor temporary drain hoses for loss of

                  ##,                       RCS inventory at least once per shift.

3. Consider installation of temporary level hose as_appropriate_for_plant_conditions.

RCS Pressure 1. Verify sufficient OMS trains are still 1 WHITE Instruments available. 0 YELLOW PT-402, PT-403, 2. Notify the Operations, Work Controls, AND PT-405 Maintenance, and Plant Managers. RCS Wide Range 1. Verify the availability of two CETs. For each ioop TH0T and TCOLD: 2. Verify that OMS controls are not affected by oniy THOT or At least one the unavailable channel. TCOLD WHITE channel per loop None YELLOW Reactor Vessel 1. Maintain RCS level higher than three (3) feet 1 YELLOW Draindown Level below the vessel flange. 0 ORANGE Indication: Two 2. Do not reduce RCS inventory until tWo requires Control of three channels channels are available. .

                                                                                 .        Room indication available,           3. Investigate the possibility of verifying (includes level           Reactor Vessel Level via some other means, hose) one with            (i.e., level hose or QSPDS).

Control Room indication #,

The level hose AND both draindown level indicators are required for RCS level lower than 3 feet below the vessel flange.

[Commitment Step 2.3.1]

1. May be OOS during depressurization of RCS for refill of reference leg.

Two channels are required if RCS level is lower than 3 feet below the vessel flange. [Commitment Step 2.3.1]

- IF RCS level is on scale in reactor vessel draindown level instruments, THEN pressurizer cold calibrated level instrument not required.

jj. pressurizer cold calibrated level indication is greater than 10%, THEN reactor vessel draindown level indication is not required. Wq7n.ITkI/mr/pmc

ENCLOSURE 2 (Page 8 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AND RCS TEMP LESS THAN 200 DEGREES WITHOUT RCS LOOPS AVAILABLE Function / Required Support Contingency Action Color Code Equipment Equipment Containment Equipment Hatch 1. Suspend activities that risk required Decay Heat Required Time Closure (capable of being closec Removal Equipment. Met GREEN with four bolts in 2. Initiate action to restore the capability to close the accordance with hatch in the required time frame. Enclosure 13) * + 3. Notify the Maintenance, Operations, Work Required Time Controls, and Plant Managers. Not Met (TCN Personnel Hatch 1. Suspend activities that risk required Decay Heat Required) - (capable of being Removal Equipment. YELLOW closed in accordance 2. Initiate action to restore the capability to close the with Enclosure 13) * + hatch in the required time frame.

3. Notify the Maintenance, Operations, Work Required Time Controls, and Plant Managers. rJot Met During Containment 1. If an exception is taken, and at least one valve in Penetrations (At least the penetration is capable of closure, either Lnventory -

one valve in each manually from the Control Room or locally, the ORANGE penetration that is penetration shall be logged on Attachment 3. The NOT pressurized log entry shall identify the actions necessary to should be kept closed close the penetration. or capable of being 2. If an exception is taken, and the penetration is closed in accordance NOT capable of being closed by at least one with Enclosure 13) # valve, a TCN with a contingency plan to achieve Exceptions may be closure is required PRIOR to authorizing work taken under on the penetration. administrative controls 3. If an exception is taken while RCS level is lower for testing, than 3 below the vessel flange, and the surveillance, and penetration is NOT capable of being closed by at maintenance.

least one valve, a TCN with a contingency plan to achieve closure and meet 20 psi containment pressure is required PRIOR to authorizing work on the penetration.

4. Initiate action to restore closure capability.

5. Suspend activities that would risk required Decay Heat Removal Equipment.

6. Notify the Maintenance, Operations, Work Controls, and Plant Managers.

Risk Significant One Auxiliary 1. IF out-of-service time is to exceed 119 hours, 0 YELLOW Equipment Building Exhaust Fan THEN notify the Work Controls Manager and Plant Manager.

2. Assess the impact on the operating unit.

3. Assess the impact on the running RHR pump.

If RCS level lower than 3 feet below the vessel flange prior to fuel offload, control in accordance with 3/4-OP-041.9, until RCS level returns above 3 feet below the vessel flange. [Commitment Step 2.3.11

See Substep 5.l.l.19.c for requirements if RCS level lower than 3 feet below the vessel flange.

[Commitment Step 2.3.1] + Capability includes provisions for the unavailability of AC power and environmental conditions expected. W07fl. IT/rIimr/mr

ENCLOSIJRE 2 (Page 9 of 9) MINIM1JM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAJ) AN]) RCS TEMP LESS THAN 200 DEGREES WITHOUT RCS LOOPS AVAILABLE Support Required Equipment Equipment Contingency Action Color Code Risk One Diesel Driven 1. Verify the availability of a portable 0 YELLOW Significant Instrument Air Instrument Air Compressor. Equipment Compressor AND 2. Verify the availability of the Instrument Air d) t (Cont the Instrument Air Cross Tie. Cross Tie Lines 3. If out-of-service time is to exceed 548 hours, notify the Work Controls Manager and Plant Manager.

4. Assess the impact on the operating unit.

Vital DC Room 1. Monitor temperature in the Inverter and DC 1 WHITE HVAC two of

                           -            Equipment Rooms.                                0 - YELLOW three units        2. Install portable fans or verify availability of required              portable fans.

E16D 3. Assess the impact on the operating unit. El 6E El 6F Service Water 1. Assess the impact on the operating unit. Loss of 1 or Pumps One

                          -                                                             more WHITE Electric pump AND one Diesel driven pump W7fl. IT/r[c/mr/mr

ENCLOSURE 3 (Page 1 of 8) MINIMuM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AN]) REACTOR CAVITY FLOODED GREATER THAN 23 FEET ABOVE THE VESSEL FLANGE Required Function Equipment Contingency Action Color Code Decay Heat Two RHR Pumps 1. Take immediate action to repair the failed 1 YELLOW Removal pump. 0 - RED

2. Go to 3/4-ONOP-050, LOSS OF RHR, for loss of RHR.

3. Maintain Reactor Cavity level greater than 23 feet above the vessel flange.

4. Maintain RCS temperature as low a possible.

5. Suspend any activities that would risk the remaining RHR, ICW, or CCW Pumps; EDG; and 4KV Bus.

6. Upon loss of both pumps, initiate actions to establish Containment Closure except for the equipment hatch.

7. Verify that the equipment hatch can be closed within the time frame specified in Enclosure

13. Station the necessary personnel at the hatch_with_direct_communications_to_the_RO.

Two RHR Heat 1. Take action as described for RHR Pumps. 1 YELLOW Exchangers 0 RED Two CCW Pumps 1. Go to 3/4-ONOP-030, COMPONENT 1 -YELLOW COOLING WATER MALFUNCTION, for 0 RED loss of CCW.

2. Carry out other actions per RHR pumps above.

AIO-7.r\

ENCLOSURE 3 (Page 2 of 8) MINIMUM REQUiRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AN]) REACTOR CAVITY FLOODED GREATER THAN 23 FEET ABOVE THE VESSEL FLANGE Required Function Equipment Contingency Action Color Code Decay Heat Two CCW Heat 1. Go to 3/4-ONOP-030, COMPONENT 1 - ORANGE Removal Exchangers COOLING WATER MALFUNCTION, for - (Contd) loss of CCW.

2. Take action to restore the unavailable component to service.

3. Take other actions as described for RHR Pumps.

Two ICW Pumps 1. Go to 3/4-ONOP-O 19, INTAKE COOLING 1 - YELLOW WATER MALFUNCTION, for loss of ICW. -

2. Suspend activities that may risk the remaining ICW Pumps.

3. CCW cross-tie to the other unit may be appropriate.

4. Notify the Work Controls Manager, Operations Manager, Maintenance Manager, and_Plant_Manager.

Two ICW 1. Verify that at least two ICW pumps AND two 1 YELLOW Headers CCW heat exchangers are aligned to the 0 RED remaining ICW header.

2. Prior to removing an ICW header from service, verify that the basket strainer associated with the remaining header is clean.

3. Have a contingency plan, with responsible individuals designated, in place to restore the header to service.

W97:DJT/cls/mr/emc

ENCLOSURE 3 (Page 3 of 8) MINIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AND REACTOR CAVITY FLOODED GREATER THAN 23 FEET ABOVE THE VESSEL FLANGE Required Function Equipment Contingency Action Color Code Inventory Two Charging 1. Initiate action to repair the unavailable 1- YELLOW Control Pumps (one with charging pump. 0- ORANGE an available EDG 2. Notify the Operations, Work Controls, power source). Maintenance and Plant Managers.

3. Verify the availability of two HHSI Pumps with suction aligned to an RWST with at least 20,000 gallons of water AND an available flowpath to the RCS.

4. Do not reduce RCS inventory; if possible, take action to maximize RCS inventory.

5. Maintain RCS temperature as low as possible.

6. Suspend activities that would place any remaining charging pump and its power supply at risk.

Flowpath from the 1. Initiate action to repair the unavailable 0- ORANGE charging pump to components. 0 RED if no the RCS (Regen 2. Notify the Operations, Work Controls, HHSI flowpath Hx or RCP seals) Maintenance, and Plant Managers. and suction 3. Verify the availability of two HHSI Pumps capability from with suction aligned to an RWST with at least BAST or RWST 20,000 gallons of water AND an available flowpath_to_the_RCS. One of four 1. Initiate action to repair the unavailable 0 YELLOW Primary Water component. Pump 2. Notify Operations, Work Controls, Maintenance, and Plant Managers.

3. Verify capability to cross connect Primary Water from opposite unit.

4. Verify the availability of the charging pump suction_from the_RWST.

Two of four Boric 1. Initiate action to repair the unavailable 1-YELLOW Acid Pumps components. 0-ORANGE

2. Notify Operations, Work Controls, Maintenance, and Plant Managers.

3. Verify the availability of the charging pump suction from the RWST.

4. Verify the availability of two HHSI pumps with suction aligned to an RWST with at least 20,000 gallons of water AND an available flowpath to the RCS.

Wq7n.IT!/mr/mr

ENCLOSURE 3 (Page 4 of 8) MINIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AN]) REACTOR CAVITY FLOODED GREATER THAN 23 FEET ABOVE THE VESSEL FLANGE Required Function Equipment Contingency Action Color Code Inventory Two of four HHSI 1. Initiate action to restore the unavailable 1 YELLOW Control Pumps each with components. 0 ORANGE (Confd) an emergency 2. Verify the availability of at least two charging power supply and pumps. suction capability 3. Maximize RCS inventory. from an RWST 4. Maintain RCS temperature as low as possible. with at least 5. Notify the Operations, Work Controls, 20,000 gallons of Maintenance, and Plant Managers. water AND an available flowpath to the RCS. On-site and Two Transformers 1. Go to 3/4-ONOP-004, LOSS OF OFF-SITE 1 xfmr with Off-site capable of POWER, for loss of off-site power. SBO tie - Power powering A OR B YELLOW

2. Go to 3/4-ONOP-092.3, STARTUP 4KV Bus

TRANSFORMER MALFUISICTION, for S/U 1 xmr without

                  . Startup           transformer malfunction.                         SBO tie  -

AUX on 3. Initiate actions to return the required ORANGE backfeed transformer to service.

4. Verify the availability of both EDGs. 0 xfrm RED

Opposite unit startup 5. Verify the availability of the station blackout transformer to tie.

A Bus 6. Suspend activities that would risk the

One C Bus remaining power supplies.

transformer to 7. Verify the availability of one C Bus to power A OR B Bus A or B 4KV Bus

8. Notify the Operations, Work Controls, Maintenance,_and Plant_Managers.

Reference Step 5.1.1.29 W7fl. ITIrIcImrImr

ENCLOSURE 3 (Page 5 of 8) MP4]MUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AN]) REACTOR CAVITY FLOODED GREATER THAN 23 FEET ABOVE THE VESSEL FLANGE Required Function Equipment Contingency Action Color Code On-site and A, B D 1. Except during refueling outage, scheduled bus outages 2 YELLOW Off-site Power 4KV Busses (one bus at a time), take action to restore the (Contd) out-of-service components. Go to the appropriate Loss of D Bus procedure below: and A or B 3/4-ONOP-004.2, LOSS OF A 4KV BUS - ORANGE 3/4-ONOP-004.3, LOSS OF B 4KV BUS 3/4-ONOP-004.5, LOSS OF D 4KV BUS Loss of A and B

2. Verify at least two on-site sources of AC power are Busses RED -

available.

3. For loss of Off-site power go to 3/4-ONOP-004, LOSS OF OFF-SITE POWER.

4. With A, B, OR D 4KV Busses unavailable, verifS the ability to power A or B Bus from one C Bus transformer.

5. With D 4KV Bus unavailable, maintain both associated unit_EDGs_available.

Two Emergency 1. Take action to restore the unavailable EDG to service. 1 YELLOW Diesel Generators on 2. Suspend activities that may risk the Off-site power 0 ORANGE the Associated Unit sources.

3. Verify availability of the station blackout tie.

4. Verify the ability to power A OR B Bus from one C Bus transformer.

Station Blackout Tie 1. Verify availability of both associated unit EDGs. 0 w/ C bus tie

2. Suspend activities that may risk the Off-site power YELLOW supplies.

3. Verify the ability to power A B Bus from one C 0 w/o:

Bus transformer.

C Bus tie AND

                                                                                                    . Opposite unit SU Xfmr   -

ORANGE Wq7fl. IT! !mrhm,-

ENCLOSURE 3 (Page 6 of 8) MINIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AN]) REACTOR CAVITY FLOODED GREATER THAN 23 FEET ABOVE THE VESSEL FLANGE Required Function Equipment Contingency Action Color Code Reactivity CB > Required I. Take actions to increase boron concentration RED if Control Refueling CB (C

0 . < Required

2. Suspend core alterations if in progress until Refueling C CB > Required Refueling CB

3. Verify NO primary water additions to the refueling_cavity_in_progress.

Shutdown Two of four 1. Take action to restore the failed components. 1/4 - WHITE Monitoring Source Range 2. Suspend activities that could reduce the 0/4 -YELLOW Instrumentation Instruments available Shutdown Margin. Audible CR may 1 with Audible 3. Notify the Operations, Work Controls, be inoperable if Count Rate Maintenance and Plant Managers. no fuel movement in orogress ARMS Channels: L Take action to restore the failed components. Loss of 1 or Three Inside 2. Install temporary monitoring equipment in the more - WHITE Containment One affected area. Spent Fuel Pool # 3. Suspend activities that may increase radiation levels_in_the_affected_area. PR1VIS Channels: 1. Take action to secure releases via the Loss of 1 or R-l I, R-12, R-14 unmonitored pathway OR take action to more WHITE continue releases as al1Wed by Technical Specifications.

2. Consider installation of temporary monitoring equipment.

One Channel of 1. Take action to restore one channel to service 0 - WHITE Containment as soon as possible. Water Level Indication Two Channels of 1. Restore two channels to service as soon as 1 WHITE Containment possible. 0 YELLOW Sump Level 2. Suspend activities that may result in increased Indication sump level.

3. Verify that any temporary drain hoses are not resulting in loss of RCS inventory at least once_per_shift.

In containment, one at a time may be OOS for calibration.

WQ7fl. ITkIcImr/mr

ENCLOSURE 3 (Page 7 of 8) MINIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AND REACTOR CAVITY FLOODED GREATER ThAN 23 FEET ABOVE THE VESSEL FLANGE Function / Support Required Equipment Equipment Contingency Action Color Code Containment Equipment Hatch 1. Suspend activities that risk required Decay Required Time Closure (capable of being Heat Removal Equipment. Met - GREEN closed with four 2. Initiate action to restore the capability to close bolts in the hatch in the required time frame. accordance with 3. Notif, the Maintenance, Operations, Work Required Time Enclosure 13)* Controls, and Plant Managers. Not Met, Core Personnel Hatch 1. Suspend activities that risk required Decay

                                                                            .               Alts NOT in Pro    ess (capable of being      Heat Removal Equipment.                            (TCN Required) closed in           2. Initiate action to restore the capability to close - YELLOW accordance with        the hatch in the required time frame.

Enclosure 13)* 3. Notify the Maintenance, Operations, Work Controls, and Plant Managers. Required Time Containment 1. If an exception is taken, and at least one valve Not Met, During Penetrations (At in the penetration is capable of closure, either least one valve in manually from the Control Room or locally, each penetration the penetration shall be logged on Attachment that is NOT 3. The log entry shall identify the actions pressurized should necessary to close the penetration. be kept closed or 2. If an exception is taken, and the penetration is capable of being NOT capable of being closed by at least one closed in valve, a TCN with a contingency plan to accordance with achieve closure is required PRIOR to Enclosure 13) authorizing work on the penetration. Exceptions may 3. Initiate action to restore closure capability. be taken under 4. Suspend activities that would risk required administrative Decay Heat Removal Equipment. controls for 5. Notify the Maintenance, Operations, Work testing, Controls, and Plant Managers. surveillance, and maintenance. Risk One Auxiliary 1. IF out-of-service time is to exceed 119 hours, 0 YELLOW Significant Building Exhaust THEN notify the Work Controls Manager Equipment Fan and Plant Manager.

2. Assess the impact on the operating unit.

3. Assess the impact on the running RHR pump.

Capability includes provisions for the unavailability of AC power and environmental conditions expected. W07fl. TIr[ImrIpmr

ENCLOSURE 3 (Page 8 of 8) MINIMUM REQUIRED EQUIPMENT, PHASE I, LARGE DECAY HEAT LOAD AN]) REACTOR CAVITY FLOODED GREATER THAN 23 FEET ABOVE THE VESSEL FLANGE System / Support Required Color Code Equipment Equipment Contingency Action Risk Significant One Diesel Driven 1. Verify the availability of a portable Instrument Air 0 YELLOW Equipment Instrument Air Compressor. (Contd) Compressor the 2. Verit the availability of the Instrument Air Cross Tie. If out-of-service time is to exceed 548 hours, notify the Work Instrument Air Cross Controls Manager and Plant Manager. Tie Lines 4. Assess the impact on the operating unit. Vital DC Room HVAC - 1. Monitor temperature in the Inverter jj DC Equipment 1 WHITE two of three units Rooms. 0 YELLOW

2. Install portable fans or verify availability of portable fans.

required EI6D, EI6E, 3 Assess the impact on the operating unit. E16F Service Water Pumps - 1. Assess the impact on the operating unit. Loss of 1 or One Electric pump more WHITE one Diesel driven pump Spent Fuel SFP Cooling Pump 1. Take immediate action to repair the failed pump, or switch to 1- YELLOW Cooling (N/A if A and B the other pump. *0 ORANGE

2. Establish Emergency SFP Coolinn Pump operation per the reactor core 314-ONOP-033. 1, Spent Fuel Pit SFP) Cooling System is fully loaded) Malfunction.

3. Notify the Operations, Work Controls. Maintenance, and Plant Managers.

4. Monitor Spent Fuel Pool temperature and level frequently.

5. Suspend any activities that would risk remaining equipment required (ICW, CCW, Electrical, Makeup).

6. Go to 3/4-ONOP-033.l, SPENT FUEL PIT (SFP)

COOLING SYSTEM MALFUNCTION. Spent Fuel Pit Exhaust 1. Initiate action to restore exhaust fan to service. 0 - WHITE Fan 2. Notify the Operations, Work Controls, Maintenance, and Plant Managers.

3. Suspend any activities that would risk Spent Fuel Pool Cooling_capabilities.

C 480 Volt Load Center 1. Initiate action to restore power to C load center. De-energized -

2. Notify Operations, Maintenance, Work Controls, and Plant YELLOW*

Managers. De-energized

3. Verify the ability to power the Emergency SFP Cooling ORANGE**

Pump JAW 314-OP-033. Spent Fuel Pit Cooling System.

4. Monitor SFP temperature and level frequently.

5. Go to 3/4-ONOP-033.1, SPENT FUEL PIT (SFP)

COOLING SYSTEM MALFUNCTION. SFP Water 2 of following water 1. Initiate actions to restore SFP makeup source in accordance 1 YELLOW Makeup Sources sources: with 3/4-OP-033. 0 ORANGE (N/A if the - RWST and RWST 2. Consider Fire Protection System and dual hose station. purification pump 3 Notify Operations, Maintenance, Work Controls and Plant reactor core is - PWT and PW pump fully loaded) Managers.

                    - CVS Holdup Tank and Recirc Pump              4. Monitor SFP level and temperature frequently.

5. Suspend all activities that would risk spent fuel cooling capabilities.

With Alt SFP cooling system available.
- \Vith Alt SFP cooling system unavailable.

Wg7n.IT/rz/mr/pmr

ENCLOSURE 4 (Page 1 of 8) MINIMUM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AN]) REACTOR CAVITY FLOODED GREATER THAN 23 FEET ABOVE THE VESSEL FLANGE Required Function Equipment Contingency Action Color Code Decay Heat Two RHR Pumps 1. Take immediate action to repair the failed 1 YELLOW Removal pump. 0 RED

2. Go to 3/4-ONOP-050, LOSS OF RHR, for loss of RHR.

3. Maintain Reactor Cavity level greater than 23 feet above the vessel flange.

4. Maintain RCS temperature as low as possible.

5. Suspend any activities that would risk the remaining RHR, ICW, or CCW Pumps; EDG; and 4KV Bus.

6. Upon loss of both pumps, initiate actions to establish Containment Closure except for the equipment hatch.

7. Verify that the equipment hatch can be closed within the time frame specified in Enclosure

13. Station the necessary personnel at the hatch_with_direct_communications_to_the_RO.

Two RHR Heat 1. Take action as described for RHR Pumps. 1 YELLOW Exchangers 0 RED Two CCW Pumps 1. Go to 3/4-ONOP-030, COMPONENT 1 YELLOW COOLING WATER MALFUNCTION, for 0 RED loss of CCW.

2. Carry out other actions per RHR pumps above.

W97:DJT/cIs/mrkm

ENCLOSURE 4 (Page 2 of 8) MINIMUM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AND REACTOR CAVITY FLOODED GREATER THAN 23 FEET ABOVE THE VESSEL FLANGE Required Function Equipment Contingency Action Color Code Decay Heat Two CCW Heat 1. Go to 3/4-ONOP-030, COMPONENT 1 ORANGE Removal Exchangers COOLING WATER MALFUNCTION, for - RED (Contd) loss of CCW.

2. Take action to restore the unavailable component to service.

3. Take other actions as described for RHR Pumps.

4. With only one CCW Heat Exchanger available, suspend activities that would risk the_remaining_heat_exchanger.

Two ICW Pumps 1. Go to 3/4-ONOP-O 19, INTAKE COOLING 1 YELLOW WATER MALFUNCTION, for loss of ICW. -

2. Suspend activities that may risk the remaining ICW Pumps.

3. CCW cross-tie to the other unit may be appropriate.

4. Notify the Work Controls Manager, Operations Manager, Maintenance Manager, and_Plant_Manager.

One ICW Header 1. Verify that at least two ICW pumps AND two 0 RED - CCW heat exchangers are aligned to the remaining ICW header.

2. Prior to removing an ICW header from service, verify that the basket strainer associated with the remaining header is clean.

3. Have a contingency plan, with responsible individuals designated, in place to restore the header to service.

A,O-7.r ITIII,-..

ENCLOSURE 4 (Page 3 of 8) MINIMUM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAI) AN]) REACTOR CAVITY FLOODED GREATER THAN 23 FEET ABOVE THE VESSEL FLANGE Required Function Equipment Contingency Action Color Code Inventory One Charging 1. Initiate action to repair the unavailable 0- ORANGE Control Pump (one with charging pump. an available EDG 2. Notify the Operations, Work Controls, power source) Maintenance and Plant Managers.

3. Verify the availability of one HHSI Pump with suction aligned to an RWST with at least 20,000 gallons of water AND an available flowpath to the RCS.

4. Do not reduce RCS inventory; if possible, take action to maximize RCS inventory.

5. Maintain RCS temperature as low as possible.

Flowpath from the 1. Initiate action to repair the unavailable 0 ORANGE charging pump to components. 0 RED if no the RCS (Regen 2. Notify the Operations, Work Controls, HHSI flowpath Hx or RCP seals) Maintenance, and Plant Managers. and suction 3. Verify the availability of one HHSI Pump capability from with suction aligned to an RWST with at least the BAST or 20,000 gallons of water AND an available RWST flowpath_to_the_RCS. One of four 1. Initiate action to repair the unavailable 0 YELLOW Primary Water component. Pumps 2. Notify Operations, Work Controls, Maintenance, and Plant Managers.

3. Verify capability to cross connect Primary Water from opposite unit.

4. Verify the availability of the charging pump suction_from the_RWST.

One of four Boric 1. Initiate action to repair the unavailable 0- ORANGE Acid Pumps components.

2. Notify Operations, Work Controls, Maintenance, and Plant Managers.

3. Verify the availability of the charging pump suction from the RWST.

4. Verify the availability of one HHSI pump with suction aligned to an RWST with at least 20,000 gallons of water AND an available flowpath to the RCS.

A,n-7.r Ir,..I-,.-.,.-,,..-.,.

ENCLOSURE 4 (Page 4 of 8) MINIMUM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AND REACTOR CAVITY FLOODED GREATER THAN 23 FEET ABOVE THE VESSEL FLANGE Required Function Equipment Contingency Action Color Code Inventory One of four HHSI 1. Initiate action to restore the unavailable 0 YELLOW Control Pumps each with components. (Contd) an emergency 2. Verify the availability of at least one charging power supply and pump. suction capability 3. Maximize RCS inventory. from an RWST 4. Maintain RCS temperature as low as possible. with at least 20,000 5. Notify the Operations, Work Controls, gallons of water Maintenance, and Plant Managers. AND an available flowpath to the RCS. On-site and Two of the below 1. Go to 3/4-ONOP-004, LOSS OF OFF-SITE 1 xfmr with Off-site listed Transformers POWER, for loss of off-site power. SBO tie - Power capable of 2. Go to 3/4-ONOP-092.3, STARTUP YELLOW powering the A TRANSFORMER MALFUNCTION, for S/U 1 xtmr without OR B 4KV Bus

transformer malfunction. SBO tie -

                . Startup            3. Initiate actions to return the required          ORANGE
                . AUX on                transformer to service.

backfeed 4. Verify the availability of both EDGs. 0 xfrm RED

                . Opposite unit      5. Verify the availability of the station blackout startup              tie.

transformer to A 6. Suspend activities that would risk the Bus remaining power supplies.

One C Bus 7. Verify the availability of one C Bus to power transformer to A A OR B 4KV Bus.

OR B Bus 8. Notify the Operations, Work Controls, Maintenance,_and_Plant_Managers. Reference Step 5.1.1.29 W07fl IT/rc/mr/m

ENCLOSURE 4 (Page 5 of 8) MINIMUM REQUIRED EQuIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AND REACTOR CAVITY FLOODED GREATER TITAN 23 FEET ABOVE THE VESSEL FLANGE Required Function Equipment Contingency Action Color Code On-site and A, B AND D 4KV 1. Except during refueling outage, scheduled bus 2 YELLOW Off-site Busses outages (one bus at a time), take action to Power restore the out-of-service components. Go to Loss of D Bus appropriate procedure below: and A or B (Contd 0 Busses 3/4-ONOP-O04.2, LOSS OF A 4KV BUS 3/4-ONOP-004.3, LOSS OF B 4KV BUS - 3/4-ONOP-004.5, LOSS OF D 4KV BUS Loss of A and B

2. Verify at least two on-site sources of AC power Busses are available. - RED

3. For loss of Off-site power go to 3/4-ONOP-004, LOSS OF OFF-SITE POWER.

4. With A, B, OR D 4KV Busses unavailable, verify the a1Ty to power A or B Bus from one C Bus transformer.

5. With D 4KV Bus unavailable, maintain both associated_unit_EDGs_available.

One Emergency 1. Take action to restore the unavailable EDG to 0 ORANGE Diesel Generator service. on the Associated 2. Suspend activities that may risk the Off-site Unit power sources.

3. Verify availability of the station blackout tie.

4. Verity the ability to power A B Bus from one_C_Bus_transformer.

Station Blackout 1. Verify availability of both associated unit 0w/C bus tie Tie EDGs. YELLOW

2. Suspend activities that may risk the Off-site power supplies. 0 w/o:

3. Verify the ability to power A fj3 B Bus from C Bus tie one C Bus transformer.

Opposite unit SUXfmr ORANGE W97fiIT/nIs/mr/em

ENCLOSURE 4 (Page 6 of 8) MINIMUM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AND REACTOR CAVITY FLOODED GREATER THAN 23 FEET ABOVE TIlE VESSEL FLANGE Required Function Equipment Contingency Action Color Code Reactivity CB Required

                     >               1. Take action to increase boron concentration (CB) RED if CB Control          Refueling CB          to > Required Refueling CB.                        < Required

2. Suspend core alterations until CB > Required Refueling CB Refueling CB.

3. Verify NO primary water additions to the refueling_cavity_in_progress.

Shutdown Two of four 1. Take action to restore the failed components. 1/4 - WHITE Monitoring Source Range 2. Suspend activities that could reduce the available 0/4 YELLOW Instrumentat Instruments . Shutdown Margin. Audible CR may be inoperable if ion 1 w/ Audible 3. Notify the Operations, Work Controls, no fuel Count Rate Maintenance, and Plant Managers. movement. ARMS Channels: 1. Take action to restore the failed components. Loss of 1 or Three Inside 2. Install temporary monitoring equipment in the more - WHITE Containment One affected area. Spent Fuel Pool # 3. Suspend activities that may increase radiation levels in the affected area. PRMS Channels: 1. Take action to secure releases via the Loss of 1 or R-11, R-12, R-14 unmonitored pathway fj3, take action to continue more WHITE-releases as allowed by Technical Specifications.

2. Consider installation of temporary monitoring equipment.

One Channel of 1. Take action to restore one channel to service as 0 WHITE Containment soon as possible. Water Level Indication Two Channels of 1. Restore two channels to service as soon as 1 WHITE Containment possible. 0 - Sump Level 2. Suspend activities that may result in increased Indication sump level.

3. Verify that any temporary drain hoses are not resulting in loss of RCS inventory at least once per_shift.

In containment, one at a time may be OOS for calibration.

W97:DJT/cls/mr/emc

ENCLOSURE 4 (Page 7 of 8) MINIMUM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AN]) REACTOR CAVITY FLOODED GREATER THAN 23 FEET ABOVE THE VESSEL FLANGE Function / Support Required Equipment Equipment Contingency Action Color Code Containment Equipment Hatch 1. Suspend activities that risk required Decay Heat Required Time Closure (capable of being Removal Equipment. Met GREEN closed with four 2. Initiate action to restore the capability to close bolts in accordance the hatch in the required time frame. Required Time with Enclosure 13) 3. Notify the Maintenance, Operations, Work Not Met, Core

Controls, and Plant Managers. Alts NOT in Personnel Hatch 1. Suspend activities that risk required Decay Heat Progress (TCN (capable of being Removal Equipment.

closed in 2. Initiate action to restore the capability to close accordance with the hatch in the required time frame. Enclosure 13)

3. Notify the Maintenance, Operations, Work Required Time Controls, and Plant Managers. Not Met, During Containment 1. If an exception is taken, and at least one valve in Penetrations (At the penetration is capable of closure, either least one valve in manually from the Control Room or locally, the each penetration penetration shall be logged on Attachment 3.

that is NOT The log entry shall identify the actions necessary pressurized should to close the penetration. be kept closed or 2. If an exception is taken, and the penetration is capable of being NOT capable of being closed by at least one closed in valve, a TCN with a contingency plan to achieve accordance with closure is required PRIOR to authorizing work Enclosure 13.) on the penetration. Exceptions may be 3. Initiate action to restore closure capability. taken under 4. Suspend activities that would risk required administrative Decay Heat Removal Equipment. controls for testing, 5. Notify the Maintenance, Operations, Work surveillance, and Controls, and Plant Managers. maintenance. Risk One Auxiliary 1. IF out-of-service time is to exceed 119 hours, 0 YELLOW Significant Building Exhaust THEN notify the Work Controls Manager and Equipment Fan Plant Manager.

2. Assess the impact on the operating unit.

3. Assess the impact on the running RHR pump.

Capability includes provisions for unavailability of AC power and environmental conditions expected. W97:DJT/cls/mr/emc

ENCLOSURE 4 (Page 8 of 8) MINIMUM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AN]) REACTOR CAVITY FLOODED GREATER THAN 23 FEET ABOVE THE VESSEL FLANGE System / Support Required Equipment Equipment Contingency Action Color Code Risk Significant One Diesel Driven I. Verify the availability of a portable Instrument Air Compressor. 0 YELLOW Equipment Instrument Air Compressor 2. Verify the availability of the Instrument Air Cross Tie. (Contd) AND the Instrument Air 3. IF out-of-service time is to exceed 548 hours, notify the Work Cross Tie Lines Controls Manager and Plant Manager.

4. Assess the impact on the operating unit.

Vital DC Room HVAC - 1. Monitor temperature in the Inverter and DC Equipment Rooms. 1 WHITE Two of three units required 2. Install portable fans or verify availability of portable fans. 0 YELLOW E16D 3. Assess the impact on the operating unit. E16E E16F Service Water Pumps One

                                                          -     1. Assess the impact on the operating unit.                                  Loss of 1 or Electric pump        one                                                                                  more WHITE Diesel driven pump Spent Fuel                        SFP Cooling Pump A          I. Take immediate action to repair the failed pump or switch to other         1 YELLOW Cooling (N/A if                   and B                           pump.                                                                      0 ORANGE

2. Establish Emergency SFP Cooling Pump operation per e reactor core is 3/4-O-NOP-033.l, Spent Fuel Pit (5FP) Cooling System Malfunction.

fully loaded)

3. Notify the Operations. Work Controls, Maintenance, and Plant Managers.

4. Monitor Spent Fuel Pool temperature and level frequently.

5. Suspend any activities that would risk remaining equipment required 6.

( ICW, CCW, Electrical, Makeup). Go to 3/4-ONOP-033.l, SPENT FUEL PIT (SFP) COOLING SYSTEM MALFUNCTION. Spent Fuel Pit Exhaust Fan 1. Initiate action to restore exhaust fan to service. 0 WHITE

2. Notify the Operations, Work Controls, Maintenance, and Plant Managers.

3. Suspend any activities that would risk Spent Fuel Pool Cooling capabilities.

C 480 Volt Load Center 1. Initiate action to restore power to C load center, Dc-energized -

2. Notify Operations, Maintenance, Work Controls, and Plant Managers. YELLOW *

3. Verify the ability to power the Emergency SFP Cooling Pump lAW De-energized 314-OP-033, Spent Fuel Pit Cooling System. ORANGE**

       ,                                                        4. Monitor SFP temperature and level frequently.

5. Go to 3/4-ONOP-033.l, SPENT FUEL PIT (SFP) COOLING SYSTEM MALFUNCTION.

SFP Water 2 of following water 1. Initiate actions to restore SEP makeup source in accordance with 1 or less Makeup Sources sources: 3/4OP-033. YELLOW

                                    -  RWST and RWST            2. Consider Fire Protection System and dual hose station.

(N/A if the reactor purification pump core is fu 11 y 3. Notify Operations, Maintenance, Work Controls and Plant Managers.

                                    -  PWT and PW pump loaded)                                                           Monitor SFP level and temperature frequently.
                                    -  CVS Holdup Tank and Recirc Pump              5. Suspend all activities that would risk spent fuel cooling capabilities.

With Alt SFP cooling system available. With Alt SFP cooling system unavailable. A?CV?.fl Imi,-.I...,......I,-,.,,,,,

Procedure No.: Procedure

Title:

Page: 81 Approval Date: 0-ADM-051 Outage Risk Assessment and Control 7/22/11 ENCLOSURE 5 (Page 1 of 9) MINIMUM REQU1RED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AND RCS TEMP LESS THAN 200 DEGREES WITHOUT RCS LOOPS AVAILABLE Required Function Equipment Contingency Action Color Code Decay Heat Two RHR 1. Take immediate action to repair the failed 1- ORANGE Removal Pumps pump. 0- RED

2. Go to 3/4-ONOP-050, LOSS OF RHR, for loss of RHR.

3. Establish or maintain Reactor Vessel level higher than three feet below the vessel flange. Maximize RCS inventory as much as is achievable.

4. Maintain RCS temperature as low as possible.

5. Ensure Feed and Bleed decay heat removal capability, using the fIRST pumps, is available.

6. Suspend any activities that would risk the remaining RHR, ICW, or CCW Pumps; EDG; AND 4KV Bus.

7. Upon loss of both pumps, initiate actions to establish Containment Closure, except for the equipment hatch.

8. Verify that the equipment hatch can be closed within the time frame to heat up to Mode 4 following a loss of shutdown cooling as predicted using the time to saturation of Figure 2. Station the necessary personnel at the hatch with direct communications to the RO.

9. Investigate the possibility of flooding the Reactor Cavity to a height of 23 feet above the Reactor Vessel Flange.

1O.IfRCS inventory is at Mid-Loop, then refer to Figure 5, Time to Core Uncovery from Mid-Loop. Two RHR Heat 1. Take action as described for RHR Pumps. I ORANGE Exchangers - ORED Two CCW 1. Go to 3/4-ONOP-030, COMPONENI 1 -ORANGE Pumps* COOLING WATER MALFUNCTION, for 0- RED loss of CCW.

2. Carry out other actions as described per RHR oumos above.

Powered from independent power sources if RCS level lower than 3 feet below the vessel flange.

[Commitment Step 2.3.1] W97:DJT/cls/mr/emc

ENCLOSURE 5 (Page 2 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AN]) RCS TEMP LESS THAN 200 DEGREES WITHOUT RCS LOOPS AVAILABLE Required Function Equipment Contingency Action Color Code Decay Heat Two CCW Heat 1. Go to 3/4-ONOP-030, COMPONENT 1 ORANGE Removal Exchangers COOLING WATER MALFUNCTION, for - RED (Contd) loss of CCW.

2. Take action to restore the unavailable component to service.

3. With only one CCW heat exchanger available, suspend operations that would risk the remaining heat exchanger.

4. Take other actions as described for RHR Pumps.

Two ICW 1. Go to 3/4-ONOP-019, iNTAKE COOLING 1 -ORANGE Pumps* WATER MALFUNCTION, for loss of ICW. 0 RED

2. Suspend activities that may risk the remaining ICW Pumps.

3. CCW cross-tie to the other unit may be appropriate.

4. Notify the Work Controls Manager, Operations Manager, Maintenance Manager, and Plant Manager.

Two ICW 1. Verify that at least two ICW pumps AND two 1 YELLOW Headers CCW heat exchangers are aligned to the 0 RED remaining ICW header.

2. Prior to removing an ICW header from service, verify that the basket strainer associated with the remaining header is clean.

3. Have a contingency plan, with responsible individuals designated, in place to restore the header_to_service.

Powered from independent power sources if RCS level lower than 3 feet below the vessel flange. [Commitment Step 2.3.1] W97:DJT/cls/mr/emc

ENCLOSURE 5 (Page 3 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD ANI) RCS TEMP LESS THAN 200 DEGREES WITHOUT RCS LOOPS AVAILABLE Required Function Equipment Contingency Action Color Code Inventory Iwo Charging 1. Initiate action to repair the unavailable charging 1 -ORANGE Control Pumps (One with pump. 0- RED an available EDG 2. Notify the Operations, Work Controls, power source. Maintenance and Plant Managers. Both with an 3. Verify the availability of two HHSI Pumps with available EDG to suction aligned to an RWST with at least meet the 20,000 gallons of water AND an available requirement flowpath to the RCS. below #) 4. Do not reduce RCS inventory; if possible, take action to maximize RCS inventory.

5. Maintain RCS temperature as low as possible.

6. Suspend activities that would place any remaining charging pump and its power supply at risk.

Flowpath from the 1. Initiate action to repair the unavailable 0 ORANGE charging pump to components. 0 RED if no the RCS (Regen 2. Notify the Operations, Work Controls, HHSI Flowrath Hx or RCP seals) Maintenance, and Plant Managers. and suction 3. Verify the availability of two HHSI Pumps with capability from suction aligned to an RWST with at least the BAST or 20,000 gallons of water AND available RWST flowpath to the RCS. One of four 1. Initiate action to repair the unavailable 0 YELLOW Primary Water components. Pumps 2. Notify Operations, Work Controls, Maintenance, and Plant Managers.

3. Verify capability to cross connect Primary Water from the opposite unit.

4. Verify the availability of the charging pump suction_from_the_RWST.

Two of four Boric 1. Initiate action to repair the unavailable 1-YELLOW Acid Pumps components. 0- ORANGE

2. Notify Operations, Work Controls, Maintenance, and Plant Managers.

3. Verify the availability of the charging pump suction from the RWST.

4. Verify the availability of two HHSI pumps with suction aligned to an RWST with at least 20,000 gallons of water AND an available flowpath to the RCS.

Two charging pumps required with available EDG power source if RCS level is lower than 3 feet below the vessel flange.

[Commitment Step 2.3.1] AIcl7fl ITfrIImrIrrn

ENCLOSURE 5 (Page 4 of 9) MLNIMIJM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AN]) RCS TEMP LESS THAN 200 DEGREES WITHOUT RCS LOOPS AVAILABLE Required Function Equipment Contingency Action Color Code Inventory Two of four HHSI 1. Initiate action to restore the unavailable components. 1 YELLOW Control Pumps each with an 2. Verify the availability of at least two charging pumps. 0 ORANGE (Contd) emergency power 3. Maximize RCS inventory. supply and suction 4. Maintain RCS temperature as low as possible. capability from an 5. Notify the Operations, Work Controls, Maintenance, and RWST with at least Plant Managers. 20,000 gallons of water AND an available flowpath to the RCS.* RCS Inventory at or N/A YELLOW above 5% in drained to

                          .                                                                                     higherthan3 pressurizer. (Color below flange Code Determination Only)                                                                                         ORANGE Drained to hot leg mid nozzle On-site and      Two of the below listed    1. Go to 3/4-ONOP-004, LOSS OF OFF-SITE POWER, for 1 trf Off-site         Transformers capable           loss of off-site power.                                       ORANGE Power            of powering A        B    2. Go  to 3/4-ONOP-092.3,     STARTUP TRANSFORMER                0 RED 4KV Bus                        MALFUNCTION, for S/U transformer malfunction.
                  . Startup               3. Initiate actions to return the required transformer to
                  . AUX on backfeed            service.
                  . Opposite unit         4. Verify the availability of both EDGs.

startup transformer 5. Verify the availability of the station blackout tie. to A Bus 6. Suspend activities that would risk the remaining power

                  . Either units C Bus        supplies.

transformer to A or 7. Verify the availability of one C Bus to power A B B Bus 4KV Bus.

8. Notify the Operations, Work Controls, Maintenance, and Plant_Managers.

Both hot and cold leg injection paths are required if RCS level is lower than 3 feet below the vessel flange. [Commitment Step 2.3.1] W97:DJT/cls/mr/emc

ENCLOSURE 5 (Page 5 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AN]) RCS TEMP LESS THAN 200 DEGREES WITHOUT RCS LOOPS AVAILABLE Required Function Equipment Contingency Action Color Code On-site and A, B AND D 1. Take action to restore the out-of-service Loss of D Bus - Off-site 4KV Busses components. Go to appropriate procedure below: YELLOW Power 3/4-ONOP-004.2, LOSS OF A 4KV BUS (Contd) 3/4-ONOP-004.3, LOSS OF B 4KV BUS oss of A or B 3/4-ONOP-004.5, LOSS OF D 4KV BUS - ORANGE

2. Verify at least two on-site sources of AC power are available. I - RED

3. For loss of Off-site power go to 3/4-ONOP-004, LOSS OF OFF-SITE POWER.

4. With A, B OR D 4KV Busses unavailable, verify the ability to power A B Bus from one C Bus transformer.

5. With D 4KV Bus unavailable, maintain both associated_unit_EDGs_available.

One Emergency 1. Take action to restore the unavailable EDG to 0 ORANGE Diesel Generator service. on the Associated 2. Suspend activities that may risk the Off-site Unit* power sources.

3. Verify availability of the station blackout tie.

4. Verify the ability to power A B from one C Bus_transformer.

Station Blackout 1. Verify availability of both associated unit EDGs. 0 wI C bus tie Tie 2. Suspend activities that may risk the Off-site YELLOW power supplies. 0 wIo

                              . 3. Verify the ability to power A Qj B from one C          . c us tie Bus transformer.

AND Opposite unit SU Xfmr - ORANGE Two EDGs required if RCS level lower than 3 feet below the vessel flange. [Commitment Step 2.3.1] W97:DJT/cls/mr/emc

ENCLOSURE 5 (Page 6 of 9) MIMMUM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AN]) RCS TEMP LESS THAN 200 DEGREES WITHOUT RCS LOOPS AVAILABLE Required Function Equipment Contingency Action Color Code Reactivity CB > 0-OP-028.2 1. Take action to restore boron concentration (CB) RED if CB< Control SDM Calculation to> 0-OP-028.2 SDM Calculation, or the required

                                         > Required Refueling C  5 as applicable.              conc for Mode 5, or
                   > Required         2. Verif NO primary water additions in progress.

Refueling CB for Mode 6 Shutdown Two of Four Source 1. Take action to restore the failed components. 1/4 WHITE Monitoring Range Instruments 2. Suspend activities that could reduce the available 0/4 YELLOW Instrumentation (1 w/ Audible Shutdown Margin. Count Rate in Mode 3. Notif, the Operations, Work Controls,

6) Maintenance, and Plant Managers.

ARMS Channels: 1. Take action to restore the failed components. Loss of I or Three Inside 2. Install temporary monitoring equipment in the more WHITE Containment One affected area. Spent Fuel Pool # 3. Suspend activities that may increase radiation levels in the affected area. PRMS Channels: 1. Take action to secure releases via the Loss of 1 or R-l 1, R-12, R-14 unmonitored pathway OR take action to more WHITE continue releases as allowed by Technical Specifications.

2. Consider installation of temporary monitoring equipment.

2 Core Exit 1. Arrange with I&C for alternate readouts or 0 YELLOW Thermocouples monitoring of CETs if possible. (Required when 2. Verif that two channels of wide range TH0T are the reactor vessel available. head is fully 3. Maintain RCS greater than 10 percent Wide tensioned.)* Range Pressurizer Level. One Channel of 1. Take action to restore at least one channel as 0 WHITE Reactor Vessel soon as possible. Level HJTC 2. Maximize RCS inventory as much as is allowed (QSPDS) by plant conditions. (Required when 3. Maintain RCS greater than 10 percent Wide the reactor vessel Range Pressurizer Level. head is fully 4. If OOS as part of reactor disassembly, verif, two tensioned.) channels of the reactor vessel draindown level indication available, one with control room readout. IF <2 channels available, maintain RCS level higher than 3 feet below the vessel flange. I A minimum of two (2) CETs are required whenever RCS level is lower than 3 feet below the vessel flange. [Commitment Step 2.3.1]

One at a time may be OOS for calibration.

Wg7: D.JT/cis/mr/mr

ENCLOSURE 5 (Page 7 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AN]) RCS TEMP LESS THAN 200 DEGREES WITHOUT RCS LOOPS AVAILABLE Required Function Equipment Contingency Action Color Code Shutdown One Channel of 1. Take action to restore one channel to service as 0 WHITE Monitoring Containment soon as possible. Instrumentati Water Level on (Contd) Indication Two Channels of 1. Restore two channels to service as soon as 1 WHITE Containment possible. 0 - YELLOW Sump Level 2. Suspend activities that may result in increased Indication sump level.

3. Verify that any temporary drain hoses are not resulting in loss of RCS inventory at least once per_shift.

One Pressurizer 1. Suspend activities which may result in RCS 0 - WHITE Cold Calibrated inventory loss. Level Indication 2. Monitor temporary drain hoses for loss of RCS inventory at least once per shift.

3. Consider installation of a temporary level hose as_appropriate_for_plant_conditions.

RCS Pressure 1. Verify sufficient OMS trains are still available. 0 WHITE Instruments 2. Notify the Operations, Work Controls, PT-402, Maintenance, and Plant Managers. PT-403, and PT-405 RCS Wide Range 1. Verify the availability of two CETs. None WHITE THOT and TC0LD: 2. Verify that OMS controls are not affected by At least one the unavailable channel. channel per ioop Reactor Vessel 1. Maintain RCS level higher than 3 feet below 1 available Draindown Level the vessel flange. YELLOW Indication: Two of 2. Do not reduce RCS inventory until two 0 ORANGE three channels channels are available, requires available, 3. Investigate the possibility of verifying Reactor Control Room (includes level Vessel Level via some other means, (i.e., level Indication hose) one with hose or QSPDS). Control Room indication*# The level hose AND both draindown level indicators are required for RCS level lower than 3 feet below the vessel flange. [Commitment Step 2.3.1] IF RCS level is on scale in reactor vessel draindown instruments, THEN pressurizer cold calibrated level instrument is not required.

IF pressurizer cold calibrated level indication is greater than 10%, THEN reactor vessel draindown level indication is not required.

W97:DJT/cls/mr/emc

ENCLOSURE 5 (Page 8 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AND RCS TEMP LESS THAN 200 DEGREES WITHOUT RCS LOOPS AVAILABLE Function / Support Required Equipment Equipment Contingency Action Color Code Containment Equipment Hatch 1. Suspend activities that risk required Decay Heat Required Time closure (capable of being Removal Equipment. Met GREEN closed with four bolts 2. Initiate action to restore the capability to close the in accordance with hatch in the required time frame. Enclosure 13)* + 3. Notify the Maintenance, Operations, Work Controls, Required Time and Plant Managers. Not Met (TCN Personnel Hatch 1. Suspend activities that risk required Decay Heat Required) - (capable of being Removal Equipment. YELLOW closed in accordance 2. Initiate action to restore the capability to close the with Enclosure 13)* + hatch in the required time frame.

3. Notify the Maintenance, Operations, Work Controls, Required Time and Plant Managers. Not Met Containment 1. If an exception is taken, and at least one valve in the During Penetrations (At least penetration is capable of closure, either manually from Reduced one valve in each the Control Room or locally, the penetration shall be Inventory -

penetration that is logged on Attachment 3. The log entry shall identify ORANGE NOT pressurized the actions necessary to close the penetration. should be kept closed 2. If an exception is taken, and the penetration is NOT or capable of being capable of being closed by at least one valve, a TCN closed in accordance with a contingency plan to achieve closure is required with Enclosure 13) # PRIOR to authorizing work on the penetration. Exceptions may be 3. If an exception is taken while RCS level is lower than taken under 3 below the vessel flange, and the penetration is NOT administrative capable of being closed by at least one valve, a TCN controls for testing, with a contingency plan to achieve closure and meet surveillance, and 20 psi containment pressure is required PRIOR to maintenance, authorizing work on the penetration.

4. Initiate action to restore closure capability.

5. Suspend activities that would risk required Decay Heat Removal Equipment.

6. Notify the Maintenance, Operations, Work Controls, and Plant Managers.

Risk One Auxiliary 1. IF out-of-service time is to exceed 119 hours, THEN 0 YELLOW Significant Building Exhaust Fan notify the Work Controls Manager and Plant Manager. Equipment 2. Assess the impact on the operating unit.

3. Assess the impact on the running RHR pump.

If RCS level lower than 3 feet below the vessel flange prior to fuel offload, control in accordance with 3/4-OP-041.9, until RCS level returns above 3 feet below the vessel flange.

[Commitment Step 2.3.1]

See Substep 5.1.l.22.c for requirements if RCS level lower than 3 feet below the vessel flange.

[Commitment Step 2.3.1] + Capability includes provisions for unavailability of AC power and environmental conditions expected. W97:DJT/c]s/mr/emc

Procedure No.: Procedure

Title:

Page: 89 Approval Date: O-ADM-051 Outage Risk Assessment and Control 7/22/11 ENCLOSURE 5 (Page 9 of 9) MINIMUM REQUIRED EQUWMENT, PHASE II, REDUCED DECAY HEAT LOAD AND RCS TEMP LESS THAN 200 DEGREES WITHOUT RCS LOOPS AVAILABLE Support Required Equipment Equipment Contingency Action Color Code Risk One Diesel Driven 1. Verify the availability of a portable Instrument 0YELLOW Significant Instrument Air Air Compressor. Equipment Compressors and 2. Verify the availability of the Instrument Air (Contd) the Instrument Air Cross Tie. Cross Tie Lines 3. If out-of-service time is to exceed 548 hours, notify the Work Controls Manager and Plant Manager.

4. Assess the impact on the operating unit.

Vital DC Room 1. Monitor temperature in the Inverter and DC 1 WHITE HVAC Two of

                               -                    Equipment Rooms.                                       0 YELLOW three units                2. Install portable fans or verify availability of required                      portable fans.

E16D 3. Assess the impact on the operating unit. El 6E El 6F Service Water 1. Assess the impact on the operating unit. Loss of I or Pumps One- more WHITE Electric pump AND one Diesel driven pump W07fl. IT/c /mr/cmr

ENCLOSURE 6 (Page 1 of 9) MIMMUM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AN]) RCS TEMP LESS THAN 200 DEGREES WITH RCS LOOPS FILLED Required Function Equipment Contingency Action Color Code Decay Heat Two RHR Pumps 1. Take immediate action to repair the failed 1 YELLOW Removal pump. 0 RED

2. Go to 3/4-ONOP-050, LOSS OF RHR, for loss of RHR.

3. Maximize RCS inventory as much as is achievable.

4. Maintain RCS pressurized to 100 psig to meet loops filled criteria.

5. Maintain RCS temperature as low as possible.

6. Ensure Feed and Bleed decay heat removal capability, using the RHSI pumps, is available.

7. Maintain Decay Heat Removal capability with at least two Steam Generators, including a source of feedwater.

8. Suspend any activities that would risk the remaining RHR, ICW, or CCW Pumps; EDG; AN]) 4KV Bus.

9. Upon loss of both pumps, initiate actions to establish Containment Closure except for the equipment hatch.

10. Verify that the equipment hatch can be closed within the time frame to heat up to Mode 4 following a loss of shutdown cooling as predicted using the heatup rates of Figure 1.

Station the necessary personnel at the hatch with_direct_communications_to_the_RO. Two RHR Heat 1. Take action as described for RHR Pumps. 1 ORANGE Exchangers 0 RED Two CCW Pumps 1. Go to 3/4-ONOP-030, COMPONENT 1 -ORANGE COOLiNG WATER MALFUNCTION, for 0 RED loss of CCW.

2. Carry out other actions as described per RHR pumps above.

Wq7fl. ITIrImrIimn

ENCLOSURE 6 (Page 2 of 9) M1]NIMIJM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AND RCS TEMP LESS THAN 200 DEGREES WITH RCS LOOPS FILLED Required Function Equipment Contingency Action Color Code Decay Heat Two CCW Heat 1. Go to 3/4-ONOP-030, COMPONENt 1 -ORANGE Removal Exchangers COOLiNG WATER MALFUNCTION, for 0- RED (Contd) loss of CCW.

2. Take action to restore the unavailable component to service.

3. Take other actions as described for RHR Pumps.

Two ICW Pumps 1. Go to 3/4-ONOP-O 19, iNTAKE COOLING 1 ORANGE WATER MALFUNCTION, for loss of ICW. 0 RED

2. Suspend activities that may risk the remaining ICW Pumps.

3. CCW cross-tie to the other unit may be appropriate.

4. Notify the Work Controls Manager, Operations Manager, Maintenance Manager, and Plant Manager.

Two ICW 1. Verify at least two ICW pumps AND two 1 YELLOW Headers CCW heat exchangers are aligned to the 0 RED remaining ICW header.

2. Prior to removing an ICW header from service, verify that the basket strainer associated with the remaining header is clean.

3. Have a contingency plan, with responsible individuals designated, in place to restore the header_to_service.

Source of 1. Take action to restore the unavailable 0 YELLOW feedwater and a component. flowpath from one 2. Restrict Activities that could potentially of the following: threaten RHR SGFP SSGFP Condensate PP Condensate Transfer PP SGWL PP 2 Steam Dump to 1. lake action to restore the unavailable 0 YELLOW Atmosphere component. Valves 2. Restrict Activities that could potentially threaten RHR Wq7fl. ITirIR/mr/Pmr

ENCLOSURE 6 (Page 3 of 9) MiNIMUM REQUIRED EQUiPMENT, PHASE II, REDUCED DECAY HEAT LOAD AND RCS TEMP LESS THAN 200 DEGREES WITH RCS LOOPS FILLED Required Function Equipment Contingency Action Color Code Inventory Two Charging 1. Initiate action to repair the unavailable 1 -YELLOW Control Pumps (one with charging pump. 0- ORANGE an available EDG 2. Notify the Operations, Work Controls, power source) Maintenance and Plant Managers.

3. Verify the availability of two HHSI Pumps with suction aligned to an RWST with at least 20,000 gallons of water AND an available flowpath to the RCS.

4. Do not reduce RCS inventory; if possible, take action to maximize RCS inventory.

5. Maintain RCS temperature as low as possible.

6. Suspend activities that would place any remaining charging pump and its power suoolv at risk.

Flowpath from the 1. Initiate action to repair the unavailable 0 ORANGE charging pump to components. the RCS (Regen 2. Notify the Operations, Work Controls, Hx or RCP seals) Maintenance, and Plant Managers. and suction 3. Verify the availability of two HHSI Pumps capability from with suction aligned to an RWST with at least BAST or RWST 20,000 gallons of water AND an available flowpath to_the_RCS. One of four 1. Initiate action to repair the unavailable 0 YELLOW Primary Water components. Pumps 2. Notify Operations, Work Controls, Maintenance, and Plant Managers.

3. Verify capability to cross connect Primary Water from the opposite unit.

4. Verify the availability of the charging pump suction_from_the_RWST.

One of tour Boric 1. Initiate action to repair the unavailable 0- ORANGE Acid Pumps components.

2. Notify Operations, Work Controls, Maintenance, and Plant Managers.

3. Verify the availability of the charging pump suction from the RWST.

4. Verify the availability of two HHSI pumps with suction aligned to an RWST with at least 20,000 gallons of water AND an available flownath to the RCS.

WQ7fl. ITinkimrimr

ENCLOSURE 6 (Page 4 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD A1NI) RCS TEMP LESS THAN 200 DEGREES WITH RCS LOOPS FILLED Required Function Equipment Contingency Action Color Code Inventory Two of four HHSI 1. Initiate action to restore the unavailable 1 YELLOW Control Pumps each with components. 0 ORANGE (Contd) an emergency 2. Verify the availability of at least two charging power supply and pumps. suction capability 3. Maximize RCS inventory. from an RWST 4. Maintain RCS temperature as low as possible. with at least 5. Notify the Operations, Work Controls, 20,000 gallons of Maintenance, and Plant Managers. water AND an available flowpath to the RCS. On-site and Two of the 1. Go to 3/4-ONOP-004, LOSS OF OFF-SITE 1 xfmr with Off-site below listed POWER, for loss of off-site power. SBO tie - Power Transformers 2. Go to 3/4-ONOP-092.3, STARTUP YELLOW capable of TRANSFORMER MALFUNCTION, for S/U 1 xfmr without powering A B transformer malfunction. SBO tie - 4KV Bus

3. Initiate actions to return the required ORANGE transformer to service.

                . Startup          4. Verify the availability of both EDGs.            0 xfrm RED

5. Verify the availability of the station blackout a AUXon tie.

backfeed 6. Suspend activities that would risk the remaining power supplies. a Opposite unit 7. Verify the availability of one C Bus to power A startup or B 4KV Bus transformer to 8. Notify the Operations, Work Controls, A Bus Maintenance, and Plant Managers. a Either Units C Bus transformer toAORBBus

Reference Step 5.1.1.29 W7nIT/nIs/mr/mn

ENCLOSURE 6 (Page 5 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AN]) RCS TEMP LESS THAN 200 DEGREES WITH RCS LOOPS FILLED Required Function Equipment Contingency Action Color Code On-site and A,BANDD4KV 1. Take action to restore the out-otservice Loss of D Bus Off-site Busses components. Go to appropriate procedure - YELLOW Power below: 3/4-ONOP-004.2, LOSS OF A 4KV BUS Loss ofA or B (Contd) Bus ORANGE 3/4-ONOP-004.3, LOSS OF B 4KV BUS 3/4-ONOP-004.5, LOSS OF D 4KV BUS 1- RED

2. Verify at least two on-site sources of AC power are available.

3. For loss of Off-site power go to 3/4-ONOP-004, LOSS OF OFF-SITE POWER.

4. With A, B, OR D 4KV Busses unavailable, verify the ability to power A OR B Bus from one C Bus transformer.

5. With D 4KV Bus unavailable maintain both associated unit EDGs available.

One Emergency 1. Take action to restore the unavailable EDG to 0 ORANGE Diesel Generator service. on the Associated 2. Suspend activities that may risk the Off-site Unit power sources.

3. Verify availability of the station blackout tie.

4. Verify the ability to power A or B Bus from one C Bus transformer.

Station Blackout 1. Verify availability of both associated unit Ow/C bus tie Tie EDGs. YELLOW

2. Suspend activities that may risk the Off-site power supplies. 0 w/o:

3. Verify the ability to power A Q3 B Bus from

C Bus tie one C Bus transformer. AND
Opposite unit SU Xfmr -

ORANGE Wg7r). IT/I/mr/mn

ENCLOSURE 6 (Page 6 of 9) MINIMUM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AND RCS TEMP LESS THAN 200 DEGREES WITH RCS LOOPS FILLED Required Function Equipment Contingency Action Color Code Reactivity CB> 0-OP-028.2 1. Take action to restore boron concentration (CB) to> RED if C 8< Control SDM Calculation O-OP-028.2 SDM Calculation. 00P028.2

2. Veri NO primary water additions in progress.

lilation Shutdown Two of Four Source I. Take action to restore the failed components. 1/4 WHITE Monitoring Range Instruments 2. Suspend activities that could reduce the available 0/4 YELLOW Instrumentation 1 w/ Audible Count Shutdown Margin. Rate 3. Notii the Operations, Work Controls, Maintenance, and Plant_Managers. ARMS Channels: 1. Take action to restore the failed components. Loss of 1 or Three Inside 2. Install temporary monitoring equipment in the affected more WHITE Containment # area.

3. Suspend activities that may increase radiation levels in the_affected_area.

PRMS Channels 1. Take action to secure releases via the unmonitored Loss of I or R-11, R-12, R-14, pathway OR take action to continue releases as allowed more WHITE R-19 by Technical Specifications.

2. Consider installation of temporary monitoring equipment.

2 Core Exit 1. Arrange with I&C for alternate readouts or monitoring of 0 YELLOW Thermocouples CETs if possible.

2. VerifS that two channels of wide range TH0T are available.

3. Maintain RCS greater than 10 percent Wide Range Pressurizer Level.

One at a time may be OOS for calibration.

W97:DJT/cls/mr/emc

ENCLOSURE 6 (Page 7 of 9) MIMMIJM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AND RCS TEMP LESS THAN 200 DEGREES WITH AT LEAST TWO RCS LOOPS FILLED Required Function Equipment Contingency Action Color Code Shutdown One Channel of 1. Take action to restore at least one channel as 0 WHITE Monitoring Reactor Vessel soon as possible. Instrumentation Level HJTC 2. Maximize RCS inventory as much as is (Contd) (QSPDS) allowed by plant conditions.

3. Maintain RCS greater than 10 percent Wide Range_Pressurizer_Level.

One Channel of 1. Take action to restore one channel to service 0 WHITE Containment as soon as possible. Water Level Indication Two Channels of 1. Restore two channels to service as soon as 1 WHITE Containment possible. 0 YELLOW Sump Level 2. Suspend activities that may result in increased Indication sump level.

3. Verify that any temporary drain hoses are not resulting in loss of RCS inventory at least once_per_shift One of four 1. Suspend activities which may result in RCS 0 WHITE channels of inventory loss.

Pressurizer Level Indication + RCS Pressure 1. Verify sufficient OMS trains are still 1 YELLOW Instruments available. 0 ORANGE PT-402, 2. Secure power to any MOV which could result PT-403, and in RHR loss due to unwanted action from an PT-405 unavailable pressure channel. (N/A if interlocks defeated.)

3. Notify the Operations, Work Controls, Maintenance,_and_Plant_Managers.

RCS Wide Range 1. Verify the availability of two CETs. Per Loop oniy TROT and TC0LD: 2. Verify that OMS controls are not affected by TH0T or At least one the unavailable channel. TC0LD channel per loop WHITE NONE - YELLOW WQ7fl. IT/nI/mr/mr

Procedure No.: Procedure

Title:

Page: 97 Approval Date: 0-ADM-051 Outage Risk Assessment and Control 7/22/11 ENCLOSURE 6 (Page 8 of 9) MINIMuM REQUIRED EQUIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AND RCS TEMP LESS THAN 200 DEGREES WITH RCS LOOPS FILLED Function / Support Required Equipment Equipment Contingency Action Color Code Containment Equipment Hatch 1. Suspend activities that risk required Decay Required Time Closure (capable of being Heat Removal Equipment. Met GREEN closed with four 2. Initiate action to restore the capability to bolts in close the hatch in the required time frame. accordance with 3. Notify the Maintenance, Operations, Work Required Time Enclosure 13)

Controls, and Plant Managers. Not Met (TCN Personnel Hatch 1. Suspend activities that risk required Decay Required) -

(capable of being Heat Removal Equipment. YELLOW closed in 2. Initiate action to restore the capability to accordance with close the hatch in the required time frame. Enclosure 13)

3. Notify the Maintenance, Operations, Work Controls,_and_Plant Managers.

Containment 1. If an exception is taken, and at least one valve Penetrations (At in the penetration is capable of closure, either least one valve in manually from the Control Room or locally, each penetration the penetration shall be logged on Attachment that is NOT 3. The log entry shall identify the actions pressurized should necessary to close the penetration. be kept closed or 2. If an exception is taken, and the penetration is capable of being NOT capable of being closed by at least one closed in valve, a TCN with a contingency plan to accordance with achieve closure is required PRIOR to Enclosure 13) authorizing work on the penetration. Exceptions may 3. Initiate action to restore closure capability. be taken under 4. Suspend activities that would risk required administrative Decay Heat Removal Equipment. controls for 5. Notify the Maintenance, Operations, Work testing, Controls, and Plant Managers. surveillance, and maintenance. Risk One Auxiliary 1. IF out-of-service time is to exceed 119 hours, 0 YELLOW Significant Building Exhaust THEN notify the Work Controls Manager Equipment Fan and Plant Manager.

2. Assess the impact on the operating unit.

3. Assess the impact on the Operating RHR pump.

Capability includes provisions for unavailability of AC power and environmental conditions expected.

Wt17fl. IT/rI/mrOmr

Procedure No.; Procedure

Title:

Page: 98 Approval Date: O-A.DM-051 Outage Risk Assessment and Control 7/22/11 ENCLOSURE 6 (Page 9 of 9) MINIMUM REQUIRED EQuIPMENT, PHASE II, REDUCED DECAY HEAT LOAD AND RCS TEMP LESS THAN 200 DEGREES WITH RCS LOOPS FILLED Support Required Equipment Equipment Contingency Action Color Code Risk One Diesel Driven 1. Verify the availability of a portable Instrument 0 - YELLOW Significant Instrument Air Air Compressor. Equipment Compressor AND 2. Verify the availability of the Instrument Air (Contd) the Instrument Air Cross Tie. Cross Tie Lines 3. IF out-of-service time is to exceed 548 hours, THEN notify the Work Controls Manager and Plant Manager.

4. Assess the impact on the operating unit.

Vital DC Room 1. Monitor temperature in the Inverter and DC I WHITE HVAC Two of

                           -                    Equipment Rooms.                                       0 YELLOW three units                2. Install portable fans or verify availability of required E16D                 portable fans.

E16E E16F 3. Assess the impact on the operating unit. Service Water 1. Assess the impact on the operating unit. Loss of 1 or Pumps One- more WHITE Electric pump AND one Diesel driven pump W97:DJT/cls/mr/emc

ENCLOSURE 7 (Page 1 of 2) MINIMUM REQUIRED EQUIPMENT SPENT FUEL POOL DURING REFUELING OUTAGES Required System Equipment Contingency Action Color Code Spent Fuel SFP Cooling Pump A 1. Take immediate action to repair the failed pump, or 1 YELLOW Cooling AND B switch to the other pump. 0-RED

2. Establish Emergency SFP Cooling Pump operation per 3/4-ONOP-033.1, Spent Fuel Pit (SFP) Cooling System Malfunction.

3. Notif the Operations, Work Controls, Maintenance, and Plant Managers.

4. Monitor Spent Fuel Pool temperature and level frequently.

5. Suspend any activities that would risk remaining equipment required (ICW, CCW, Electrical, Makeup).

6. Go to 3/4-ONOP-033.l, SPENT FUEL PIT (SFP)

COOLING SYSTEM MALFUNCTION. Two ICW Pumps 1. Go to 3/4-ONOP-O 19, INTAKE COOLING WATER 1 YELLOW MALFUNCTION, for loss of ICW. 0 RED

2. Initiate action to restore at least one (1) ICW Pump to service.

3. Monitor SFP temperature and level periodically.

4. Notif the Operations, Maintenance, Work Controls, and Plant Managers.

5. Go to 314-ONOP-033.1, SPENT FUEL PIT (SFP)

COOLING SYSTEM MALFUNCTION. One ICW Header 1. Obtain Operations and Plant Manager permission prior 0 RED to removing an ICW Header from service.

2. Veri one ICW pump AND one CCW Heat Exchanger are aligned to the functional header.

3. Verify functional header basket strainer is clean.

4. Initiate actions to restore at least one header to functional status.

5. Take actions as described for ICW Pump.

Two cCW Pumps 1. Take action to restore at least one pump to service. 1 YELLOW

2. Go to 314-ONOP-030, COMPONENT COOLING 0 RED WATER MALFUNCTION, for loss of CCW.

3. Notify Operations, Maintenance, Work Controls, and Plant Managers.

4. Monitor SFP temperature and level frequently.

5. Go to 3/4-ONOP-033.1, SPENT FUEL PIT (SFP)

COOLING SYSTEM MALFUNCTION. One CCW Heat 1. Take actions as described for CCW pump. 0 RED Exchanger AIO7fl ITbl!r,,r!,

ENCLOSURE 7 (Page 2 of 2) MINIMUM REQUIRED EQUIPMENT SPENT FUEL POOL DURING REFUELING OUTAGES Function / Required System Equipment Contingency Action Color Code Spent Fuel A ANfl B 4KV Bus 1. Go to 3/4-ONOP-004, LOSS OF OFF-SITE POWER, for 1 YELLOW Cooling loss of off-site power. 0 bus RED

2. Take action to restore out-of-service components.

3. Notify Operations, Maintenance, Work Controls, and Plant Managers.

4. Go to appropriate procedure below:

3/4-ONOP-004.2, LOSS OF A 4KV BUS 314-ONOP-004.3,_LOSS_OF B 4KV BUS Spent Fuel Pit Exhaust 1. Initiate action to restore exhaust fan to service. 0 WHITE Fan 2. Notify the Operations, Work Controls, Maintenance, and Plant Managers.

3. Suspend any activities that would risk Spent Fuel Pool Cooling_capabilities.

Onsite! One Emergency Diesel 1. Take action to restore the unavailable EDG to service. 0 ORANGE Offsite Power Generator on the 2. Suspend activities that may risk the off-site power sources. Function Associated Unit 3. Verify the availability of the Station Blackout Ties.

4. Verify the ability to energize A OR B 4KV Bus from either_unit_C_Bus.

C 480 Volt Load I. Initiate action to restore power to C load center. 0 YELLOW Center 2. Notify Operations, Maintenance, Work Controls, and Plant W/ALT SFP Managers. COOLING

3. Verify the ability to power the Emergency SFP Cooling 0 RED WINO Pump lAW 3/4-OP-033, Spent Fuel Pit Cooling System. ALT SFP

4. Monitor SFP temperature and level frequently. COOLING

5. Go to 314-ONOP-033.l, SPENT FUEL PIT (SFP)

COOLING SYSTEM MALFUNCTION. SFP Water 2 of following water 1. Initiate actions to restore SFP makeup source in 1 or less Makeup sources: accordance with 314-OP-033. YELLOW RWST and RWST 2. Consider Fire Protection System and dual hose station. Sources purification pump 3. Notifj Operations, Maintenance, Work Controls and Plant PWT and PW pump Managers.

                  - CVS Holdup Tank and Recirc Pump      4. Monitor SFP level and temperature frequently.

5. Suspend all activities that would risk spent fuel cooling capabilities.

W97:DJT/cls/mr/emc

ENCLOSURE 8 (Page 1 of 1) UNTT 4 2000 REFUELING OUTAGE OVERVIEW UNIT 42000 REFUELING OUTAGE OVERVIEW ADM-051 ENCLOSURES III 2 161 i I .Mt0I$C00000 0XC0010 COMWON pc20FLLnomcr 200 00F00ED 4 0XVflV 4 o&o.oOTMYS 0000o R0L0 T 4° t 4L.. i I I ti.t t Ii + 251261271281291301011021031041051061071081091101111121131141151181171181191201

                                         -  I                                                                             hJ 00 0000 00 FOMWGO 00000000 00000 I

R0IE00N 0000000 OX 10000010 r T r. 0.01000000.0050. 4 p..

                                                                                                                                      -                    I I          W00T04000                                    000PIIATOT 00010                                           EOU011010TOI 00010    U01HOT0 0.0000 F.                                      100100100000 10 O.000O0 0.0100010101000 9

A!Q7fl IT/,Io/nTr/on,o

ENCLOS1JRE 9 (Page 1 of 2) SAMPLE OUTAGE COMMUNICATIONS TOOL 03/28/05 12:40 PM 41 Turkey Point Nuclear XXJXX!XX PT4-22 0CC Turnover (Nights to Days) Industrial Safety & Human Performance Outage Dose Status 41 Injuries In Last 24 Hours: 0 Last 12 Hours: Actual 0.000 Rem Estimate- 0.000 Rem TOTALS: 0 MINOR 0 OSHA RECORDABLES Outage Total: Actual 0.0000 Rem Eslimate 0.000 Rem Injuries: None PCRs last 12 Hours: 0 Near Misses: None PCRs Outage Total : 0 Level I 0 Level II SAFETY NEVER TAKES A DAY OFF! Posting Changes: Unit 3 Areas Of Unit 4 Status: Mode 3 Outage Unit ] ilr jor Ops Evolutions Risk Status: Critical Equipment: Evolutions in Proeress: None Evolutions planned for next 24 hours: Critical Path & Priority Activity Status: Expected Upcoming Mi1stones Major Work Completed in Last 24 hours Major Maintenance Activities Maj or Engineering Activities Parts Issues Outage Paper Work Status Major Projects Activities Total Scheduled Total Total in Sched: To Date Received Total WOs: 0 0 0 Red WOs: 0 0 0 Yellow WOs: 0 0 0 WAs: 0 0 0 Turbine Activiti es Working Complete G\WC\Commojt\OCC\U3 Cyc 21 2004\PT3-21 Turnover Sheets\Turnover (date days/nights or nights to days) W97:DJT/cls/mr/emc

ENCLOSURE 9 (Page 2 of 2) SAMPLE OUTAGE COMMUNICATIONS TOOL 03/28/05 12:40 PM Protected Equipment FIJINCTION REQUIRED EQUIPMENT 3A & 3B RHR Pumps/ CCW/ ICW Pp - SEE ENCLOSURE 6 DECAY HEAT REMOVAL 0-ADM-051 FOR LIST OF EQUIPMENT 2 Chg Pumps with Boron Flow path SEE ENCLOSURE 6 INVENTORY CONTROL

j. O 51 FOR LIST OF EQUIPMENT ON-SITE ,OFF-SITE POWER U V Busses/One EDG SEE ENCLOSURE 6 R LIST OF EQUiPMENT tion meets Plant Curve Book SEE ENCL. 6 REACTIVITY CONTROL 0-At ,R LIST OF EQUIPMENT 2 Source Range Inst. - SEE ENCLOSURE 6 SHUTDOWN MONITOR INSTRUMENTATION O-ADM-05 I FOR LIST OF EQUiPMENT 30 Minute Closure - SEE ENCLOSURE 6 CONTAINMENT CLOSURE 0-ADM-05 I FOR LIST OF EQUIPMENT 2 Aux. Bldg. Exh. Fans / One Diesel I. Air Comp. SEE RISK SIGNIFICANT EQUIPMENT ENCLOSURE 6 0-ADM-05 I FOR LIST OF EQUIPMENT G\WC\Common\OCC\U3 Cyc 21 2004\PT3-21 Tumover Sheets\Tumover (date days/nights or nights to days)

W97:DJT/clslmr/emc

ENCLOSURE 10 (Page 1 of 4) MODES 5,6, AND DEFUELED ACTIVE SHUTDOWN COOLING EQUIPMENT PROTECTED TRAIN CONCEPT 200 Deg 200 Deg Modes 1-4 Modes 1-4 On-Line On-Line Protected Train Protected Train Concept Concept RCS Depress ECS Depress

                                                                                          /Drained <10% PZR                    IPilled >10% PZR Cavity Flooded                       Cavity Flooded RCS         >23 Above the                        >23 Above the RCS Loops        Depressu rized!   Rx Vessel Range                      Rx Vessel Range                    RCS Loops Availabie                                          RCS Defueled                                             Available.
                                            /DrainecL
                        -                                                                                         i Enclosure 2                                            Enclosure 4        Enclosure      Enclosure B Enclosure I                      Enclosure 3       Enclosure 7
                        .4             .4                                 r-4 Protect Seth                                                                          Protect Operating Protect the                   Protect Operating    Protect 8FF      Protect Operating                    RI-IR Train RHE Trains      RHR Trair(And         Cooling         RHR Trln(An Operating 8FF Cooling                           SFP Cooling RHR Train During Offload)                       During Reload)

Protect Seth RHR Trains

                                                                                                                  -I W97:DJT/cls/mr/emc

ENCLOSURE 10 (Page 2 of 4) MODES 5,6, ANT) DEFUELED ACTIVE SNIJTDOWN COOLING EQUIPMENT PROTECTED TRAIN CONCEPT a Specific procedural guidance for the placement and removal of signs and barriers is provided in Attachments 8 through 21. RCS Loops Available Protect the following equipment with signs and/or barriers:

Switchyard bay for the transformer (Startup or Main) supplying the safety related 4 kv buses.
Transformer (Startup or Main & Aux) supplying the safety related 4 kv buses.

Operating RHR train 4kv switchgear

Operating RHR train vital 480v load centers
Operating RHR train EDG rooms
3A MCC Vital Section (3A Train only)
D bus room (if C CCW pump or C ICW pump is required for the operating RHR Train)
Operating RHR pump room
Operating RHR train CCW pump
Operating RHR train ICW pump
2of3CCWHx and 5 (Pressurizer Drained <10%) Without RCS Loops Available Protect the following equipment with signs and/or barriers:
Switchyard bay for the transformer (Startup or Main) supplying the safety related 4 kv buses.
Transformer (Startup or Main & Aux) supplying the safety related 4 kv buses.
Both A&B 4kv switchgear Vital 480v load centers
Both EDG rooms
3A MCC Vital Section (3A Train only)
D bus room (if C CCW pump or C ICW pump is required for the protected RHR Train)
Both RHR pump rooms
Operating RHR train CCW pump
Operating RHR train ICW pump
1 non-operating RHR train CCW pump
1 non-operating RHR train ICW pump
2of3CCWHx W97DJT/ds/mr/mr

ENCLOSURE 10 (Page 3 of 4) MODES 5,6, AN]) DEFIJELED ACTIVE SHUTDOWN COOLING EQUIPMENT PROTECTED TRAIN CONCEPT and 4 Cavity Flooded >23 Above the Vessel Flange Protect the following equipment with signs and/or barriers:

Switchyard bay for the transformer (Startup or Main) supplying the safety related 4 kv buses Transformer (Startup or Main & Aux) supplying the safety related 4 kv buses
Operating RHR train 4kv switchgear
Operating RHR train vital 480v load centers or all vital 480v load centers when cross-tied
C 480v load center (if core less than fully loaded)
SFP cooling equipment room and heat exchanger (if core less than fully loaded)
Operating RFIR train EDG rooms
3A MCC Vital Section (3A Train only)
D bus room (if C CCW pump or C ICW pump is required for the operating RHR Train)
Operating RHR pump room
Operating RHR train CCW pump
Operating RI-IR train ICW pump
2of3CCWHx
SFP makeup water sources (pumps) (Pressurizer Filled >10%) Without RCS Loops Available Protect the following equipment with signs and/or barriers:
Switchyard bay for the transformer (Startup or Main) supplying the safety related 4 kv buses
Transformer (Startup or Main & Aux) supplying the safety related 4 kv buses
Operating RHR train 4kv switchgear
Operating RHR train vital 480v load centers
Operating R}IR train EDG rooms 3A MCC Vital Section (3A Train only)
D bus room (if C CCW pump or C ICW pump is required for the operating R1{R Train)
Operating RHR pump room
Operating RHR train CCW pump
Operating RHR train ICW pump 2of3CCWHx RCS Loops Available Protect the following equipment with signs and/or barriers:
Switchyard bay for the transformer (Startup or Main) supplying the safety related 4 kv buses
Transformer (Startup or Main & Aux) supplying the safety related 4 kv buses
Operating RRR train 4kv switchgear
Operating RI-IR train vital 480v load centers
Operating RHR train EDG rooms
3A MCC Vital Section (3A Train only)
D bus room (if C CCW pump or C ICW pump is required for the protected RHR Train)
Operating RHR pump room
Operating RHR train CCW pump
Operating RI-JR train ICW pump
2of3CCWHx Wq7fl. IT//mr/cmr

ENCLOSURE 10 (Page 4 of 4) MODES 5,6, AI1) DEFUELED ACTIVE SHUTDOWN COOLING EQUIPMENT PROTECTED TRAIN CONCEPT RCS Defueled Protect the following equipment with signs and/or barriers:

Switchyard bay for the transformer (Startup or Main) supplying the safety related 4 kv buses.
Transformer (Startup or Main & Aux) supplying the safety related 4 kv buses.

If C 480v load center fed from A 4kv bus:

A 4kv switchgear
A EDG rooms
3A MCC Vital Section
A480v load center
1 A train CCW pump
1 A train ICW pump
If C 480v load center fed from D 480v load center:

B 4kv switchgear

B EDO rooms B and D 480v load centers
1 B train CCW pump
1 B train ICW pump
C 480v load center or all vital 480v load centers when cross-tied
SFP cooling equipment room
D bus room (if C CCW pump or C ICW pump is required for the operating SFP cooling loop)
1of3CCWHx
SFP makeup water sources (pumps)

W97:DJT/cls/mr/eme

ENCLOSURE 11 (Page 1 of 1) OUTAGE ACTIVITY REVIEW CHECKLIST

1. Does the activity involve work in or affecting the Switchyard? Yes LI No LI

2. Does the activity affect, or have the potential to effect, required Yes LI No LI equipment listed in Enclosures 1 through 7 (Even if not reducing below the minimum Required)?

3. Does the activity involve configuration, or changing configuration of Yes LI No LI operating shutdown cooling trains?

4. Does the activity involve work on or near protected/operating shutdown Yes LI No LI cooling equipment?

5. Does the activity challenge containment closure or provide a direct path Yes LI No LI to atmosphere that does not meet the requirements of Attachment 3?

6. Does the activity involve a freeze seal that threatens inventory control? Yes LI No LI

7. Does the activity involve the potential introduction of hazards (e.g., fire, Yes LI No LI flooding, etc.) *

8. Does the activity or evolution have the potential to result in a rapid loss of RCS or SFP inventory in the event of an active failure or personnel Yes LI No LI error.

A Yes answer indicates that the activity should be considered a R-Iogic activity in the outage schedule unless further review concludes the activity is adequately controlled by other existing processes or procedures. Evaluate hot work performed in areas that risk Key Safe Shutdown Functions. Determine if contingency plans are required. W97flJT/eIs/mr/emc

Procedure No.: Procedure

Title:

Page: 109. Approval Date: 0-ADM-051 Outage Risk Assessment and Control 7/22/11 ENCLOSURE 12 (Page 1 of 1) COMPONENT AVAILABILITY SCREENING CHECKLIST a a A conservative approach should be employed when assessing component availability. a a a a a a I

1. If the component is ECO tagged, is it under operations control, or Yes LI No LI capable of being placed under operations control, in a reasonable time frame? (i.e., the component is not under a danger tag)

2. Can the component be restored in a time frame consistent with the Yes LI No LI anticipated need for the component?

3. Is the component intact and can be made functional by automatic or Yes LI No LI simple manual action?

4. Is the contingency plan for the restoration of the component well Yes LI No LI communicated and understood by all groups involved?

5. Is the contingency plan for restoration of the component adequate and Yes LI No LI reasonably expected to be accomplished?

6. Is the component under a non-intrusive surveillance not requiring Yes LI No LI extensive efforts(i.e., filling and venting of systems, etc) to restore?

7. If the component or function is temporary, has the component been Yes LI No LI tested?

All Yes answers support considering the component available. Any No answers indicate the component should be considered unavailable. W7fl.ITIeIq/mr!pmr,

ENCLOSURE 13 (Page 1 of 1) CONTAIINMENT CLOSURE TIME LIMITS May be Ctmt extended O-ADM-051 Closure with Enclosure Time Limit TCN? Comments 1 30 minutes Y 2 Time to core N NUMARC 91-06 Guidelines (Not RI, time to core boil <30 boiling minutes) 2 30 minutes Y Still limited to time to core (Not RI, time to core boil >30 boiling (NUMARC 91-06) minutes) 2 Time to core N NUMARC 9 1-06 Guidelines (RI, time to core boil <30 boiling minutes) 2 30 minutes N NRC Commitment (GL88-17) (RI, time to core boil >30 minutes) 3 30 minutes Y Time to core boiling is (no core alts) assumed to be >30 minutes in this enclosure. Still limited to time to core boiling. NUMARC 91-06 Guidelines 3 30 minutes N NUMARC 93-01 Guidelines (During core alts) [Commitment 2.3.2] 4 30 minutes Y Time to core boiling is (no core alts) assumed to be >30 minutes in this enclosure. Still limited to time to core boiling. NUMARC 91-06 Guidelines 4 30 minutes N NUMARC 93-01 Guidelines (During core alts) [Commitment 2.3.2] 5 Time to core N NUMARC 91-06 Guidelines (Not RI, time to core boil <30 boiling minutes) 5 30 minutes Y Still limited to time to core (Not RI, time to core boil >30 boiling. NUMARC 91-06 minutes) Guidelines 5 Time to core N NUMARC 91-06 Guidelines (RI, time to core boil <30 boiling minutes) 5 30 minutes N NRC Commitment (GL88-17) (RI, time to core boil >30 minutes) 6 30 minutes Y 7 N/A RI Reduced Inventory W97:DJT/cls/mr/emc

ATTACHMENT 1 (Page 1 of 1) INTENTIONALLY LEFT BLANK W97:DJT/cls/mr/emc

ATTACHMENT 2 (Page 1 of 2) TEMPORARY CHANGE NOTIFICATION iange Number UNIT CYCLE NUMBER or FO name Systei Number System Name Inittating Document/Activity

Description:

                 *1 Expected Duration of Change Plant EvaluationlAssessment of Key Safe Shutdown Functions Note: Evaluation should include:

1. Consideration of common or unit specific equipment that affects the other unit

2. Review of all TCNs in effect during the duration of this TCN to ensure the tota mpact of all equipment out of service is considered.

F-367 1:2- Rev. 2(8/30/10 0-ADM-051) W97:DJT/cls/mr/emc

ATTACHMENT 2 (Page 2 of 2) TEMPORARY CHANGE NOTIFICATION Temporary Change Number Affete4Dramings and Procedures (Attach Markups and OTSCs) [1 i es []No The applicable off-normal response procedures are challenged by this TC If Yes, the appropriate recovery guideiites ieificluked in the procedure mark-ups and are available in the Control Room. Special Notes/Off Normal Guidance/Contingencies LI YES LI NO PWO requires contingency actions If YES, then verify PWO contingencies are incorporated and reviewe4 as acceptable. Approval/Acceptance Risk Assessment Lead .Dtr_______________ System Engineer SM Operations Manager Plant General Manager Engineering Manager Work Controls Manager Maintenance Manager F-367 2:2 Rev. 2 (SR OIiO O-ADM.051) Wi7fl. ITIckImrIm.

ATTACHMENT 3 (Page 1 of 3) CONTAINMENT PENETRATION EXCEPTIONS Part A t. cionsequIre Department Estimated Peetrati& Responsible Time to Date Closed or osure fl ere Etd For Closure Close F-369/1 :3 Rev. 4 (09/24/09 0-ADM-051) WQ7fl. IT//mr/mr

ATTACHMENT 3 (Page 2 of 3) CONTAINMENT PENETRATION EXCEPTIONS EQUIPMENT HATCH DOOR Date:_________ Part

       ,    ,        .,                      Containment                                       Notify tcclrne                         Coordinator/Designee               Signature*           SM/US Name (Print)                                     Ext 6493 Signature         -  Indicates designated individual accepts responsibility to close the Containment Equipment Hatch with a minimum of 4 bolts in accordance with Q-AIM-O51, Enclosure 13, when and if directed by the Shift Manager. The designated person has an ssigned crew of individuals and has verified the necessary equipment to close the Equipment Hatch is staged in accordance with OGMM051 .2, including provisions for unavailability ofi AC power and environmental conditions expected.

Reviewed by: Shift Manager or SRO DesigAee F-369/2:3 Rev. 4 (09/24/09 0-ADM-051) W07fl. IThk/mr/mr

ATTACHMENT 3 (Page 3 of 3) CONTAINMENT PENETRATION EXCEPTIONS PERSONNEL AIRLOCK DOOR Date: ErtC

              .. me 1

andT Name (Print) Signature* Signature Indicates designated individual accepts respqnsihility to close in an expeditious manner within 30 minutes, or prior to time to core boiling, (whichever is less) at least one Containment Personnel Airlock Door when directed by the Sliff Manager. If RCS level lower than 3 feet below the vessel prior to fuel offload, control in accordance with 314-OP-041 .9 until RCS level returns above 3 feet below the vessel. [Commitment Stp-2,i.j.j Reviewed by: Sflhtt Manager or SfrO Designee F-369/3:3 Rev. 4(09/24/09 0-ADM-051) W07fl IT/I/mr/cmr

ATTACHMENT 4 (Page 1 of 12) OUTAGE RISK ASSESSMENT AND PROTECTED TRAIN POSTING VERIFICATION INSTRUCTIONS FOR COMPLETING OUTAGE RISK ASSESSMENT FORMS NOTES I I I

Complete Parts A and B at the following times: I Prior to shift turnover and to be available for the crew meetings.

I I

When changing enclosures or minimum equipment as used to determine risk color.

I I

Upon commencing or completing fuel movement in containment or the SFP.
Part B should be completed each shift when swapping protected train equipment Updates to Attachment 4, Part A and B should be provided as soon as reasonably possible.
Part C is a daily verification of protected train postings and should be performed each dayshift and documented in the RCO logs when completed.

L.. _ = = = = = Completion of Part A

1. Evaluate color determination using the current enclosure based on plant conditions.

2. Obtain review of Attachment 4 Part A from the Shift Manager or designee.

3. Scan Attachment 4 Part A and email to Document Control Technician at documentcontrolptn@fpl.com who will:

a. Provide a copy to the 0CC Manager.

b. Place a copy of the Risk Assessment Book in the WCC.

4. Place the reviewed copy of Attachment 4 Part A in the Risk Assessment Book in the Control Room.

10 Part B will be maintained electronically and the foiowing pages provide an example of the information contained in the electronic version. a a = a I Completion of Part B

1. Open the electronic version of the Risk Control Form.

2. Obtain a copy of the latest revision to the outage schedule from the Work Controls web site.

3. Open the Risk Control Form worksheet tab corresponding to the applicable enclosure of O-ADM-05 1.

Wq7 fl. ITIImrIcmr

ATTACHMENT 4 (Page 2 of 12) OUTAGE RISK ASSESSMENT AND PROTECTED TRAIN POSTING VERIFICATION INSTRUCTIONS FOR COMPLETING OUTAGE RISK ASSESSMENT FORMS

4. Update the Risk Control Form for the current plant conditions. Identify the status of components by the following convention:

a. Protected or required components per 0-ADM-5 1 will be shaded a light gray.

b. Running or energized equipment will be bolded.

5. Update the top of the form with current date, time and risk color determination.

6. Calculate and record the time to boil for the reactor. When applicable, use the Plant Curve Book to determine time to heat SFP to 200°F.

7. Include the applicable TCNs number and title if currently in affect.

8. j risk color is less than white due to an equipment failure or unanticipated change in plant condition and a TCN has not been completed, THEN provide information identifying the at risk components.

9. Provide the completed copy to the Shift Manager or SRO designee for review.

10. Post the reviewed copy of Attachment 4 Part B in an appropriate location in the Control Room.

11. Save a copy Attachment 4 Part B in G:\Wc\DeptShares\0-ADM-05 I Risk Status\PTX-XX.

12. E-mail Attachment 4 Part B to Document Control Technician at documentcontrolptn@fpl.com who will:

a. Provide eight color 11 X 17 copies to the 0CC Manager.

b. Provide three color 11 X 17 copies and post them at the 0CC, WCC and Operations Turnover Meeting Room.

13. The 0CC Manager will ensure that the applicable department supervisor places a copy of Attachment 4 Part B, in an appropriate location assessable to his personnel, at:

a. I&C Maint.

b. Elect. Maint

c. Mech. Maint

d. AMES

e. Projects

f. RSS

g. Turbine Team

h. EPU W97:DJT/cls/mr/emc

Procedure No.: Procedure

Title:

Page: 119 Approval Date: O-ADM-051 Outage Risk Assessment and Control 7/22/11 ATTACHMENT 4 (Page 3 of 12) OUTAGE RISK ASSESSMENT AND PROTECTED TRAIN POSTING VERIFICATION INSTRUCTIONS FOR COMPLETING OUTAGE RISK ASSESSMENT FORMS Completion of Part C

1. Obtain a copy of the current protected train posting attachment in the risk assessment book.

2. Perform a check of the protected train postings:

a. Ensure the proper placement of postings and barriers has been maintained to adequately identify protected equipment or areas.

b. Ensure no unauthorized work is occurring in these protected areas.

3. Document completion of this walk down in the appropriate RCO logbook.

\A107fl. !TIckilmrk.mr

ATTACHMENT 4 (Page 4 of 12) OUTAGE RISK ASSESSMENT A1NI) PROTECTED TRAIN POSTING VERIFICATION COLOR CODE DETER1HNATION WORKSHEET PART A KEY SAFE EQUIPMENT FUNCTION SHUTDOWN EQUIPMENT COLOR COLOR FUNCTION CODE CODE RHR Pumps G Y 0 R N/A RHRHx GYOR N/A CCW Pumps G Y 0 R N/A CCWHx GYOR N/A vIt ICW Pumps G Y 0 R N/A ICW Headers G Y 0 R N/A Feed Source/Flow GY N/A Path SDTA GY N/A Charging Pumps GYOR N/A Cha FlowDath G OR N/A Inventory Control Primary Wtr Pmp G Y 0 N/A BA Trf Pumos G Y 0 R N/A HHSI Pumps G Y 0 R N/A RCS lnvento G Y 0 N/A Transformers GYOR N/A A, B, D Busses G Y 0 R N/A Power Availability EDG G Y 0 N/A Sta Bikout Tie G Y 0 N/A Reactivity Control Boron Conc OR N/A Source Range G W Y N/A ARMs Channels 0 W N/A PRMS Channels G W N/A CETs GYOR N/A RVLIS GWYO N/A Instrumentation Cont Water lnd G W N/A Cont Sump md G W Y N/A PRZ Lvi lnd G W Y N/A RCS Press md G W Y 0 N/A RCS Wde Rng Temp G W Y N/A Rx Drndwn Lvi 0 Y 0 R N/A NQ7fl. IT/rIc/mr/mr

ATTACHMENT 4 (Page 5 of 12) OUTAGE RISK ASSESSMENT AN]) PROTECTED TRAIN POSTING VERIFICATION COLOR CODE DETERMINATION WORKSHEET PART A KEY SAFE SHUTDOWN FUNCTION I SYSTEM I SUPPORT EQUIPMENT FUNCTION EQUIPMENT EQUIPMENT COLOR CODE COLOR CODE Containment Penetration G N/A Integrity Isolation Aux Bldq Exh Fan GY N/A Risk Significant IAC Diesel D GY N/A Equipment DC Room HVAC GW Y N/A Svc Water Pumps GW N/A SEP Cooling Pump GYOR N/A A and B Two ICW Pumps GYR N/A One ICW Header GR N/A Two CCW Pumps GYR N/A Spent Fuel Cooling One CCW Hx GR N/A A and B SWGR GYR N/A One EDG GO N/A C Load Center GYO R N/A SEP Exh Fan GW N/A SF Makeup WTR I 2 of four I G Y N/A I Dayshift/Nightshift (circle one) Prepared by:_ Enclosure Date:________ Time: Risk: Reviewed by: Shift Manager/SR 0 Designee Date W97:DJT/cls/mr/emc

C C) riD C a) I -J 0 0 U 0 a: C U Ui z C 1 c-) 0 E 0 riD c. I vU C,) 0 C 2 U z 0 U 0 C x C,) 0 C C (0 E C c a: U 0 U C I oJ a: C a- LI. C C a. C E

Z C H 0) 0 0) 0) 0) H > riD lJ C I 0 E 0 0 0 -J 0 00 c) C U U H H w Z ZN C 01 E c-) 0; 0 0 , 0 CJD (a Q I (U z 4;, 0 (0 C) 0 EZ C) H C.) H 4;, (a 0 Ot U H 0 IC Z 0 C; C C) C 4) 0) c I 4; C LJ 0 C 4; C-: It E a; E CO 0 z01) C: F 0 I) 0 0 0)

z C a 4) c-) 0 0 0. 4)) 0. 4) C 4) a) LL 4) C > 0

                          .0           I-.

0 4) C)

                  -1   U               0 C       U L1I cI   x A    >

x Z -

4) X Zr C -J o 4)

S 0 E 0

                          .2 IJ--Ijz      U 4).

CJD I U z C-) U: C) cJ 0 ci c) C) 4) C

4) C C) C a

I c 4) 4> C C

4) 4)

H

4) I U z

4) 0 a: 4) 0

                                   .0 0                        4) 0   4)

I E E 4) z C I U 0

0 U

0 r 0 a

z C z C > C F z - 0, It c,) 0 oOE (C 0 rM C x 4 Z 0 () () I F-) 0 C 0 z r U C C) C ca ci) ci) C I) V L ci) (I Cl) C)

a. F)

F) Ci) C E z C) C C) 2

z C C) c.) C) ci) ci CU] CU CU I Co ciD C 0, 0 0 -J (0 U U C w LL] 0 C c c.) 0 ri) C) rl) cj1

0 c.) C z CU C) 0 C) C?) 0 4.? U, I.. z a;: 0 0 CU C 0) CU, C C) c ci, C) F -C I CU a;: 0) C C) LL,

-d ci) 0.)

rf, C CJD 0

a. 4),

0 10 1 In 0 E Co z0 0) C F C) -C) 0) C C C.) 0

C c-) 4).

.4)

Co 0, 0 ci) 0 I -j C z 0) 0 I C U L z C -I 0 jj 0_i o 0 Ci) 0 I vU C z 0 0 0 U 0) I 0 0 C C C C 0 F a.. C E E C I C

ATTACHMENT 4 (Page 12 of 12) OUTAGE RISK ASSESSMENT AND PROTECTED TRAIN POSTING VERIFICATION PART B RISK CONTROL PART B RISK CONTROL Enclosure 7 Spent Fuel Pool Minimum Required Equipment Status: COLOR Date: xxlxx!xx Time: xxxx Desicination: Shaded = Protected Bold = Runnina orEneraized Protected Train 4A 4B SFP Coolinci Pump A B low Pump 4A 4B 40 lOW Header A 8 COW Pump 4A 4B 40 COW Heat Exchanger 4A 4B 40 4160 Bus 4A 4B SEP Exhaust Fan On Ott Emergency Diesels 4A 4E 480 Volt LO 40 Yes No RWST & CVOS Hold purification PWST & PW uplank& SFP Make-uD Water Source oumo ciumn Recirc Pmci Tank Level = Spent Fuel Pool Time to Boil f Minutes ApplicbleTCNs Reason for Reduced Risk Performed By: Reviewed By: AccepBy: I Cont Room, ciSC, wcc, 0513 Date/Time W97:DJT/cis/mr/emc

ATTACHMENT 5 (Page 1 of 1) TEMPORARY CHANGE INDEX TEMPORARY CHANGE INDEX umr j... Key Date Date escrIpLIon Fnctián Entered Restored F-368 Rev. 1(8/22/07.- O-ADM-051) W97:DJT/ds/mr/emc

ATTACHMENT 6 (Page 1 of 2) APPROVAL OF WORK ON PROTECTED/OPERATING TRAIIN Dcription of Activity Justification For Work on ProtectedJOperating Train (i.e., plant design, emergent condition, etc) Risk Assessment Team Review Required equipment will be reduced below thIevel of Enclosures 1 through Yes LI No LI 7 (Le., TCN is required) Required equipment not reduced below the level of Enclosures 1 through 7, Yes LI No LI but TCN recommended? Additional protected equipment signs or barriers required as a result of the work? If Yes, list specific components/locations. Yes LI No LI Any additional recommended compensatory actions? If Yes, list below. Yes LI No LI Recommendation by the Risk Assessment Team: Yes LI No LI RAT Leader (Ops) F-56211/2- Rev. 3(09/24/09 0-ADM-051) W07fl. IT/ric/mr/emr

ATTACHMENT 6 (Page 2 of 2) APPROVAL OF WORK ON PROTECTED/OPERATING TRAIN NOTES

Approval by the below individuals must be in a face to face or per telecom group discussion.

Delegation of signature authority for the individuals below must be in writing to the Risk Assessment Team Leader. Delegation of that authority is allowable only when the G individual is not on site. I

Review by the Shift Manager is required prior to performing activity permitted by this attachment.

I

         . A copy of this approved attachment shall be in hand at the job site prior to I         commencing work.

Approved by: Engineering Manager Approved by: Work Controls Manager Approved by: Operations Manager Approved by: Plant General Manager

Approval Expires:

(Date/Time or specific plant condition) Reviewed by: Sh ft Manager Restoration If additional protected equipment signs and barriers used, verify removed upon completion of activity. Shfl Manager or SRO Designee F-562/2/2- Rev. 3(09/24/09 0-ADM-051) WQ7fl. IT//mr/mr

Procedure No.: Procedure

Title:

Page: 12 Approval Date: O-ADM-051 Outage Risk Assessment and Control 7/22/11 ATTACHMENT 7 (Page 1 of 2) RISK SIGNIFICANT SCHEDULE CHANGE (RSSC) NOTES I Submittal of this form is the responsibility of the department or project lead requesting an R-Logic or potentially risk significant schedule change.

A minor change to a R flagged activity is when NO adverse risk significant change H occurs due to the requested change having obvious inconsequential degradation to outage or shutdown safety risk. Review of Enclosures I through 7 and 11 should be U considered to verify no adverse impact to risk Ensure the basis is adequately I documented.
Complete only Section 1 or 2 as applicable and retain the approved copy in the U Outage Risk Assessment Notebook.

I

A Condition Report must be attached to all Risk Significant Schedule Changes not I deemed as minor.

Section 1: Minor Change Yes No (See Section 2)

1. Describe the change:

2. Describe impact or reason determined as minor change:

3. Approval as Minor RSSC RislcAssessment Team Lead Date

4. Schedule changes processed:

WC initials

5. Retain this form in the Outage Risk Assessment Notebook.

F-563/1 :2 - Rev. 2(09124/09 O-ADM-051) AIO1fl

ATTACHMENT 7 (Page 2 of 2) RISK SIGNIFICANT SCHEDULE CHANGE (RSSC) Section 2: Risk Signfficant Schedule Change Yes D No E

1. Describe Risk Significant Schedule Change and Activities:

2. Discuss overall benefits and risk of change in terms of nuclear safety/outage risk including the impact on required equipment in Enclosures 1 through 7.

3. Approval of RSSC: Yes El No LI Remarks:

Risk Assessment Team Lead Date Operations Jvfanager Date Plant General L[anager Date

4. RAT member delineate risk logic ties for the approved change.

5. Schedule changes processed:

WC Initials

6. WC and/or 0CC Outage Managers apprised of changes:

Initials

7. Document in Condition Report and attach copy of CR.

8. Retain this form in the Outage Risk Assessment Notebook.

F-563/2:2 - Rev. 2(09/24109 0-ADM-051) W97:DJT/cls/mr/emc

ATTACHMENT 8 (Page 1 of 5) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 1 NOTES

The steps in this attachment may be performed in any order.
Due to the size of the switchyard bay, the size of the area around the transformers, and the size of the area around the CCW Heat Exchangers, those specified postings are not intended to provide a physical barrier; rather; to provide information and heightened awareness.
If the operating train is swapped, or if components within a train are swappecJ protected equipment postings should be placed or removed as necessa,y to maintain the postings and equipment status consistent. The new alignment should be posted prior to deposting the previously protected equipment IF offsite power is from the startup transformer, THEN perform the following:

a. In the switchyard, install barriers around the startup transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the startup transformer, install barriers around the startup transformer.

2. IF offsite power is from backfeed, THEN perform the following:

a. In the switchyard, install barriers around the main transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the main and aux transformers, install barriers around the main and aux transformers.

W97:DJT/cls/mr/emc

ATTACHMENT 8 (Page 2 of 5) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 1

3. IF 3A Train is the designated operating train, THEN post signs and/or barriers as follows:

a. Install barriers in the 3A 4kv bus room at the following locations:

(1) East side of the 3A switchgear bus from the north wall to the south wall (2) West side of the 3A switchgear bus from the north wall to the south wall (Allow access to LP34.)

b. Install barriers and sign in the U3 480v load center rooms:

(1) Install barriers in front of 3A and 3C 480v LCs. (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

c. Install barriers at the following entry doors to 3A EDG rooms:

(1) Door 073-1 (2) Door 072-2 (3) Door 13 1-1 to the 3A EDG radiator area (4) Door 075-ito the 3A EDG Daytank room

d. Post 3A MCC 480v MCC Vital Section as follows:

(1) At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), place magnetic STOP signs on each cabinet door of 3A 480v MCC Vital Section (8 signs total). (2) At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), place a magnetic STOP sign on the north side facing north. (3) At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), place a magnetic STOP sign on the south side facing south.

e. IF the 3A ICW or CCW pump is unavailable and the 3D bus is aligned to the 3A bus, THEN install barriers at the following entry doors to 3D 4kv bus room:

(1) Door 134-i (2) Door 134-2 W97:DJT/clslmr/emc

ATTACHMENT 8 (Page 3 of 5) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 1

3. (Contd)

f. In the control room, place unique information tags on the following pump control switches identifying them as the protected/operating train:

(1) 3ARRRPump (2) Select one: (N/A pump not operating)

i. 3A CCW Pump OR ii. 3CCCWPump (3) Select one: (N/A pump not operating)

i. 3AICWPump OR ii. 3C ICW Pump

4. 3B Train is the designated operating train, THEN post signs and/or barriers as follows:

a. Install barriers in the 3B 4kv bus room at the following locations:

(1) East side of the 3B switchgear bus from the north wall to the south wall (Permit access to the ASD panel.) (2) West side of the 3B switchgear bus from the north wall to the south wall

b. Perform the.following in the U3 480v load center rooms:

(1) Install barriers at the following locations: o In front of 3B 480v LC o In front of 3D 480v LC (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

c. Install barriers at the following entry doors to 3B EDG rooms:

(1) Door 072-1 (2) Door 072-2 (3) Vital area door 3EDG3 131 to the 3B EDG radiator area (4) Door 074-1 to the 3B EDG Daytank room. W97:DJT/ds/mr/emc

ATTACHMENT 8 (Page 4 of 5) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 1

4. (Contd)

d. the 3B ICW or CCW pump is unavailable and the 3D bus is aligned to the 3B bus, THEN install barriers at the following entry doors to 3D 4kv bus room:

(1) Door 134-1 (2) Door 134-2

e. In the control room, place unique information tags on the following pump control switches identifying them as the protected/operating train:

(1) 3BRHRPump (2) Select one: (N/A pump not operating)

i. 3BCCWPump OR ii. 3CCCWPump (3) Select one: (N/A pump not operating)

i. 3B ICW Pump OR ii. 3C ICW Pump

5. In the 3A 4kv bus room, install signs as follows:

a. Place a protected equipment sign on the front of 3C23A (Old Sequencer Cabinet) located on the north wall of the 3A 4kv bus room.

NOTE I The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could cause a bus lockout. a a a a a a I

b. Place a protected equipment sign on the cubicle door for breaker 3AA09

c. Place a protected equipment sign on the 3AA04 cubicle door.

W97:DJT/cls/mr/emc

ATTACHMENT 8 (Page 5 of 5) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 1

6. In the 3B 4kv bus room, install signs as follows:

a. Place a protected equipment sign on the front of 3C23B (Old Sequencer Cabinet) located on the north wall of the 3B 4kv bus room.

n = = a = 1

                                                                                             =     1 The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could I    cause a bus lockout.

1..... = a a a a a I

b. Place a protected equipment sign on the cubicle door for breaker 3AB22

c. Place a protected equipment sign on the 3AB04 cubicle door.

7. In the CCW room, install barriers around the CCW pump whose 4kv power supply is protected above.

a. Record pump protected

8. Install barriers at the top of stairway to running protected RHR Pump Room (10 ft).

a. Record RFIR Pump Room protected

9. Install barriers on the south end of 2 of 3 CCW Hxs.

a. Record Hxs protected

10. At the Intake, install barriers around the ICW pump whose 4kv power supply is protected above.

a. Record pump protected Date/Time Completed: /

PERFORMED BY (Print) ll.TITIALS W97:DJT/ds/mr/emc

Procedure No.: Procedure

Title:

Page:

                                                                                                      -   139 Approval Date:

0-ADM-051 Outage Risk Assessment and Control 7/22/11 ATTACHMENT 9 (Page 1 of 4) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 2 AND 5 (PRESSURIZER DRAINED <10%) The steps in this attachment may be performed in any order.

Due to the size of the switchyard bay, the size of the area around the transformers, u and the size of the area around the CCW Heat Exchangers, those specified postings are not intended to provide a physical barrier; rather, to provide information and heightened awareness.

a If the operating train is swapped, or if components within a train are swappecJ protected equipment postings should be placed or removed as necessaiy to maintain the postings and equipment status consistent. The new alignment should be posted prior to deposting the previously protected equipment

                                           =                                                 I IF offsite power is from the startup transformer, THEN perform the following:

a. In the switchyard, install barriers around the startup transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the startup transformer, install barriers around the startup transformer.

2. IF offsite power is from backfeed, THEN perform the following:

a. In the switchyard, install barriers around the main transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the main and aux transformers, install barriers around the main and aux transformers.

Wq7fl. IT//mrIcmr

ATTACHMENT 9 (Page 2 of 4) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 2 AND 5 (PRESSURIZER DRAINED <10%)

3. Install barriers in the 3A 4KV Bus room at the following locations:

a. East side of the 3A switchgear bus from the north wall to the south wall

b. West side of the 3A switchgear bus from the north wall to the south wall (Permit access to LP34.)

4. Install barriers in the 3B 4KV Bus room at the following locations:

a. East side of the 3B switchgear bus from the north wall to the south wall (Permit access to the ASD panel.)

b. West side of the 3B switchgear bus from the north wall to the south wall.

5. Perform the following in the U3 480v load center rooms:

a. Install barriers at the following locations:

o In front of 3A 480v LC

In front of 3B 480v LC o In front of 3C 480v LC
In front of 3D 480v LC

b. Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

6. Install barriers at the following entry doors to 3A and 3B EDG rooms:

a. Door 073-1

b. Door 075-ito the 3A EDG Daytank room

c. Door 072-1

d. Vital area door 3EDG3 131 to the 3B EDG radiator area

e. Door 074-1 to the 3B EDG Daytank room.

7. Post 3A MCC 480v MCC Vital Section as follows:

a. At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), place magnetic STOP signs on each cabinet door of 3A 480v MCC Vital Section (8 signs total).

b. At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), place a magnetic STOP sign on the north side facing north.

c. At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), place a magnetic STOP sign on the south side facing south.

W97:DJT/cls/mr/emc

ATTACHMENT 9 (Page 3 of 4) UNIT 3 PROTECTED EQ1JIPMENT POSTINGS DURING ENCLOSURE 2 AN]) 5 (PRESSURIZER DRAINED <10%)

8. In the 3A 4kv bus room, install signs as follows:

a. Place a protected equipment sign on the front of 3C23A (Old Sequencer Cabinet) located on the north wall of the 3A 4kv bus room.

NOTE The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could cause a bus lockout. I L_.

b. Place a protected equipment sign on the cubicle door for breaker 3AA09

c. Place a protected equipment sign on the 3AA04 cubicle door.

9. In the 3B 4kv bus room, install signs as follows:

a. Place a protected equipment sign on the front of 3C23B (Old Sequencer Cabinet) located on the north wall of the 3B 4kv bus room.

NOTE The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could cause a bus lockout. L.a a I

b. Place a protected equipment sign on the cubicle door for breaker 3AB22

c. Place a protected equipment sign on the 3AB04 cubicle door.

10. IF 3C CCW pump, OR 3C ICW pump, is required to support operability of either RHR train (i.e., any A or B ICW/CCW pump is unavailable), THEN install barriers at the following entry doors to 3D 4kv bus room:

a. Door 134-1

b. Door 134-2

11. In the CCW room, install barriers around the CCW pumps whose 4kv power supplies were protected above.

a. Record pumps protected

12. Install barriers at the top of stairway to the 3A RHR Pump Room (10 ft).

13. Install barriers at the top of stairway to the 3B RHR Pump Room (10 ft).

W97:DJT/cls/mr/emc

ATTACHMENT 9 (Page 4 of 4) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 2 AN]) 5 (PRESSURIZER DRAIi[ED <10%)

14. Install barriers on the south end of 2 of 3 CCW Hxs.

a. Record Hxs protected

15. At the Intake, install barriers around the ICW pumps whose 4kv power supplies were protected above.

a. Record pumps protected

16. In the control room, place unique information tags on the following Pump control switches identifying them as the protected/operating Train: (N/A pumps not operating)

a. 3ARHRPump

b. 3BRHRPump

c. 3A CCW Pump

d. 3B CCW Pump

e. 3CCCWPump

f. 3AICWPump

g. 3B ICW Pump

h. 3C ICW Pump

i. Record operating train Date/Time Completed: /____________

PERFORMED BY (Print) INITIALS

ATTACHMENT 10 (Page 1 of 7) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 3 AND 4 CAVITY FLOODED >23 ABOVE THE VESSEL FLANGE lu_I NOTES 1 The steps in this attachment may be performed in any order.

Due to the size of the switchyard bay, the size of the area around the transformers, and the size of the area around the CCW Heat Exchangers, those specified postings are not intended to provide a physical barrier; rather; to provide information and heightened awareness.

a If the operating train is swapped, or if components within a train are swappecJ protected equipment postings should be placed or removed as necessary to maintain the postings and equipment status consistent. The new alignment should be posted prior to deposting the previously protected equipment offsite power is from the startup transformer, THEN perform the following:

a. In the switchyard, install barriers around the startup transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the startup transformer, install barriers around the startup transformer.

2. j offsite power is from backfeed, THEN perform the following:

a. In the switchyard, install barriers around the main transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the main and aux transformers, install barriers around the main and aux transformers.

W97:DJT/cls/mr/emc

ATTACHMENT 10 (Page 2 of 7) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 3 AN]) 4 CAVITY FLOODED >23 ABOVE THE VESSEL FLANGE

3. IF 3A Train is the designated operating train, THEN post signs and/or barriers as follows:

a. Install barriers in the 3A 4kv bus room at the following locations:

(1) East side of the 3A switchgear bus from the north wall to the south wall (2) West side of the 3A switchgear bus from the north wall to the south wall (Allow access to LP34.)

b. In the 3A 4kv bus room, install signs as follows:

(1) Place a protected equipment sign on the front of 3C23A (Old Sequencer Cabinet) located on the north wall of the 3A 4kv bus room. K The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could cause a bus lockout. I _a 1 a a = a a a = I (2) Place a protected equipment sign on the cubicle door for breaker 3AA09 (3) Place a protected equipment sign on the 3AA04 cubicle door.

c. In the 3B 4kv bus room, place a protected equipment sign on the 3AB04 cubicle door.

d. IF the 480v LCs are split, THEN:

(1) Install barriers in front of 3A and 3C 480v LCs. (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

e. Install barriers at the following entry doors to 3A EDG rooms:

(1) Door 073-1 (2) Door 072-2 (3) Door 13 1-1 to the 3A EDG radiator area (4) Door 075-1 to the 3A EDG Daytank room W97:DJT/cls/mr/emc

ATTACHMENT 10 (Page 3 of 7) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 3 AND 4 CAVITY FLOODED >23 ABOVE THE VESSEL FLANGE

3. (Contd)

f. Post 3A MCC 480v MCC Vital Section as follows:

(1) At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), place magnetic STOP signs on each cabinet door of 3A 480v MCC Vital Section (8 signs total). (2) At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), place a magnetic STOP sign on the north side facing north. (3) At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), place a magnetic STOP sign on the south side facing south.

g. II? the 3A ICW or CCW pump is unavailable and the 3D bus is aligned to the 3A bus, THEN install barriers at the following entry doors to 3D 4kv bus room:

(1) Door 134-1 (2) Door 134-2

h. Install barriers at the top of stairway to the 3A RHR Pump Room (10 ft).

In the Control Room, place unique information tags on the following pump control switches identifying them as the protected/operating train: (1) 3ARHRPump (2) Select one: (N/A pump not operating)

i. 3ACCWPump OR ii. 3C CCW Pump (3) Select one: (N/A pump not operating)

i. 3AICWPump OR ii. 3C ICW Pump WQ7:DIT/cls/mr/emc

ATTACHMENT 10 (Page 4 of 7) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 3 AN]) 4 CAVITY FLOODED >23 ABOVE THE VESSEL FLANGE

4. IF 3B Train is the designated operating train, THEN post signs and/or barriers as follows:

a. Install barriers in the 3B 4kv bus room at the following locations:

(1) East side of the 3B switchgear bus from the north wall to the south wall (Permit access to the ASD panel.) (2) West side of the 3 B switchgear bus from the north wall to the south wall

b. In the 3B 4kv bus room, install signs as follows:

(1) Place a protected equipment sign on the front of 3C23B (Old Sequencer Cabinet) located on the north wall of the 3B 4kv bus room. The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could causeabus lockout. C C _ a (2) Place a protected equipment sign on the cubicle door for breaker 3AB22 (3) Place a protected equipment sign on the 3AB04 cubicle door.

c. j the 480v LCs are split, THEN:

(1) Install barriers in front of 3B and 3D 480v LCs. (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

d. Install barriers at the following entry doors to 3B EDG rooms:

(1) Door 072-1 (2) Door 072-2 (3) Vital area door 3EDG3 131 to the 3B EDG radiator area (4) Door 074-1 to the 3B EDG Daytank room.

e. fl 3B ICW or CCW pump is unavailable and the 3D bus is aligned to the 3B bus, THEN install barriers at the following entry doors to 3D 4kv bus room:

(1) Door 134-1 (2) Door 134-2

ATTACHMENT 10 (Page 5 of 7) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 3 AND 4 CAVITY FLOODED >23 ABOVE THE VESSEL FLANGE

4. (Contd)

f. IF the reactor core is less than fully loaded, THEN perform the following:

(1) j 3C 480v LC is fed from 3A 4kv bus, then post signs and/or barriers as follows: a) Install barriers in the 3A 4KV Bus room at the following locations:

1) East side of the 3A switchgear bus from the north wall to the south wall

2) West side of the 3A switchgear bus from the north wall to the south wall (Allow access to LP34.)

b) In the 3A 4kv bus room, install signs as follows:

1) Place a protected equipment sign on the front of 3C23A (Old Sequencer Cabinet) located on the north wall of the 3A 4kv bus room.

NOTE I The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could cause a bus lockout. a = = = I

2) Place a protected equipment sign on the cubicle door for breaker 3AA09 c) Install barriers at the Unit 3 480v load center rooms:

1) Install barriers in front of 3A and 3C 480v LCs.

2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

d) Install barriers at the following entry doors to 3A EDG rooms:

1) Door 073-1

2) Door 075-1 to the 3A EDG Daytank room

g. In the 3A 4kv bus room, place a protected equipment sign on the 3AA04 cubicle door.

h. Install barriers at the top of stairway to the 3B RHR Pump Room (10 fi).

Wq7fl. IT/s/mr/mr

Procedure No. Procedure

Title:

Page:

                                                                                   -            . 148 Approval Date:

0-ADM-051 Outage Risk Assessment and Control 7/22/11 ATTACHMENT 10 (Page 6 of?) UI1IT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 3 AN]) 4 CAVITY FLOODED >23 ABOVE THE VESSEL FLANGE

4. (Contd)

i. In the Control Room, place unique information tags on the following pump control switches identifying them as the protected/operating train:

(1) 3BRHRPump (2) Select one: (N/A pump not operating)

i. 3B CCW Pump OR ii. 3C CCW Pump (3) Select one: (N/A pump not operating)

i. 3BICWPump OR ii. 3CICWPump

5. IF the 480v LCs are cross-tied, ThEN post signs and/or barriers as follows:

a. Perform the following in the U3 480v load center rooms:

(1) Install barriers at the following locations: o In front of 3A 480v LC

In front of 3B 480v LC
In front of 3C 480v LC
In front of 3D 480v LC (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

6. In the CCW room, install barriers around the CCW pump whose 4kv power supply is protected above.

a. Record pump protected

7. Install barriers on the south end of 2 of 3 CCW Hxs.

a. Record Hxs protected W07fl. IT/rIc/mr/pm

ATTACHMENT 10 (Page 7 of 7) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 3 AND 4 CAVITY FLOODED >23 ABOVE THE VESSEL FLANGE

8. IF the reactor core is less than fully loaded, ThEN perform the following:

a. Install a barrier at the SFP Pump and Hx Room entry door.

b. Install a barrier at the SFP Cooling Heat Exchanger.

c. Place a magnetic stop sign on 480 V LC Breaker Cubicle 30309, SFP Cooling Pumps.

d. Place a magnetic stop sign on 480V LC Breaker Cubicle 40309, SFP Cooling Pumps.

9. At the Intake, install barriers around the ICW pump whose 4kv power supply is protected above.

a. Record pump protected

10. offsite power is from backfeed, THEN place a protected equipment sign at the safeguards racks to protect the Aux Transformer breaker.

a. 3QR42

b. 3QR43

c. 3QR44

d. 3QR45

11. the RWST is one of the two credited sources of makeup water to the Spent Fuel Pit, THEN place a magnetic stop sign on RWST purification pump breaker 30788 (U3 outage) or 40788 (U4 outage).

a. Record the breaker protected

12. IF Primary Water is one of the two credited sources of makeup water to the Spent Fuel Pit, THEN place a magnetic stop sign on ONE of the following Primary Water Pump breakers:

0885 (3A), 30664 (3B), 0884 (4A), 40664 (4B).

a. Record the breaker protected

13. IF the CVCS HUT is one of two credited sources of makeup water to the Spent Fuel Pit, THEN place a magnetic stop sign on CVCS HUT recirculation pump breaker, 0853.

Date/Time Completed: /____________ PERFORMED BY (Print) INITIALS WQ7fl. IT!I/mrIcm

ATTACHMENT 11 (Page 1 of 6) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 5 (PRESSURIZER FILLED >10%) I.. . . NOTES The steps in this attachment may be performed in any order.

Due to the size of the switchyard bay, the size of the area around the transformers and the size of the area around the CCW Heat Exchangers, those specified postings are not intended to provide a physical barrier; rather, to provide information and heightened awareness.
If the operating train is swapped or if components within a train are swappec.

protected equipment postings should be placed or removed as necessaiy to maintain the postings and equipment status consistent. The new alignment should be posted prior to deposting the previously protected equipment. _ = = I IF offsite power is from the startup transformer, THEN perform the following:

a. In the switchyard, install barriers around the startup transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the startup transformer, install barriers around the startup transformer.

2. offsite power is from backfeed, THEN perform the following:

a. In the switchyard, install barriers around the main transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the main and aux transformers, install barriers around the main and aux transformers.

W97D.iT/ds/mr/mc

ATTACHMENT 11 (Page 2 of 6) TJ1IT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 5 (PRESSURIZER FILLED >10%)

3. IF 3A Train is the designated operating train, THEN post signs and/or barriers as follows:

a. Install barriers in the 3A 4kv bus room at the following locations:

(1) East side of the 3A switchgear bus from the north wall to the south wall (2) West side of the 3A switchgear bus from the north wall to the south wall (Permit access to LP34.)

b. In the 3A 4kv bus room, install signs as follows:

(1) Place a protected equipment sign on the front of 3C23A (Old Sequencer Cabinet) located on the north wall of the 3A 4kv bus room. C = C a The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could cause a bus lockout. I 1_Ill. = C = a a 1 (2) Place a protected equipment sign on the cubicle door for breaker 3AA09 (3) Place a protected equipment sign on the 3AA04 cubicle door.

c. Perform the following in the U3 480v load center rooms:

(1) Install barriers at the following locations:

In front of 3A 480v LC
In front of 3C 480v LC (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

d. Install barriers at the following entry doors to 3A EDG rooms:

(1) Door 073-1 (2) Door 072-2 (3) Door 131-1 to the 3A EDG radiator area (4) Door 075-1 to the 3A EDG Daytank room WQ7fl. T/rIs/mr/cmr

Procedure No.: Procedure

Title:

Page:

  *                                        ..                           *.      -.                 152 Approval Date:

O-ADM-051 Outage Risk Assessment and Control 7/22/11 ATTACHMENT 11 (Page 3 of 6) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 5 (PRESSURIZER FILLED >10%) 3 (Contd)

e. Post 3A MCC 480v MCC Vital Section as follows:

(1) At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), place magnetic STOP signs on each cabinet door of 3A 480v MCC Vital Section (8 signs total). (2) At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), place a magnetic STOP sign on the north side facing north. (3) At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), place a magnetic STOP sign on the south side facing south.

f. Install barriers at top of stairway to the 3A RHR Pump Room (10 fi).

g. In the control room, place unique information tags on the following pump control switches identifiing them as the protected/operating train:

(1) 3ARNRPump (2) Select one: (N/A pump not operating)

i. 3ACCWPump OR ii. 3C CCW Pump (3) Select one: (N/A pump not operating)

i. 3AICWPump OR ii. 3CICWPump W07fl. IT/rIc/mr/mr

ATTACHMENT 11 (Page 4 of 6) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURES (PRESSURIZER FILLED >19%)

4. IF 3B Train is the designated operating train, THEN post signs and/or barriers as follows:

a. Install barriers in the 3B 4kv bus room at the following locations:

(1) East side of the 3B switchgear bus from the north wall to the south wall (Permit access to the ASD panel.) (2) West side of the 3B switchgear bus from the north wall to the south wall

b. In the 3B 4kv bus room, install signs as follows:

(1) Place a protected equipment sign on the front of 3C23B (Old Sequencer Cabinet) located on the north wall of the 3B 4kv bus room.

The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could causea bus lockout. a a a n a a a a (2) Place a protected equipment sign on the cubicle door for breaker 3AB22 (3) Place a protected equipment sign on the 3AB04 cubicle door.

c. Perform the following in the U3 480v load center rooms:

(1) Install barriers at the following locations: e Infrontof3B48OvLC

Infrontof3D48OvLC (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

d. Install barriers at the following entry doors to 3B EDG rooms:

(1) Door 072-1 (2) Door 072-2 (3) Vital area door 3EDG3 131 to the 3B EDG radiator area (4) Door 074-1 to the 3B EDG Daytank room.

e. Install barriers at top of stairway to the 3B RHR Pump Room (10 11).

W7fl. ITiI/mr/mr

ATTACHMENT 11 (Page 5 of 6) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 5 (PRESSURIZER FILLED >10%)

4. (Contd)

f. In the control room, place unique information tags on the following pump control switches identifying them as the protected/operating train:

(1) 3BRHRPump (2) Select one: (N/A pump not operating)

i. 3BCCWPump OR ii. 3CCCWPump (3) Select one: (N/A pump not operating)

i. 3B ICW Pump OR ii. 3C ICW Pump

5. the 3C CCW or ICW pump is running and required for operability of the protected RHR train, THEN install barriers at the following entry doors to the 3D 4kv bus room.

a. Door 134-1

b. Door 134-2 WQ7fl. IT/cIs/mr/Amr

ATTACHMENT 11 (Page 6 of 6) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 5 (PRESSURIZER FILLED >10%)

6. In the CCW room, install barriers around the CCW pump whose 4kv power supply is protected above.

a. Record pump protected

7. Install barriers on the south end of 2 of 3 CCW Hxs.

a. Record Hxs protected

8. At the intake, install barriers around the ICW pump whose 4kv power supply is protected above.

a. Record pump protected Date/Time Completed: /_____________

PERFORMED BY (Print) INITIALS

ATTACHMENT 12 (Page 1 of 5) UNIT 3 PROTECTED EQUIPMENT POSTINGS D1JRIiNG ENCLOSURE 6 NOTES a The steps in this attachment may be performed in any order.

Due to the size of the switchyard bay, the size of the area around the transformers, and the size of the area around the CCW Heat Exchangers, those specified postings B are not intended to provide a physical barrier; rather; to provide information and heightened awareness.

If the operating train is swappecJ or if components within a train are swapped, protected equipment postings should be placed or removed as necessaiy to maintain the postings and equipment status consistent. The new alignment should be posted prior to deposting the previously protected equipment. B offsite power is from the startup transformer, THEN perform the following:

a. In the switchyard, install barriers around the startup transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the startup transformer, install barriers around the startup transformer.

2. j offsite power is from backfeed, THEN perform the following:

a. In the switchyard, install barriers around the main transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the main and aux transformers, install barriers around the main and aux transformers.

IIç7*fl IT/,k/mr/pmr

ATTACHMENT 12 (Page 2 of 5) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 6

3. IF 3A Train is the designated operating train, THEN post signs and/or barriers as follows:

a. Install barriers in the 3A 4kv bus room at the following locations:

(1) East side of the 3A switchgear bus from the north wall to the south wall (2) West side of the 3A switchgear bus from the north wall to the south wall (Permit access to LP34.)

b. In the 3A 4kv bus room, install signs as follows:

(1) Place a protected equipment sign on the front of 3C23A (Old Sequencer Cabinet) located on the north wall of the 3A 4kv bus room. I The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could cause a bus lockout. (2) Place a protected equipment sign on the cubicle door for breaker 3AA09 (3) Place a protected equipment sign on the 3AA04 cubicle door.

c. Perform the following in the U3 480v load center rooms:

(1) Install barriers at the following locations: In front of 3A 480v LC o In front of 3C 480v LC (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

d. Install barriers at the following entry doors to 3A EDG rooms:

(1) Door 073-1 (2) Door 072-2 (3) Door 13 1-1 to the 3A EDG radiator area (4) Door 075-ito the 3A EDG Daytank room W97:DJT/cls/mr/emc

ATTACHMENT 12 (Page 3 of 5) IJ1NIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 6

3. (Contd)

e. Post 3A MCC 480v MCC Vital Section as follows:

(1) At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), place magnetic STOP signs on each cabinet door of 3A 480v MCC Vital Section (8 signs total). (2) At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), place a magnetic STOP sign on the north side facing north. (3) At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), place a magnetic STOP sign on the south side facing south.

f. IF the 3A ICW or CCW pump is unavailable and the 3D bus is aligned to the 3A bus, THEN install barriers at the following entry doors to 3D 4kv bus room:

(1) Door 134-1 (2) Door 134-2

g. In the control room, place unique information tags on the following pump control switches identifjing them as the protected/operating train:

(1) 3ARHRPump (2) Select one: (N/A pump not operating)

i. 3ACCWPump OR ii. 3CCCWPump (3) Select one: (N/A pump not operating)

i. 3AICWPump OR ii. 3CICWPump Wq7nIT/rIs/mrkmr

ATTACHMENT 12 (Page 4 of 5) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 6

4. IF 3B Train is the designated operating train, THEN post signs and/or barriers as follows:

a. Install barriers in the 3B 4kv bus room at the following locations:

(1) East side of the 3B switchgear bus from the north wall to the south wall (Permit access to the ASD panel.) (2) West side of the 3B switchgear bus from the north wall to the south wall

b. In the 3B 4kv bus room, install signs as follows:

(1) Place a protected equipment sign on the front of 3C23B (Old Sequencer Cabinet) located on the north wall of the 3B 4kv bus room.

                                       =                               =   =             
                                                 =

The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could K causeabuslockout. K a a = = = = a = a I (2) Place a protected equipment sign on the cubicle door for breaker 3AB22 (3) Place a protected equipment sign on the 3AB04 cubicle door.

c. Perform the following in the U3 480v load center rooms:

(1) Install barriers at the following locations: o In front of 3B 480v LC o In front of 3D 480v LC (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

d. Install barriers at the following entry doors to 3B EDG rooms:

(1) Door 072-1 (2) Door 072-2 (3) Vital area door 3EDG3 131 to the 3B EDG radiator area (4) Door 074-1 to the 3B EDG Daytank room.

e. IF the 3B ICW or CCW pump is unavailable and the 3D bus is aligned to the 3B bus, THEN install barriers at the following entry doors to 3D 4kv bus room:

(1) Door 134-1 (2) Door 134-2 W97:D.iT/clslmr/emc

ATTACHMENT 12 (Page 5 of 5) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 6 4.f. (Contd)

f. In the control room, place unique information tags on the following pump control switches identifying them as the protected/operating train:

(1) 3BRHRPump (2) Select one: (N/A pump not operating)

i. 3BCCWPump OR ii. 3C CCW Pump (3) Select one: (N/A pump not operating)

i. 3B ICW Pump OR ii. 3C ICW Pump

5. In the CCW room, install barriers around the CCW pump whose 4kv power supply is protected above.

a. Record pump protected

6. Install barriers at the top of the stairway to the running protected RHR pump room (10 ft).

a. Record RHR Pump Room protected 7 Install barriers on the south end of 2 of 3 CCW Hxs.

a. Record Hxs protected 8 At the Intake, install barriers around the ICW pump whose 4kv power supply is protected above.

a. Record pump protected Date/Time Completed: /

PERFORMED BY (Print) LNITIALS W97DJT/eIs/mr/emc

ATTACHMENT 13 (Page 1 of 6) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 7 RCS DEFUELED a = a a a a The steps in this attachment may be performed in any order Due to the size of the switchyard bay, the size of the area around the transformers, and the size of the area around the CCW Heat Exchangers, those specified postings are not intended to provide a physical barrier; rather; to provide information and heightened awareness.

If the operating train is swapped or if components within a train are swapped, protected equipment postings should be placed or removed as necessary to maintain the postings and equipment status consistent. The new alignment should be posted prior to deposting the previously protected equipment.

a a c a a a offsite power is from the startup transformer, THEN perform the following:

a. In the switchyard, install barriers around the startup transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the startup transformer, install barriers around the startup transformer.

2. IF offsite power is from backfeed, THEN perform the following:

a. In the switchyard, install barriers around the main transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the main and aux transformers, install barriers around the main and aux transformers.

W97:DJT/cls/mr/emc

ATTACHMENT 13 (Page 2 of 6) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 7 RCS DEFUELED

3. 3C 480v LC is fed from 3A 4kv bus, THEN post signs and/or barriers as follows:

a. Install barriers in the 3A switchgear bus room at the following locations:

(1) East side of the 3A switchgear bus from the north wall to the south wall (2) West side of the 3A switchgear bus from the north wall to the south wall (Permit access to LP34.)

b. In the 3A 4kv bus room, install signs as follows:

(1) Place a protected equipment sign on the front of 3C23A (Old Sequencer Cabinet) located on the north wall of the 3A 4kv bus room.

U The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could cause a bus lockout. L.. I (2) Place a protected equipment sign on the cubicle door for breaker 3AA09. (3) Place a protected equipment sign on the 3AA04 cubicle door.

c. In the 3B 4kv Bus Room, place a Protected Equipment sign on the 3AB04 Cubicle Door.

d. Perform the following in the U3 480v load center rooms:

(1) Install barriers at the following locations:

In front of 3A 480v LC
In front of 3C 480v LC (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

(3) IF load centers are cross-tied, THEN install barriers at the following locations:

Infrontof3B48OvLC e In front of 3D 480v LC W97fl.IT/c!s/mr/emc

ATTACHMENT 13 (Page 3 of 6) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 7 RCS DEFUELE])

3. (Contd)

e. Install barriers at the following entry doors to 3A EDG rooms:

(1) Door 073-1 (2) Door 072-2 (3) Door 13 1-i to the 3A EDG radiator area (4) Door 075-ito the 3A EDG Daytank room

f. Post 3A MCC 480v MCC Vital Section as follows:

(1) At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), place magnetic STOP signs on each cabinet door of 3A 480v MCC Vital Section (8 signs total). (2) At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), place a magnetic STOP sign on the north side facing north. (3) At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), place a magnetic STOP sign on the south side facing south.

g. IF the 3A ICW or CCW pump is unavailable and the 3D bus is aligned to the 3A bus, THEN install barriers at the following entry doors to 3D 4kv bus room:

(1) Door 134-1 (2) Door 134-2

h. In the control room, place unique information tags on the following pump control switches identifing them as the protected/operating train:

(1) Select one: (N/A pump not operating)

i. 3ACCWPump OR ii. 3CCCWPump (2) Select one: (N/A pump not operating)

i. 3A ICW Pump OR ii. 3C ICW Pump Wq7fl. ITIIImricmn

ATTACHMENT 13 (Page 4 of 6) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 7 RCS DEFUELED

4. IF 3C 480v LC is fed from 3D LC, ThEN post signs and/or barriers as follows:

a. Install barriers in the 3B 4KV Bus room at the following locations:

(1) East side of the 3B switchgear bus from the north wall to the south wall (Permit access to the ASD panel.) (2) West side of the 3B switchgear bus from the north wall to the south wall

b. In the 3B 4kv bus room, install signs as follows:

(1) Place a protected equipment sign on the front of 3C23B (Old Sequencer Cabinet) located on the north wall of the 3B 4kv bus room. a = a The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could cause a bus lockout. a a a a a a a I (2) Place a protected equipment sign on the cubicle door for breaker 3AB22 (3) Place a protected equipment sign on the 3AB04 cubicle door.

c. In the 3A 4kv Bus Room, place a Protected Equipment sign on the 3AA04 Cubicle Door.

d. Perform the following in the U3 480v load center rooms:

(1) Install barriers at the following locations:

In front of 3A 480v LC
Infrontof3B48OvLC
Infrontof3C48OvLC
Infrontof3D48OvLC (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

WQ7n. IT! /mr!mr

ATTACHMENT 13 (Page 5 of 6) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 7 RCS DEFIJELED

4. (Contd)

e. Install barriers at the following entry doors to 3B EDG rooms:

(1) Door 072-1 (2) Door 072-2 (3) Vital area door 3EDG3 131 to the 3B EDG radiator area (4) Door 074-1 to the 3B EDG Daytank room.

f. IF 3B ICW or CCW pump is unavailable and the 3D bus is aligned to the 3B bus, THEN install barriers at the following entry doors to 3D 4kv bus room:

(1) Door 134-1 (2) Door 134-2

g. In the control room, place unique information tags on the following pump control switches identifying them as the protected/operating train:

(1) Select one: (N/A pump not operating)

i. 3BCCWPump OR ii. 3CCCWPump (2) Select one: (N/A pump not operating)

i. 3B ICW Pump OR ii. 3C ICW Pump

5. In the CCW room, install barriers around the CCW pump whose 4kv power supply is protected above.

a. Record pump protected

6. Install barriers on the south end of 1 of 3 CCW Hxs.

a. Record Hxs protected

ATTACHMENT 13 (Page 6 of 6) UNIT 3 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 7 RCS DEFUELED

7. At the SFP pump and Hx room, install a barrier at the entry door.

8. At the Intake, install barriers around the ICW pump whose 4kv power supply is protected above.

a. Record pump protected

9. IF offsite power is from backfeed, THEN place a protected equipment sign at the safeguards racks to protect the Aux Transformer breaker.

a. 3QR42

b. 3QR43

c. 3QR44

d. 3QR45

10. Place a magnetic stop sign on 480 V LC Breaker Cubicle 40309, SFP Cooling Pumps.

11. Place a magnetic stop sign on 480V LC Breaker Cubicle 30309, SFP Cooling Pumps.

12. IF the RWST is one of the two credited sources of makeup water to the Spent Fuel Pit, THEN place a magnetic stop sign on RWST purification pump breaker 30788 (U3 outage) or 40788 (U4 outage).

a. Record the breaker protected

13. IF Primary Water is one of the two credited sources of makeup water to the Spent Fuel Pit, THEN place a magnetic stop sign on ONE of the following Primary Water Pump breakers:

0885 (3A), 30664 (3B), 0884 (4A), 40664 (4B).

a. Record the breaker protected

14. IF the CVCS HUT is one of two credited sources of makeup water to the Spent Fuel Pit, THEN place a magnetic stop sign on CVCS HUT recirculation pump breaker, 0853.

Date/Time Completed: /____________ PERFORMED BY (Print) INITIALS W97:DJT/cls/mr/emc

ATTACHMENT 14 (Page 1 of 6) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 1 NOTES

The steps in this attachment may be performed in any order.
Due to the size of the switchyard bay, the size of the area around the transformers, and the size of the area around the CCW Heat Exchangers, those specified postings are not intended to provide a physical barrier; rather; to provide information and heightened awareness.
If the operating train is swappecJ or if components within a train are swapped protected equipment postings should be placed or removed as necessary to maintain the postings and equipment status consistent. The new alignment should be posted prior to deposting the previously protected equipment.

1. IF offsite power is from the startup transformer, THEN perform the following:

a. In the switchyard, install barriers around the startup transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the startup transformer, install barriers around the startup transformer.

2. IF offsite power is from backfeed, THEN perform the following:

a. In the switchyard, install barriers around the main transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the main and aux transformers, install barriers around the main and aux transformers.

W97:DJT/cls/mr/emc

ATTACHMENT 14 (Page 2 of 6) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 1

3. 4A Train is the designated operating train, THEN post signs and/or barriers as follows:

a. Install barriers in the 4A 4KV bus room at the following locations:

(1) East side of the 4A switchgear bus from the north wall to the south wall (2) West side of the 4A switchgear bus from the north wall to the south wall (Permit access to LP44.)

b. Perform the following in the U4 480v load center rooms:

(1) Install barriers at the following locations: o In front of 4A 480v LC In front of 4C 480v LC (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

c. Install barriers at the following entry doors to 4A EDO rooms:

(1) Door 138-1 (2) Door 133-2 (3) Door 141-1 to the 4A EDO DOTP area (4) Door 138-2 (5) Door 140-1 (6) Door 139-2

d. IF the 4A ICW or CCW pump is unavailable and the 4D bus is aligned to 4A bus, THEN install barriers at the following entry doors to 4D 4kv bus room:

(1) Door 139-1 (2) Door 139-2 (3) Door 135-2

ATTACHMENT 14 (Page 3 of 6) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 1

3. (Contd

e. In the control room, place unique information tags on the following pump control switches identifying them as the protected/operating train:

(1) 4ARHRPump (2) Select one: (N/A pump not operating)

i. 4ACCWPump OR ii. 4C CCW Pump (3) Select one: (N/A pump not operating)

i. 4A ICW Pump OR ii. 4C ICW Pump

4. IF 4B Train is the designated operating train, THEN post signs and/or barriers as follows:

a. Install barriers in the 4B 4KV bus room at the following locations:

(1) East side of the 4B switchgear bus from the north wall to the south wall (Permit access to the ASD panel.) (2) West side of the 4B switchgear bus from the north wall to the south wall

b. Perform the following in the U4 480v load center rooms:

(1) Install barriers at the following locations:

In front of 4B 480v LC
In front of 4D 480v LC (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

Wq7fl. IT//mr/m

ATTACHMENT 14 (Page 4 of 6) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 1

4. (Contd)

c. Install barriers at the following entry doors to 48 EDG rooms:

(1) Door 133-1 (2) Door 133-2 (3) Door 136-1 to the 4B EDG DOTP area (4) Door 133-3 (5) Door 135-2 (6) Door 135-1 (7) Door 134-2

d. IF the 4B ICW or CCW pump is unavailable and the 4D bus is aligned to 4B bus, THEN install barriers at the following entry doors to 4D 4kv bus room:

(1) Door 139-1 (2) Door 139-2 (3) Door 135-2

e. In the control room, place unique information tags on the following pump control switches identifying them as the protected/operating train:

(1) 4B RHR Pump (2) Select one: (N/A pump not operating)

i. 4B CCW Pump OR ii. 4C CCW Pump (3) Select one: (N/A pump not operating)

i. 4B ICW Pump OR ii. 4C ICW Pump W97:DJT/cls/mrtemc

ATTACHMENT 14 (Page 5 of 6) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 1

5. In the 4A 4KV Bus room, install signs as follows:

a. Place a protected equipment sign on the front of 4C23A (Old Sequencer Cabinet) located on the north wall of the 4A 4KV Bus room.

rma a a a a a a a a a The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could cause a bus lockout. a a a a a a 1

b. Place a protected equipment sign on the cubicle door for breaker 4AA09.

c. Place a protected equipment sign on the 4AA04 cubicle door.

6. Perform the following in the 4B 4KV Bus room:

a. Place a protected equipment sign on the front of 4C23B (Old Sequencer Cabinet) located on the north wall of the 4B 4KV Bus room.

NOTE The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could I I cause a bus lockout. a a a a a a a a a

b. Place a protected equipment sign on the cubicle door for breaker 4AB22

c. Place a protected equipment sign on the 4AB04 cubicle door.

W97:DJT/cls/mr/emc

Procedure No.: Procedure

Title:

Page:

                                                                                           .      172-Approval Date:

O-ADM-051 Outage Risk Assessment and Control 7/22/11 ATTACHMENT 14 (Page 6 of 6) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 1

7. In the CCW room, install barriers around the CCW pump whose 4kv power supply is protected above.

a. Record pump protected

8. Install barriers at the top of stairway to running protected RHR Pump Room (10 fi)

a. Record R}IR Pump Room protected

9. Install barriers on the north end of 2 of 3 CCW Hxs.

a. Record Hxs protected

10. At the Intake, install barriers around the ICW pump whose 4kv power supply is protected above.

a. Record pump protected Date/Time Completed: /____________

PERFORMED BY (Print) INITIALS W97:DJT/cls/mr/emc

ATTACHMENT 15 (Page 1 of 4) UNIT 4 PROTECTED EQUIPMENT POSTING DURING ENCLOSURE 2 AN]) 5 (PRESSURIZER DRAINED <10%) NOTES The steps in this attachment may be performed in any order.

Due to the size of the switchyard bay, the size of the area around the transformers, and the size of area around the COW Heat Exchangers, those specified postings are not intended to provide a physical barrier; rather; to provide information and heightened awareness.

If the operating train is swapped, or if components within a train are swappecJ protected equipment postings should be placed or removed as necessary to maintain the postings and equipment status consistent. The new alignment should be posted prior to deposting the previously protected equipment. a offsite power is from the startup transformer, THEN perform the following:

a. In the switchyard, install barriers around the startup transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the startup transformer, install barriers around the startup transformer.

2. IF offsite power is from backfeed, THEN perform the following:

a. In the switchyard, install barriers around the main transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the main and aux transformers, install barriers around the main and aux transformers.

W97:DJT/cis/mrlemc

Procedure No. Procedure

Title:

Page:

                                              -                                                    174 Approval Date:

O-ADM-051 Outage Risk Assessment and Control 7/22/11 ATTACHMENT 15 (Page 2 of 4) UNIT 4 PROTECTED EQUIPMENT POSTING DURING ENCLOSURE 2 ANT) 5 (PRESSURIZER DRAINED <10%)

3. Install barriers in the 4A and 4B 4KV Bus rooms as follows:

a. Install barriers in the 4A 4KV Bus room at the following locations:

(1) East side of the 4A switchgear bus from the north wall to the south wall (2) West side of the 4A switchgear bus from the north wall to the south wall (Permit access to LP44.)

b. Install barriers in the 4B 4KV Bus room at the following locations:

(1) East side of the 4B switchgear bus from the north wall to the south wall (Permit access to the ASD panel.) (2) West side of the 4B switchgear bus from the north wall to the south wall

4. Perform the following in the U4 480v load center rooms:

a. Install barriers at the following locations:

In front of 4A 480v LC
In front of 4B 480v LC
In front of 4C 480v LC
In front of 4D 480v LC

b. Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

5. Install barriers at the following entry doors to 4A and 4B EDG rooms:

a. Door 138-1

b. Door 133-1

c. Door 14 1-1 to the 4A EDG DOTP area

d. Door 13 6-1 to the 4B EDG DOTP area

e. Door 138-2

f. Door 133-3 W7fl. IT/r[/mr/mc

ATTACHMENT 15 (Page 3 of 4) UNIT 4 PROTECTED EQUIPMENT POSTING DURING ENCLOSURE 2 AN]) 5 (PRESSURIZER DRAINED <10%)

6. In the 4A 4KV Bus room, install signs as follows:

a. Place a protected equipment sign on the front of 4C23A (Old Sequencer Cabinet) located on the north wall of the 4A 4KV Bus room.

The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could cause a bus lockout. 11 L _ I

b. Place a protected equipment sign on the 4AA09 cubicle door.

c. Place a protected equipment sign on the 4AA04 cubicle door.

7. In the 4B 4KV Bus room, install signs as follows:

a. Place a protected equipment sign on the front of 4C23B (Old Sequencer Cabinet) located on the north wall of the 4B 4KV Bus room.

[NOTEj The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could i cause a bus lockout.

b. Place a protected equipment sign on the cubicle door for breaker 4AB22

c. Place a protected equipment sign on the 4AB04 cubicle door.

8. IF 4C CCW pump, OR 4C ICW pump, is required to support operability of either RHR train (i.e., any A or B ICW/CCW pump is unavailable), THEN install barriers at the following entry doors to 4D 4kv bus room:

a. Door 139-1

b. Door 139-2

c. Door 135-2 AIQ7fl tTkk,II-,,.-

ATTACHMENT 15 (Page 4 of 4) UNIT 4 PROTECTED EQUIPMENT POSTING DJJRING ENCLOSURE 2 ANI) 5 (PRESSURIZER DRAINED <10%)

9. In the CCW room, install barriers around the CCW pumps whose 4kv power supplies were protected above.

a. Record pumps protected

10. Install barriers at the top of stairway to the 4A RHR Pump Room (10 ft).

11. Install barriers at the top of stairway to the 4B RHR Pump Room (10 fi).

12. Install barriers on the north end of 2 of 3 CCW Hxs.

a. Record Hxs protected

13. At the Intake, install barriers around the ICW pumps whose 4kv power supplies were protected above.

a. Record pumps protected

14. In the control room. place unique information tags on the following pump control switches identifying them as the protected/operating train: (N/A pumps not operating)

a. 4ARHRPump

b. 4B RHR Pump

c. 4A CCW Pump

d. 4B CCW Pump

e. 4C CCW Pump

f. 4A ICW Pump

g. 4BICWPump

h. 4C ICW Pump

i. Record operating train Date/Time Completed: /____________

PERFORMED BY (Print) INITIALS

ATTACHMENT 16 (Page 1 of 8) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 3 AND 4 CAVITY FLOODED >2Y ABOVE THE VESSEL FLANGE NOTES

The steps in this attachment may be performed in any order.
Due to the size of the switchyard bay, the size of the area around the transformers, and the size of the area around the CCW Heat Exchangers, those specified postings are not intended to provide a physical barrier; rather; to provide information and heightened awareness.
If the operating train is swapped or if components within a train are swapped protected equipment postings should be placed or removed as necessaiy to maintain the postings and equipment status consistent. The new alignment should be posted prior to deposting the previously protected equipment.

I _ = a a j offsite power is from the startup transformer, THEN perform the following:

a. In the switchyard, install barriers around the startup transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the startup transformer, install barriers around the startup transformer.

2. IF offsite power is from backfeed, THEN perform the following:

a. In the switchyard, install barriers around the main transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the main and aux transformers, install barriers around the main and aux transformers.

W7fl. IT/rk/mr/mr

Procedure No.: Procedure

Title:

Page: 17& Approval Date: O-ADM-051 Outage Risk Assessment and Control 7/22/11 ATTACHMENT 16 (Page 2 of 8) UNIT 4 PROTECTED EQUiPMENT POSTINGS DURING ENCLOSURE 3 AND 4 CAVITY FLOODED >23 ABOVE THE VESSEL FLANGE

3. IF 4A train is the designated operating train, THEN post signs and/or barriers as follows:

a. Install barriers in the 4A 4KV Bus room at the following locations:

(1) East side of the 4A switchgear bus from the north wall to the south wall (2) West side of the 4A switchgear bus from the north wall to the south wall (Permit access to LP44.)

b. In the 4A 4KV bus room, install signs as follows:

(1) Place a protected equipment sign on the front of 4C23A (Old Sequencer Cabinet) located on the north wall of the 4A 4KV bus room. The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could cause a bus lockout. (2) Place a protected equipment sign on the cubicle door for breaker 4AA09. (3) Place a protected equipment sign on the 4AA04 cubicle door.

c. In the 4B 4kv bus room, place a protected equipment sign on the 4AB04 cubicle door.

d. IF the 480v LCs are split, THEN:

(1) Install barriers in front of 4A and 4C 480v LCs. (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

e. IF the reactor core is less than fully loaded, THEN place a magnetic stop sign on 480V LC Breaker Cubicle 40309, SFP Cooling Pumps (4P212A1B).

f. Install barriers at the following entry doors to 4A EDG rooms:

(1) Door 1381 (2) Door 133-2 (3) Door 14 1-1 to the 4A EDG DOTP area (4) Door 138-2 (5) Door 140-1 (6) Door 139-2 A1O7fl ITiI/r,,rhn

ATTACHMENT 16 (Page 3 of 8) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 3 AN]) 4 CAVITY FLOODED >23 ABOVE THE VESSEL FLANGE

3. (Contd)

g. IF the 4A ICW or CCW pump is unavailable and the 4D bus is aligned to the 4A bus, THEN install barriers at the following entry doors to 4D 4kv bus room:

(1) Door 139-1 (2) Door 139-2 (3) Door 135-2

h. Install barriers at the top of stairway to the 4A RHR pump room.

In the Control Room, place unique information tags on the following pump control switches identifying them as the protected/operating train: (1) 4ARHRPump (2) Select one: (N/A pump not operating)

i. 4ACCWPump OR ii. 4C CCW Pump (3) Select one: (N/A pump not operating)

i. 4A ICW Pump OR ii. 4C ICW Pump W97:DJT/cls/mr/emc

Procedure No.: Procedure

Title:

Page:

                                   -                                                                    18t1 Approval Date:

O-ADM-051 Outage Risk Assessment and Control 7/22/11 ATTACHMENT 16 (Page 4 of 8) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 3 AN]) 4 CAVITY FLOODED >23 ABOVE THE VESSEL FLANGE

4. IF 4B Train is the designated operating train, THEN post signs and/or barriers as follows:

a. Install barriers in the 4B 4KV Bus room at the following locations:

(1) East side of the 4B switchgear bus from the north wall to the south wall (Permit access to the ASD panel.) (2) West side of the 4B switchgear bus from the north wall to the south wall

b. In the 4B 4KV Bus room, install signs as follows:

(1) Place a protected equipment sign on the front of 4C23B (Old Sequencer Cabinet) located on the north wall of the 4B 4KV Bus room. The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could cause a bus lockout. I L.a = = = = = I (2) Place a protected equipment sign on the cubicle door for breaker 4AB22 (3) Place a protected equipment sign on the 4AB04 cubicle door.

c. IF the 480v LCs are split, THEN:

(1) Install barriers in front of 4B and 4D 480v LCs. (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

d. Install barriers at the following entry doors to 4B EDG rooms:

(1) Door 133-1 (2) Door 133-2 (3) Door 13 6-1 to the 4B EDG DOTP area. (4) Door 133-3 (5) Door 135-2 (6) Door 134-2 (7) Door 135-1

ATTACHMENT 16 (Page 5 of 8) U41T 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 3 AN]) 4 CAVITY FLOODED >23 ABOVE THE VESSEL FLANGE

4. (Contd)

e. j the 4B ICW or CCW pump is unavailable and the 4D bus is aligned to the 4B bus, THEN install barriers at the following entry doors to 4D 4kv bus room:

(1) Door 139-1 (2) Door 139-2 (3) Door 135-2

f. IF the reactor core is less than fully loaded, THEN perform the following:

(1) j 4C 480v LC is fed from 4A 4kv bus, then post signs and/or barriers as follows: a) Install barriers in the 4A 4KV bus room at the following locations:

1) East side of the 4A switchgear bus from the north wall to the south wall

2) West side of the 4A switchgear bus from the north wall to the south wall (Permit access to LP44.)

NOTE I The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could causeabuslockout. I a = a a a a I b) In the 4A 4KV bus room, install signs as follows:

1) Place a protected equipment sign on the front of 4C23A (Old Sequencer Cabinet) located on the north wall of the 4A 4KV bus room.

2) Place a protected equipment sign on the cubicle door for breaker 4AA09.

c) Install barriers at the following locations in the Unit 4 480v load center rooms:

1) Install barriers in front of 4A, 4B and 4C, 4D 480v LCs.

2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

W97: DJT/eIs/mr/mc

ATTACHMENT 16 (Page 6 of 8) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 3 AN]) 4 CAVITY FLOODED >23 ABOVE THE VESSEL FLANGE 4.f.(1) (Contd) d) Install barriers at the following entry doors to 4A EDG rooms:

1) Door 138-1

2) Door 14 1-1 to the 4A EDG DOTP area

3) Door 138-2

4) Door 139-2

g. In the 4A 4kv bus room, place a protected equipment sign on the 4AA04 cubicle door.

h. Install barriers at the top of stairway to the 4B RFTR pump room.

In the Control Room, place unique information tags on the following pump control switches identifying them as the protected/operating train: (1) 4BRHRPump (2) Select one: (N/A pump not operating)

i. 4BCCWPump OR ii. 4C CCW Pump (3) Select one: (N/A pump not operating)

i. 4B ICW Pump OR ii. 4C ICW Pump

5. IF the 480v LCs are cross-tied, THEN post signs and/or barriers as follows:

a. Install barriers at the following locations in the Unit 4 480v load center rooms:

(1) Install barriers in front of 4A, 4B and 4C, 4D 480v LCs. (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms. WQ7fl. IT/nI/mr/mn

ATTACHMENT 16 (Page 7 of 8) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 3 ANT) 4 CAVITY FLOODED >23 ABOVE THE VESSEL FLANGE

6. In the CCW room, install barriers around the CCW pump whose 4kv power supply is protected above.

a. Record pump protected

7. Install barriers on the north end of 2 of 3 CCW Hxs.

a. Record Hxs protected

8. IF the reactor core is less than fully loaded, THEN perform the following:

a. Install a barrier at the SFP pump and Hx room entry door.

b. Install a barrier at the SFP Cooling Heat Exchanger.

c. Place a magnetic stop sign on 480V LC Breaker Cubicle 40309, SFP Cooling Pumps

d. Place a magnetic stop sign on 480 V LC Breaker Cubicle 30309, SFP Cooling Pumps.

9. At the Intake, install barriers around the ICW pump whose 4kv power supply is protected above.

a. Record pump protected

10. j offsite power is from backfeed, THEN place a protected equipment sign at the safeguards racks to protect the Aux Transformer breaker.

a. 4QR42

b. 4QR43

c. 4QR44

d. 4QR45

11. IF the RWST is one of the two credited sources of makeup water to the Spent Fuel Pit, THEN place a magnetic stop sign on RWST purification pump breaker 30788 (U3 outage) or 40788 (U4 outage).

a. Record the breaker protected AiO7fl ITfrI/nr/rnr

ATTACHMENT 16 (Page 8 of 8) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 3 ANI) 4 CAVITY FLOODED >23 ABOVE THE VESSEL FLANGE

12. Primary Water is one of the two credited sources of makeup water to the Spent Fuel Pit, THEN place a magnetic stop sign on ONE of the following Primary Water Pump breakers:

0885 (3A), 30664 (3B), 0884 (4A), 40664 (4B).

a. Record the breaker protected

13. the CVCS HUT is one of two credited sources of makeup water to the Spent Fuel Pit, TKEN place a magnetic stop sign on CVCS HUT recirculation pump breaker, 0853.

Date/Time Completed: /____________ PERFORMED BY (Print) INITIALS AJO7fl IT!,4irnrkn,,.

ATTACHMENT 17 (Page 1 of 5) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 5 (PRESSURIZER FILLED >10%) NOTES 1 The steps in this attachment may be performed in any order. o Due to the size of the switchyard bay, the size of the area around the transformers, and the size of the area around the CCW Heat Exchangers, those specified postings are not intended to provide a physical barrier; rather; to provide information and heightened awareness.

If the operating train is swapped, or if components within a train are swappeci protected equipment postings should be placed or removed as necessary to maintain the postings and equipment status consistent. The new alignment should be posted prior to deposting the previously protected equipment.

a I offsite power is from the startup transformer, THEN perform the following:

a. In the switchyard, install barriers around the startup transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the startup transformer, install barriers around the startup transformer.

2. IF offsite power is from backfeed, THEN perform the following:

a. In the switchyard, install barriers around the main transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the main and aux transformers, install barriers around the main and aux transformers.

W97:DJT/cls/mr/emc

ATTACHMENT 17 (Page 2 of 5) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 5 (PRESSURIZER FILLED >10%)

3. IF 4A Train is the designated operating train, THEN post signs and/or barriers as follows:

a. Install barriers at in the 4A 4KV Bus room at the following locations:

(1) East side of the 4A switchgear bus from the north wall to the south wall (2) West side of the 4A switchgear bus from the north wall to the south wall (Permit access to LP44.)

b. In the 4A 4KV Bus room, install signs as follows:

(1) Place a protected equipment sign on the front of 4C23A (Old Sequencer Cabinet) located on the north wall of the 4A 4KV Bus room. a a The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could causeabuslockout. I a a I (2) Place a protected equipment sign on the cubicle door for breaker 4AA09 (3) Place a protected equipment sign on the 4AA04 cubicle door.

c. Perform the following in the U4 480v load center rooms:

(1) Install barriers at the following locations: In front of 4A 480v LC o Infrontof4C48OvLC (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

d. Install barriers at the following entry doors to 4A EDG rooms:

(1) Door 138-1 (2) Door 133-2 (3) Door 14 1-1 to the 4A EDG DOTP area (4) Door 138-2 (5) Door 140-1 (6) Door 139-2

e. Install barriers at the top of stairway to the 4A R}{R Pump Room (10 fi).

AR7fl T/,.I&r,,rk.,,,.

Procedure No.: Procedure

Title:

Page: 187 Approval Date: O-ADM-051 Outage Risk Assessment and Control 7/22/11 ATTACHMENT 17 (Page 3 of 5) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 5 (PRESSURIZER FILLED >10%)

3. (Contd)

f. In the control room, place unique information tags on the following pump control switches identifying them as the protected/operating train:

(1) 4ARHRPump (2) Select one: (N/A pump not operating)

i. 4ACCWPump OR ii. 4C CCW Pump (3) Select one: (N/A pump not operating)

i. 4A ICW Pump OR ii. 4C ICW Pump

4. IF 4B Train is the designated operating train, THEN post signs and/or barriers as follows:

a. Install barriers in the 4B 4KV Bus room at the following locations:

(1) East side of the 4B switchgear bus from the north wall to the south wall (Permit access to the ASD panel.) (2) West side of the 4B switchgear bus from the north wall to the south wall

b. In the 4B 4KV Bus room, install signs as follows:

(1) Place a protected equipment sign on the front of 4C23B (Old Sequencer Cabinet) located on the north wall of the 4B 4KV Bus room. NOTE I I The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could I cause a bus lockout. I (2) Place a protected equipment sign on the cubicle door for breaker 4AB22 (3) Place a protected equipment sign on the 4AB04 cubicle door.

ATTACHMENT 17 (Page 4 of 5) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 5 (PRESSURIZER FILLED >10%)

4. (Contd)

c. Perform the following in the U4 480v load center rooms:

(1) Install barriers at the following locations: o In front of 4B 480v LC o In front of 4D 480v LC (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

d. Install barriers at the following entry doors to 4B EDG rooms:

(1) Door 133-1 (2) Door 133-2 (3) Door 136-1 to the 4B EDG DOTP area (4) Door 133-3 (5) Door 135-2 (6) Door 134-2 (7) Door 135-1

e. Install barriers at the top of stairway to the 4B RHR Pump Room (10 ft).

f. In the control room, place unique information tags on the following pump control switches identifying them as the protected/operating train:

(1) 4B RHR Pump (2) Select one: (N/A pump not operating)

i. 4B CCW Pump OR ii. 4C CCW Pump (3) Select one: (N/A pump not operating)

i. 4B ICW Pump OR ii. 4C ICW Pump W97:DJT/cls/mr/emc

Procedure No.: Procedure

Title:

Page:

                                                                                -.                189 Approval Date:

0-ADM-051 Outage Risk Assessment and Control 7/22/11 ATTACHMENT 17 (Page 5 of 5) UNIT 4 PROTECTED EQUTP1vIENT POSTINGS DURING ENCLOSURE 5 (PRESSURIZER FILLED >10%)

5. IF the 4C CCW or 4C ICW pump is running and required for operability of the protected RHR train, THEN install barriers at the following entry doors to the 4D 4kv bus room.

a. Door 139-1

b. Door 139-2

c. Door 135-2

6. In the CCW room, install barriers around the CCW pump whose 4kv power supply is protected above.

a. Record pump protected

7. Install barriers on the north end of 2 of 3 CCW Hxs.

a. Record Hxs protected 8 At the Intake, install barriers around the ICW pump whose 4kv power supply is protected above.

a. Record pump protected Date/Time Completed: /

PERFORMED BY (Print) NITIALS W97:DJT/clslmr/eme

ATTACHMENT 18 (Page 1 of 5) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 6 F_I NOTES a The steps in this attachment may be performed in any order. I

Due to the size of the switchyard bay, the size of the area around the transformers, and the size of the area around the CCW Heat Exchangers, those specified postings are not intended to provide a physical barrier; rather; to provide information and heightened awareness.
If the operating train is swapped or if components within a train are swapped, protected equipment postings should be placed or removed as necessaiy to maintain the postings and equipment status consistent. The new alignment should be posted prior to deposting the previously protected equipment.

IF offsite power is from the startup transformer, THEN perform the following:

a. In the switchyard, install barriers around the startup transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the startup transformer, install barriers around the startup transformer.

2. IF offsite power is from backfeed, THEN perform the following:

a. In the switchyard, install barriers around the main transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the main and aux transformers, install barriers around the main and aux transformers.

W97:DJT/cls/mr/emc

ATTACHMENT 18 (Page 2 of 5) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 6

3. IF 4A Train is the designated operating train, THEN post signs and/or barriers as follows:

a. Install barriers in the 4A 4KV Bus room at the following locations:

(1) East side of the 4A switchgear bus from the north wall to the south wall (2) West side of the 4A switchgear bus from the north wall to the south wall (Permit access to LP44.)

b. In the 4A 4KV Bus room, install signs as follows:

(1) Place a protected equipment sign on the front of 4 (Old Sequencer Cabinet) located on the north wall of the 4A 4KV Bus room. I The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could cause a bus lockout. _ = a a a a = a a (2) Place a protected equipment sign on the cubicle door for breaker 4AA09. (3) Place a protected equipment sign on the 4AA04 cubicle door.

c. Perform the following in the U4 480v load center rooms:

(1) Install barriers at the following locations: Infrontof4A48OvLC

In front of 4C 480v LC (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

d. Install barriers at the following entry doors to 4A EDG rooms:

(1) Door 138-1 (2) Door 133-2 (3) Door 14 1-1 to the 4A EDG DOTP area (4) Door 138-2 (5) Door 140-1 (6) Door 139-2 W97:DJT/cls/mr/emc

ATTACHMENT 18 (Page 3 of 5) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 6

3. Contd)

e. jJ the 4A ICW or CCW pump is unavailable and the 4D bus is aligned to the 4A bus, THEN install barriers at the following entry doors to 4D 4kv bus room:

(1) Door 139-1 (2) Door 139-2 (3) Door 135-2

f. In the control room, place unique information tags on the following pump control switches identifying them as the protected/operating train:

(1) 4ARHRPump (2) Select one: (N/A pump not operating)

i. 4ACCWPump OR ii. 4C CCW Pump (3) Select one: (N/A pump not operating)

i. 4A ICW Pump OR ii. 4C ICW Pump

4. IF 4B Train is the designated operating train, THEN post signs and/or barriers as follows:

a. Install barriers in the 4B 4KV Bus room at the following locations:

(1) East side of the 4B switchgear bus from the north wall to the south wall (Permit access to the ASD panel.) (2) West side of the 4B switchgear bus from the north wall to the south wall

b. In the 4B 4KV Bus room, install signs as follows:

(1) Place a protected equipment sign on the front of 4C23B (Old Sequencer Cabinet) located on the north wall of the 4B 4KV Bus room. W97:DJT/cls/mr/emc

ATTACHMENT 18 (Page 4 of 5) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 6 4.b. (Contd) a The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could cause a bus lockout. (2) Place a protected equipment sign on the cubicle door for breaker 4AB22 (3) Place a protected equipment sign on the 4AB04 cubicle door.

c. Perform the following in the U4 480v load center rooms:

(1) Install barriers at the following locations: o In front of 4B 480v LC o In front of 4D 480v LC (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

d. Install barriers at the following entry doors to 4B EDG rooms:

(1) Door 133-1 (2) Door 133-2 (3) Door 136-1 to the 4B EDG DOTP area (4) Door 133-3 (5) Door 135-2 (6) Door 134-2 (7) Door 135-1

e. IF the 4B ICW or CCW pump is unavailable and the 4D bus is aligned to the 4B bus, THEN install barriers at the following entry doors to 4D 4kv bus room:

(1) Door 139-1 (2) Door 139-2 (3) Door 135-2 \AIQ7fl ITIr{ImrImr

ATTACHMENT 18 (Page 5 of 5) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 6

4. (Contd

f. In the control room, place unique information tags on the following pump control switches identifying them as the protected/operating train:

(1) 4BRHRPump (2) Select one: (N/A pump not operating)

i. 4BCCWPump OR ii. 4C CCW Pump (3) Select one: (N/A pump not operating)

i. 4B ICW Pump OR ii. 4C ICW Pump

5. In the CCW room, install barriers around the CCW pump whose 4kv power supply is protected above.

a. Record pump protected

6. Install barriers at the top of the stairway to the running protected RHR pump room (10 ft).

a. Record RHR pump room protected 7 Install barriers on the north side of 2 of 3 CCW Hxs.

a. Record Hxs protected 8 At the Intake, install barriers around the ICW pump whose 4kv power supply is protected above.

a. Record pump protected Date/Time Completed: /____________

PERFORMED BY (Print) INITIALS W97:DJT/cls/mr/emc

ATTACHMENT 19 (Page 1 of 6) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 7 RCS DEFUELEI) IIItII NOTES 1

The steps in this attachment may be performed in any order.
Due to the size of the switchyard bay, the size of the area around the transformers, and the size of the area around the CCW Heat Exchangers, those specified postings are not intended to provide a physical barrier; rather; to provide information and heightened awareness.

a If the operating train is swappecJ or if components within a train are swapped, protected equipment postings should be placed or removed as necessaiy to maintain the postings and equipment status consistent. The new alignment should be posted prior to deposting the previously protected equipment. IF offsite power is from the startup transformer, THEN perform the following:

a. In the switchyard, install barriers around the startup transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the startup transformer, install barriers around the startup transformer.

2. IF offsite power is from backfeed, THEN perform the following:

a. In the switchyard, install barriers around the main transformer bay as follows:

(1) Install a barrier on the east side of the bay facing east. (2) Install a barrier on the north side facing north. (3) Install a barrier on the west side facing west (4) Install a barrier on the south side facing south.

b. At the main and aux transformers, install barriers around the main and aux transformers.

W97:DJT/cls/mr/emc

ATTACHMENT 19 (Page 2 of 6) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 7 RCS DEFUELED

3. jj 4C 480v LC is fed from 4A 4kv bus, THEN post signs and/or barriers as follows:

a. Install barriers in the 4A 4KV Bus room at the following locations:

(1) East side of the 4A switchgear bus from the north wall to the south wall (2) West side of the 4A switchgear bus from the north wall to the south wall (Permit access to LP44.)

b. In the 4A 4KV Bus room, install signs as follows:

(1) Place a protected equipment sign on the front of 4C23A (Old Sequencer Cabinet) located on the north wall of the 4A 4KV Bus room.

            =               a      a         a   a    a                 a NOTE i   The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could H cause a bus lockout.

(2) Place a protected equipment sign on the 4AA09 cubicle door. (3) Place a protected equipment sign on the 4AA04 cubicle door.

c. In the 4B 4kv Bus Room, place a Protected Equipment sign on the 4AB04 Cubicle Door.

d. Perform the following in the U4 480v load center rooms:

(1) Install barriers at the following locations: c Infrontof4A48OvLC e Infrontof4C48OvLC (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms. (3) IF load centers are cross-tied, THEN install barriers at the following locations:

Infrontof4B48OvLC
In front of 4D 480v LC

ATTACHMENT 19 (Page 3 of 6) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 7 RCS DEFUELED

3. (Cont d) t

e. Install barriers at the following entry doors to 4A EDG rooms:

(1) Door 138-1 (2) Door 133-2 (3) Door 141-1 to the 4A EDG DOTP area (4) Door 138-2 (5) Door 140-1 (6) Door 139-2

f. IF the 4A ICW or CCW pump is unavailable and the 4D bus is aligned to the 4A bus, THEN install barriers at the following entry doors to 4D 4kv bus room:

(1) Door 139-1 (2) Door 139-2 (3) Door 135-2

g. In the control room, place unique information tags on the following pump control switches identifying them as the protected/operating train:

(1) Select one: (N/A pump not operating)

i. 4ACCWPump OR ii. 4CCCWPump (2) Select one: (N/A pump not operating)

i. 4A ICW Pump OR ii. 4C ICW Pump

ATTACHMENT 19 (Page 4 of 6) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 7 RCS DEFUELED

4. j 4C 480v LC is fed from 4D LC, ThEN post signs and/or barriers as follows:

a. Install barriers in the 4B 4KV Bus room at the following locations:

(1) East side of the 4B switchgear bus from the north wall to the south wall (Permit access to the. ASD panel.) (2) West side of the 4B switchgear bus from the north wall to the south wall

b. In the 4B 4KV Bus room, install signs as follows:

(1) Place a protected equipment sign on the front of 4C23B (Old Sequencer Cabinet) located on the north wall of the 4B 4KV Bus room. a aaa The C bus tie breaker cubicle contains an HGA relay that if mechanically agitated could cause a bus lockout. laa. a a a a a a a a a 1 (2) Place a protected equipment sign on the cubicle door for breaker 4AB22 (3) Place a protected equipment sign on the 4AB04 cubicle door.

c. In the 4A 4kv Bus Room, place a Protected Equipment sign on the 4AA04 Cubicle Door.

d. Install barriers at the following locations in the Unit 4 480v load center rooms:

(1) Install barriers in front of 4A, 4B and 4C, 4D 480v LCs. (2) Install protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

e. Install barriers at the following entry doors to 4B EDG rooms:

(1) Door 133-1 (2) Door 133-2 (3) Door 13 6-1 to the 4B EDO DOTP area (4) Door 133-3 (5) Door 135-2 (6) Door 134-2 (7) Door 135-1 W97:DJT/cls/mr/emc

ATTACHMENT 19 (Page 5 of 6) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 7 RCS DEFUELED

4. (Contd)

f. j the 4B ICW or CCW pump is unavailable and the 4D bus is aligned to the 4B bus, THEN install barriers at the following entry doors to 4D 4kv bus room:

(1) Door 139-1 (2) Door 139-2 (3) Door 135-2

g. In the control room, place unique information tags on the following pump control switches identifying them as the protected/operating train:

(1) Select one: (N/A pump not operating)

i. 4B CCW Pump OR ii. 4C CCW Pump (2) Select one: (N/A pump not operating)

i. 4B ICW Pump OR ii. 4C ICW Pump

5. In the CCW room, install barriers around the CCW pump whose 4kv power supply is protected above.

a. Record pump protected W97:DJT/cIs/mr/mc

Procedure No.: Procedure

Title:

Page:

                                                                                             -  204J Approval Date:

O-ADM-051 Outage Risk Assessment and Control 7/22/11 ATTACHMENT 19 (Page 6 of 6) UNIT 4 PROTECTED EQUIPMENT POSTINGS DURING ENCLOSURE 7 RCS DEFUELED

6. Install barriers on the north end of 1 of 3 CCW Hxs.

a. Record Hxs protected

7. At the SFP pump and Hx room, install a barrier at the entry door.

8. Place a magnetic stop sign at 480V LC Breaker Cubicle 40309, SFP Cooling Pumps.

9. Place a magnetic stop sign on 480 V LC Breaker Cubicle 30309, SFP Cooling Pumps.

10. j offsite power is from backfeed, THEN place a protected equipment sign at the safeguards racks to protect the Aux Transformer breaker.

a. 4QR42

b. 4QR43

c. 4QR44

d. 4QR45

11. At the Intake, install barriers around the ICW pump whose 4kv power supply is protected above.

a. Record pump protected

12. IF the RWST is one of the two credited sources of makeup water to the Spent Fuel Pit, THEN place a magnetic stop sign on RWST purification pump breaker 30788 (U3 outage) or 40788 (U4 outage).

a. Record the breaker protected

13. j Primary Water is one of the two credited sources of makeup water to the Spent Fuel Pit, THEN place a magnetic stop sign on ONE of the following Primary Water Pump breakers:

0885 (3A), 30664 (3B), 0884 (4A), 40664 (4B).

a. Record the breaker protected

14. IF the CVCS HUT is one of two credited sources of makeup water to the Spent Fuel Pit, THEN place a magnetic stop sign on CVCS HUT recirculation pump breaker, 0853.

Date/Time Completed: /____________ PERFORMED BY (Print) INITIALS W97:DJT/cls/mr/emc

ATTACHMENT 20 (Page 1 of 4) UNIT 3 PROTECTED EQUIPMENT POSTINGS RESTORATION Ensure Unit 3 RCS temperature is above 200 deg.

                =             =     =              IS The remainder of this attachment may be completed in any order

2. In switchyard, perform the following:

a. In the startup transformer bay, ensure the following barriers are removed:

(1) Barrier on the east side of the bay facing east. (2) Barrier on the north side facing north. (3) Barrier on the west side facing west (4) Barrier on the south side facing south.

b. In the main transformer bay, ensure the following barriers are removed:

(1) Barrier on the east side of the bay facing east. (2) Barrier on the north side facing north. (3) Barrier on the west side facing west (4) Barrier on the south side facing south.

3. At the startup transformer, ensure all barriers around the startup transformer are removed.

4. At the main and aux transformers, ensure all barriers around the main and aux transformers are removed.

5. At the 4kv bus rooms, perform the following:

a. Ensure barriers are removed from the following entry locations:

(1) East side of the 3A switchgear bus from the north wall to the south wall (2) West side of the 3A switchgear bus from the north wall to the south wall (1) East side of the 3B switchgear bus from the north wall to the south wall (2) West side of the 3B switchgear bus from the north wall to the south wall W97:DJT/cls/mrtemc

ATTACHMENT 20 (Page 2 of 4) UNIT 3 PROTECTED EQUIPMENT POSTINGS RESTORATION

5. (Contd)

b. In the 3A 4kv bus room, ensure protected equipment signs and barriers are removed at the following locations:

(1) Breaker 3AA09, Cross-tie to 3C Bus breaker (2) Cubicle door 3AA04 (3) 3C23A (old sequencer panel)

c. In the 3B 4kv bus room, ensure protected equipment signs and barriers are removed at the following locations:

(1) Breaker 3AB22, Cross-tie to 3C Bus breaker (2) Cubicle door 3AB04 (3) 3C23B (old sequencer panel)

6. At the 480v load center rooms, perform the following:

a. Ensure barriers removed from the following locations:

(1) In front of 3A, 3B and 3C, 3D 480v LCs (2) Remove protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

7. At the EDG rooms ensure barriers are removed from the following entry doors:

a. Door 073-i

b. Door 072-2

c. Door 13 1-1 to the 3A EDG radiator area

d. Door 075-ito the 3A EDG Daytank room

e. Door 072-1

f. Vital area door 3EDG3131 to the 3B EDG radiator area

g. Door 074-ito the 3B EDG Daytank room wq7ri ITIrIImrimr

ATTACHMENT 20 (Page 3 of 4) UNIT 3 PROTECTED EQUIPMENT POSTINGS RESTORATION

8. Remove 3A MCC 480v MCC Vital Section as follows:

a. At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), remove magnetic STOP signs on each cabinet door of 3A 480v MCC Vital Section (8 signs total).

b. At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), remove a magnetic STOP sign on the north side facing north.

c. At 3A 480v MCC Vital Section (east side of Turbine Bldg walkway, immediately above condensate pumps), remove a magnetic STOP sign on the south side facing south.

9. At the 3D 4kv bus room, ensure barriers at the following entry doors are removed:

(1) Door 134-1 (2) Door 134-2

10. In the Control Room, ensure any information tags on the RHR, CCW, or ICW pump control switches for designated operating and protected trains are removed.

11. In the Control Room, ensure any protected equipment signs are removed from safeguards racks 3QR42/43/44/45.

12. In the CCW room, ensure all barriers around the CCW pumps are removed.

13. At the RHR pump rooms, ensure all barriers to 3A and 3B RHR pumps are removed.

14. In the CCW room, ensure all barriers around CCW Hxs are removed.

15. At the Intake, ensure all barriers around the ICW pumps are removed.

16. At the U3 SFP pump room, ensure all barriers are removed from the entrance door and SFP Cooling Heat Exchanger.

17. At 480V LC Breaker Cubicle 30309 SFP Cooling Pump ensure stop sign removed

18. At 480V LC Breaker Cubicle 40309 SFP Cooling Pump ensure stop sign removed.

Wq7fl.ITkIs/mr/pmr,

ATTACHMENT 20 (Page 4 of 4) UNIT 3 PROTECTED EQUIPMENT POSTINGS RESTORATION

19. Ensure magnetic stop signs are removed from the following locations:

a. the RWST purification pump breakers : 30788, 407788.

b. the Primary Water Pumps breakers: 0885, 30664, 0884, 40664.

c. the CVCS HUT recirculation pump breaker: 0853.

Date/Time Completed: /____________ PERFORMED BY (Print) INITIALS W7fl. IT//mr/cmr

ATTACHMENT 21 (Page 1 of 4) UNIT 4 PROTECTED EQUIPMENT POSTINGS RESTORATION Ensure Unit 4 RCS temperature is above 200 deg.

                   =   =   =       =                          =

The remainder of this attachment may be completed in any order.

                         =       =                          =                       =

2. In switchyard, perform the following:

a. In the startup transformer bay, ensure the following barriers are removed:

(1) Barrier on the east side of the bay facing east. (2) Barrier on the north side facing north. (3) Barrier on the west side facing west (4) Barrier on the south side facing south.

b. In the main transformer bay, ensure the following barriers are removed:

(1) Barrier on the east side of the bay facing east. (2) Barrier on the north side facing north. (3) Barrier on the west side facing west (4) Barrier on the south side facing south.

3. At the startup transformer, ensure all barriers around the startup transformer are removed.

4. At the main and aux transformers, ensure all barriers around the main and aux transformers are removed.

5. At the 4kv bus rooms, perform the following:

a. Ensure barriers are removed from the following entry locations:

(1) East side of 4A switchgear bus from north to south wall (2) West side of 4A switchgear bus from north to south wall (3) East side of 4B switchgear bus from north to south wall (4) West side of 4B switchgear bus from north to south wall \AIc7fl IT/c kImrhm,

ATTACHMENT 21 (Page 2 of 4) UNIT 4 PROTECTED EQUIPMENT POSTINGS RESTORATION

5. (Contd)

b. In the 4A 4KV Bus room, ensure protected equipment signs are removed from the following cubicle doors:

(1) Breaker 4AA09, Cross-tie to 4C Bus breaker (2) Cubicle door 4AA04 (3) 4C23A (old sequencer panel)

c. In the 4B 4KV Bus room, ensure protected equipment signs are removed from the following cubicle doors:

(1) Breaker 4AB22, Cross-tie to 4C Bus breaker (2) Cubicle door 4AB04 (3) 4C23B (old sequencer panel)

a. Ensure barriers removed from the following locations:

(1) In front of 4A and 4B 480v load centers (2) In front of 4C and 4D 480v load centers

b. Remove protected equipment signs at their respective undervoltage relay panels located on the south wall of the 480v load center rooms.

W97:DJT/clslmr/emc

ATTACHMENT 21 (Page 3 of 4) UNIT 4 PROTECTED EQUIPMENT POSTINGS RESTORATION

7. At the EDG rooms ensure barriers are removed from the following entry doors:

a. Door 138-1

b. Door 133-2

c. Door 141-1 to the 4A EDG DOTP area

d. Door 138-2

e. Door 139-1

f. Door 139-2

g. Door 133-1

h. Door 136-1 to the 4B EDG DOTP area

i. Door 133-3

j. Door 135-2

k. Door 134-2

1. Door 140-1

8. In the control room, ensure any information tags on the RHR, CCW, or ICW pump control switches for designated operating and protected trains are removed.

W97:DJT/cls/mr/emc

ATTACHMENT 21 (Page 4 of 4) UNIT 4 PROTECTED EQUIPMENT POSTINGS RESTORATION

9. In the Control Room, ensure any protected equipment signs are removed from safeguards racks 4QR42/43/44/45.

10. In the CCW room, ensure all barriers around the CCW pumps are removed.

11. At the RHR pump rooms, ensure all barriers to 4A and 4B RHR pumps are removed.

12. In the CCW room, ensure all barriers around CCW Hxs are removed.

13. At the Intake, ensure all barriers around the ICW pumps are removed.

14. At door to the U4 SFP pump room, ensure all barriers are removed from the entrance door and SFP Cooling Heat Exchanger.

15. At 480V LC Breaker Cubicle 40309 SFP Cooling Pump 4P212A/B, ensure stop sign removed.

16. At 480V LC Breaker Cubicle 30309 SFP Cooling Pump ensure stop sign removed.

17. Ensure magnetic stop signs are removed from the following locations:

a. the RWST purification pump breakers: 30788, 407788.

b. the Primary Water Pumps breakers: 0885, 30664, 0884, 40664.

c. the CVCS HUT recirculation pump breaker: 0853.

Date/Time Completed: / PERFORMED BY (Print) iNITIALS FINAL PAGE W97fllT/iIs/mr/mr}}

ML12167A015

Text

Title:

Reference:

References:

Response

Title:

Reference:

References:

Response

Title:

SUMMARY

7.0 REFERENCES

7.0 REFERENCES

Title:

Reference:

References:

Response

Title:

2.0 REFERENCES

Title:

2.0 REFERENCES

Title:

Title:

Title:

Title:

Title:

Title:

Title:

Title:

Title:

Title:

Title:

Title:

Title:

Subject:

Title:

Title:

Title:

SUMMARY

7.0 REFERENCES

6.0 REFERENCES

Title:

Reference:

References:

Response

Title:

SUMMARY

7.0 REFERENCES

Title:

Reference:

References:

Response

Response

REFERENCE:

REFERENCE:

REFERENCE:

REFERENCE:

SUMMARY

Title:

Title:

Title:

2.0 REFERENCES

Title:

Title:

Title:

Title:

2.0 REFERENCES

Title:

Title:

Title:

Title:

Title:

Title:

Title:

Title:

Title:

Title:

Title:

Title: