Text

Initial Exam 2012-301 Final Administrative JPMs
	ML12331A314
Person / Time
Site:	Browns Ferry
Issue date:	11/23/2012
From:	; NRC/RGN-II
To:	; Tennessee Valley Authority
References
	50-259/12-301, 50-260/12-301, 50-296/12-301 50-259/12-301, 50-260/12-301, 50-296/12-301
	Download: ML12331A314 (299)
	v • d • e

FINAL Browns Ferry ILT 1205 NRC EXAM Admin JPMs FINAL

F I NAL Admin SRO/RO Ala PAGE 1 OF 11 OPERATOR:

RO SRO DATE:

JPM NUMBER: Admin SRO/RO Ala TASK NUMBER: Conduct of Operations TASK TITLE: O-SR-3.8.l.A.l, Verification of Offsite Power Availability to 4.16 KV Shutdown Boards KJANUMBER: 2.1.31 KIA RATING: R04.6 SRO4.3 PRA:

TASK STANDARD: Marks 500KV and 161KV Sources as Qualified. Completes Attachment 1 for Unit 3 accurately, records indicated voltages for step 7.3 [5] and does not sign acceptance criteria, does not sign acceptance criteria for 7.5[1], and marks acceptance criteria satisfied on Surveillance Task Sheet (STS) as NO.

LOCATION OF PERFORMANCE: Simulator REFERENCES/PROCEDURES NEEDED: 0-SR-3 .8.1 .A. 1 VALIDATION TIME: 20 minutes MAX. TIME ALLOWED: 60 minutes PERFORMANCE TIME:

COMMENTS:______________________________

Additional comment sheets attached? YES NO RESULTS: SATISFACTORY UNSATISFACTORY SIGNATURE:___________ DATE:

EXAMINER

INITIAL CON]MTIONS: You are an extra Operator. Breaker 1312, 4KV Unit BD 3ANonnal Feeder Breaker is out of service for a breaker swap. The 3A Diesel Generator was removed from service due to an oil leak and declared inoperable 15 minutes ago. Units 1, 2 and 3 are at 100%

power. The performance of 0-SR-3.8.1.A.1, Verification of Offsite Power Availability to 4.16KV Shutdown Boards is necessary. The TVA Transmission Operator reports that the qualification status of the 500 KV and 161 KV Sources is GREEN to Browns Ferry Nuclear Plant.

INITIATING CUE: The Unit 3 Unit Supervisor directs that you perform 0-SR-3.8.1.A.1, Verification of Offsite Power Availability to 4.16 KV Shutdown Boards for Unit 3. The Unit 1 and 2 portions have already been completed.

Adinin SRO/RO Ala PAGE 3 OF 11 IN-SIMULATOR: I will explain the initial conditions and state the task to be performed. I will provide initiating cues and reports on other actions when directed by you. When you complete the task successfully, the objective for this job performance measure will be satisfied. When your task is given, you will repeat the task and I will acknowledge Thats Correct. (OR Thats Incorrect, if applicable). When you have completed your assigned task, you will say, my task is complete and I will acknowledge that your task is complete.

INITIAL CONDITIONS: You are an extra Operator. Breaker 1312,4KV Unit BD 3A Normal Feeder Breaker is out of service for a breaker swap. The 3A Diesel Generator was removed from service due to an oil leak and declared inoperable 15 minutes ago. Units 1, 2 and 3 are at 100%

power. The performance of 0-SR-3.8.1.A.1, Verification of Offsite Power Availability to 4.16KV Shutdown Boards is necessary. The TVA Transmission Operator reports that the qualification status of the 500 KV and 161 KV Sources is GREEN to Browns Ferry Nuclear Plant.

INITIATING CUE: The Unit 3 Unit Supervisor directs that you perform 0-SR-3.8.1.A.1, Verification of Offsite Power Availability to 4.16 KV Shutdown Boards for Unit 3. The Unit 1 and 2 portions have already been completed.

Admin SRO/RO Ala PAGE 4 OF 11 START TIME____

Performance Step 1: Critical X Not Critical

[2] DOCUMENT the source qualification below.

QUALIFIED UNQUALIFIED 500KV SOURCE 161KV SOURCE Standard:

Marks the 500 KV and 161 KV Sources as Qualified SAT_ UNSAT_ N/A COMMENTS:_________

Admin SRO/RO Ala PAGE 5 OF 11 Performance Step 2: Critical X Not Critical

[3] COMPLETE Attachment 1, to document which subcomponents are credited as satisfying the requirements of a qualified offsite circuit for Unit 1, Unit 2, and Unit 3 by marking the subcomponent with a circle around it and placing an initial next to the subcomponent.

Standard:

Completes attachment 1 for Unit 3, Columns 1 and 2. Must use USST 3B in either column I or2.

Can use Either CSST A or B in column 2 or 1 (whichever column USST 3B was not used for).

For USST 3B, BKR 1314, 4KV Unit BD 3B, BKR 1332, BKRs 1338 and 1342, and 4KV SD BD 3EC and 3ED.

For CSST A, BKR 1412, Start Bus 1A, BKR 1432,4KV Unit BD 3A, BKR 1326, BKRs 1334 and 1336, and 4KV SD 3EA and 3EB.

For CSST B, BKR 1518, Start Bus 1A, BKR 1432,4KV Unit BD 3A, BKR 1326, BKRs 1334 and 1336, and 4KV SD 3EA and 3EB.

SAT UNSAT N/A COMMENTS:________________________________

Admin SRO/RO Ala PAGE 6 OF 11 Performance Step 3: Critical Not Critical NOTE Specific voltmeters are NOT listed to allow the performer maximum flexibility when obtaining readings. However, Control Room indications should be used whenever possible.

[4] IF performing this procedure to satisfy Technical Specification 3.8.1 Required Action A. 1 or B. 1 or G. 1 for Unit 1 and Unit 2, THEN RECORD voltages for the following boards and CHECK proper voltage is available, (Otherwise N/A Steps 7.3[4]A, 7.3[4]B, 7.3[4]C, and 7.3[4]D.)

A. 4KV SD BD A VOLTAGE Voltage (3950 4400 VOLTS)

B. 4KV SD BD B VOLTAGE Voltage (3950 4400 VOLTS)

C. 4KV SD BD C VOLTAGE Voltage (3950 4400 VOLTS)

D. 4KV SD BD D VOLTAGE Voltage (3950 4400 VOLTS)

Standard:

Step is NA SAT_ UNSAT N/A COMMENTS:_____________________

Cue: If Operator requests Voltage Readings A4300, B4250, C4350 and D4300

Admin SRO/RO Ala PAGE 7 OF 11 Performance Step 4: Critical X Not Critical NOTE Specific voltmeters are NOT listed to allow the performer maximum flexibility when obtaining readings. However, Control Room indications should be used whenever possible.

[5] IF performing this procedure to satisfy Technical Specification 3.8.1 Required Action A.1 or B.l for Unit 3, THEN RECORD voltages for the following boards and CHECK proper voltage is available, (Otherwise N/A Steps 7.3 [5]A, 7.3 [5]B, 7.3[5]C, and 7.3[5]D.)

A. 4KV SD BD 3EA VOLTAGE Voltage (3950 4400 VOLTS)

B. 4KV SD BD 3EB VOLTAGE Voltage (3950 4400 VOLTS)

C. 4KV SD BD 3EC VOLTAGE Voltage (3950 4400 VOLTS)

D. 4KV SD BD 3ED VOLTAGE Voltage (3950 4400 VOLTS)

Standard:

Records voltage readings for 3EA, 3EB, 3EC and 3ED. Voltage for 3EA and 3EB are outside the required voltage range.

SAT_ UNSAT N/A COMMENTS:_____________________________

Cue: If Operator request an AUO to check voltages locally report voltages agree with control room indications

Admin SRO/RO Ala PAGE 8 OF 11 Performance Step 5: Critical Not Critical X 7.4 Verification of Unit 1 and or Unit 2 Offsite AC Power Circuits NOTES

1) Step 7.4[lj and 7.4[2] may be marked N/A if this procedure is NOT required to satisfy Unit I and 2 Technical Specification 3.8.1 Required Action A.1 or B.l.

2) Completed Attachment 1 is Utilized to EVALUATE offsite circuit availability.

[1] IF performing this procedure to satisfy Unit 1(2) Technical Specification 3.8.1 Required Action B.l (one required Unit land 2 DG inoperable), THEN (Otherwise N/A).

[2] IF performing this procedure to satisfy Unit 1(2) Technical Specification 3.8.1 Required Action A. 1 (one required offsite circuit inoperable), THEN (Otherwise N/A)

[3] IF performing this procedure to satisfy Unit 1(2) Technical Specification 3.8.1 Condition G ( one required offsite circuit inoperable and one Unit 1 and 2 DG inoperable, THEN (Otherwise N/A)

Standard:

Step is NA SAT_ UNSAT N/A COMMENTS:_______________________________

Admin SRO/RO Ala PAGE 9 OF 11 Performance Step 6: Critical X Not Critical 7.5 Verification of Unit 3 Offsite AC Power Circuits NOTES

1) Step 7.5[1] and 7.5[2] may be marked N/A if this procedure is NOT required to satisfy Unit 3 Technical Specification 3.8.1 Required Action A. 1 or B.1.

2) Completed Attachment 1 is Utilized to EVALUATE offsite circuit availability.

[1] IF performing this procedure to satisfy Unit 3 Technical Specification 3.8.1 Required Action B. 1 (one required Unit 3DG inoperable), THEN VERIFY at least two Unit 3 Offsite AC circuits are determined Operable in Attachment 1 and the shutdown boards included in the Operable circuits have proper voltage verified in step 7.3[5]. (Otherwise N/A).

[2] IF performing this procedure to satisfy Unit 3 Technical Specification 3.8.1 Required Action A. 1 (one required offsite circuit inoperable), THEN VERIFY at least one Unit 3 Offsite AC circuit is determined Operable in Attachment 1 and the shutdown boards included in the Operable circuit have proper voltage verified in step 7.3[5] (Otherwise N/A).

Standard:

Step 7.5 [1] is the reason for the surveillance, the Operator does NOT initial acceptance criteria because the voltage on 4KV SD Boards 3EA and 3EB are less than the required 3950 volts.

SAT_ UNSAT N/A COMMENTS:________________________________

Admin SRO/RO Ala PAGE 10 OF 11 Perfonnance Step 7: Critical Not Critical X 7.6 Common Cause Failure Evaluation and Surveillance Completion

[1] EVALUATE the necessity to perform O-TI-403, Determination of Common Cause Failure for Emergency Diesel Generators, if this surveillance is being performed for an inoperable Diesel Generator.

Standard:

Continue to next step.

SAT_ UNSAT_ N/A COMMENTS:________________________________

CUE: The Shift Manager is evaluating the necessity of performing O-TI-403 I Performance Step 8: Critical X Not Critical

[2) On the Surveillance Task Sheet (STS)

A. RECORD the Completion Date and Time.

B. REVIEW and COMPLETE the Surveillance Task Sheet (STS) through the Test Director/Lead Performer & Date fields.

Standard:

Completes Surveillance Task Sheet (STS), the critical step is that Acceptance Criteria Satisfied is marked NO.

SAT UNSAT N/A COMMENTS:

Admin SRO/RO Ala PAGE 11 OF 11 Performance Step 9: Critical Not Critical X

[3] NOTIFY the Unit One, Unit Two and Unit Three Operators (UOs) this Surveillance Procedure is complete.

Standard:

NOTIFIES the Unit Two and Three Unit Operators (U0 s) this Surveillance Procedure is 1

complete.

SAT_ UNSAT_ N/A COMMENTS:________________________________

I CUE: Acknowledge Notification. I Performance Step 10: Critical Not Critical X

[4] NOTIFY the Unit Supervisor (US) this surveillance procedure is complete and PROVIDE status of any Corrective Actions or unsatisfactory performance.

Standard:

NOTIFIES the Unit Supervisor (US) this surveillance procedure is complete and PROVIDES status of any Corrective Actions or unsatisfactory performance.

SAT_ UNSAT N/A COMMENTS:_________________________

Cue: Acknowledge Notification I END OF TASK STOP TIME

Browns Ferry Nuclear Plant Unit 0 Surveillance Procedure 0-SR4.8..1 Al Verification of Offsite Power Availability to 4.16 kV Shutdown Boards Revision 0012 Quality Related Level of Use: Continuous Use Level of Use or Other Informallon: Key Number P1905 Effective Date: 04-12-2011 A Responsible Organization: OPS, Operations /i--

Prepared By: Keith Smith Approved By: Keith W. Benefield

BFN Verification of Offslte Power O-SR-3.8.1 Al Unit 0 AvailabilIty to 4.1$ kV Shutdown Rev. 0012 Boards Page 2 of 21 Current Revision Description Type of Change: Enhancement Tracking Number 013 PCRs: 11000692 Documentation: None Step 7.3[1] changed TRO-TO-SOP-10.128 to TRO-TO-SOP-30.128

BFN Verification of Offslte Power 0-SR-3.8.1 .A.1 UnIt 0 Availability to 4.16 kV Shutdown Rev. 0012

t. Boards Table of Contents Page3of2l 1.0 IN1RODUCTION 4 1.1 Purpose 4 1.2 Scope 4 1.3 Frequency 4 1.4 Applicability 4

2.0 REFERENCES

5 2.1 Technical Specifications 5 2.2 UFSAR 5 2.3 Plant Instructions 5 2.4 TVA INSTRUCTIONS 5 2.5 Plant Drawings 6 3.0 PRECALI1 IONS AND LIMFATIONS . *,,,. 7 3.1 General Precautions 7 3.2 Operability and LCOs 7 3.3 Equipment 7 3.4 Qualified Grid Source 8 4.0 PREREQUlSES ............ 9 5.0 SPECIAL TOOLS AND. RECOMMENDED EQUIPMENT 9 6.0 ACCEP1ANCE CRI1ERIA 10 7.0 PROCEDURE STEPS ..... **,*.*******.****....*.*** ... 12 7.1 Initiation and Approvals 12 7.2 Technical Specification Required Action Determination 13 7.3 Verification of Offslte 500kv and 161kv Sources 14 7.4 Verification of Unit I and or Unit 2 Offsite AC Power Circuits 17 7.5 Verification of Unit 3 Offsite AC Power Circuits 18 7.8 Common Cause Failure Evaluation and Surveillance Completion 19 8.0 ILLUS1R.*.TIONSIAT1ACHMEt41S t1** 19 Attachment 1: Table of Offslte and Onsite Circuits AssIgned to Units 1, 2 arid 3 *1I**t 20

BFN Verification of Offslte Power 0-SR4.8.1 .A.1 Unit 0 Avaflabllity to 4.16 kV Shutdown Rev. 0012 t INTRODUCTION Boards Page 4 of 21 1.0 1.1 Purpose This procedure is performed to verify power availability from the offsite transmission network to the onsite Class I E AC Electrical Power Distribution System in conformance with the requirements specified In Technical Specification 3.8.1 Required Action Al and B.l.

1.2 Scope This procedure verifies the availability of qualified circuits between the offsite transmission network and the onsite Class I E AC Electrical Power Distribution System. Qualification and continuity from the offsite electrical power supply to the onsite distribution network Is ensured by determinIng the:

[I] Qualification of the 500 KV and 161 KV off-site power system.

[21 Qualification of the 500KV and 161 off site power system.

[31 Configuration and operability for each of the four basic Unit 112 circuits from the transmission network to the safety related DMsion I and 114kV Shutdown Boards.

[4] Configuration and operability for each of the three basic Unit 3 circuits from the transmission network to the safety related Division I and 114kV Shutdown Boards.

[5] Proper voltage on the 4.16 KV shutdown boards.

1.3 Frequency Performanceof this procedure is conditional, dependent on the status of required offsite circuits and Diesel Generators. This procedure shall be performed within one hour from the time:

[1] One required offelte circuit Is declared inoperable or

[2] One required Unit 1/2 DG is declared inoperable, or

[3] One required Unit 3 DG Is declared Inoperable.

Then once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter, until each unit (in mode 1, 2 or 3) has two qualified offsite circuits operable and all required DIGs operable.

1.4 ApplicabIlity The requirements of this procedure are applicable in Modes 1,2, and 3.

BFN Verification of Offsite Power 0-SR-3.8.l Al UnIt 0 AvaIlability to 4.16 kV Shutdown Rev 0012 Boards Page 5 of 21

2.0 REFERENCES

2.1 TechnIcal Specifications Section B3.8.1, AC Sources Operating Section 3.8.1, AC Sources Operating 2.2 UFSAR Section 8.1, Summary Description Section 8.2, Generators Section 8.3, Transmission System Section 8.4, Normal Auxiliary Power System Section 8.5, Standby A-C Power Supply and Distribution Appendix F, Unit Sharing And Interactions 2.3 Plant Instructions O-GOI-300-4, Switchyard Manual O-Ol-57A, Switchyard and 4160V AC Electrical System OPDP-1, Conduct of Operations NPG-SPP-06.9.1, Conduct of Testing NPG-SPP-06.9.2, Surveillance Test Program 2.4 WA INSTRUCTIONS IGA-6, Inter-group Agreement TRO-TO-SOP-1O.128, Browns Ferry Nuclear Plant (BFN) Grid Operating Guide

BFN Verification of OffsIte Power 0-SR-3.8.1.A.1 UnIt 0 AvailabilIty to 4.16 kV Shutdown Rev. 0012 Boards Page 6 of 21 2.5 Plant Drawings 0-1 5E500-1, Key Diagram of Standby Auxiliary Power System 3-15E500-3, Key Diagram of Normal & Standby Auxiliary Power System O-45N500, Wiring Diagrams Development Single Line O-45E506, Wiring Diagram Main Single Line SH 1161 Ky SWYD 0

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BFN Verification of Offslte Power 0-SR-3.8.1.A.1 Unit 0 AvaIlability to 4.16 kV Shutdown Rev. 0012 Boards Page 7 of 21 3.0 PRECAUTIONS AND LIMITATIONS 3.1 General Precautions A. This procedure may be performed In any plant operating condition subject to the approval of the Unit Supervisor (US).

B. In the context of this procedure, equipment tagged and/or de-ene,ized as indicated by Indicating lights, control switch positions or indicating meters In the Control Room Is NOT AVAILABLE. Skill of the performer will be utilized to make this determination.

C. Only offsite power delivered to Unit 1/2 Shutdown Boards through their normal feeder breakers can be credited, since common accident signal (CAS) logic will trip the alternate breaker.

3.2 OperabIlity and LCOs A. There are four basic Unit 1/2 circuits from the transmission network to the safety related Division I and 114kV Shutdown Boards. For Units I and 2:

1. Only two of the four qualified circuits are REQUIRED to be operable.

2. If any two of the four circuits are operable, then LCO 3.8.1 .a is satisfied.

B. There are three basic Unit 3 circuits from the transmission network to the safety related DMsIon I and 114kV Shutdown Boards. For Unit 3:

1. Only two of the three qualified circuits are required to be operable.

2. If any two of the three circuits are operable, then LCO 3.8.1 .a is satisfied.

3.3 EquIpment A. Multiple units can claim a 161kV offsite power circuit simultaneously. However, if a load is connected to a 4kV Start Bus, O-Ol-57A will Initiate manual actions to disable automatic transfer of selected 4kV Unit Boards and 4kV Common Boards to the 161kV circuits. The 161kV source may still be considered operable with a delayed manual transfer.

With the most restrictive manual actions in place, diesel generators would supply the safety related loads needed to mitigate the Immediate consequences of an accident or analyzed operational transient. Operators can manually transfer loads to the 4kV start bus to support long term post accident or transient recovery and shutdown.

BFN Verification of Offsite Power 0-SR4.8.1 .A.1 Unit 0 Avaflablllty to 4.16 kV Shutdown Rev. 0012 t 3.4 Qualified Grid Source Boards Page 8 of 21 A. TVAs Transmission Operator (TOp) is responsible for determining if the transmission grid is configured and operating within established limits that ensure the grids ability to provide QUALIFIED offslte power to Browns Ferry Nuclear Plant.

B. This procedure verifies OPERABILITY for each of the seven basic AC circuits, from the offsite source to 4kV Shutdown boards (four Unit 112 circuits or three Unit 3 circuits). To be OPERABLE, each basic circuit must have a QUALIFIED offsite power source. The Browns Ferry Operator must request the WA Southwestern TOp to determine the QUALIFICATION status of the offsite power source (500kV or 161kV) when performing this procedure.

C. A color code system is used to communicate the QUALIFICATION status of the offsite power sources, both for current conditions and for postulated grid contingencies. The TOp will verbally inform Browns Ferry Operations of status color code changes In real-time. The status color code definitions and associated restrictions and requirements are contained in TRO-TO-SOP-10.128, Browns Feny Nuclear Plant (BFN) Grid Operating Guide.

D. A QUALIFIED offslte circuit may be connected to more than one division of 4kV shutdown boards and not violate separation criteria. A circuit that is not connected to the Division I or 114kV shutdown boards is required to have the capability to be connected to at least one division of 4kV shutdown boards to be considered OPERABLE.

BFN Verification of Offslte Power 0-SR4.8.1 .A.1 UnIt 0 AvailabilIty to 4.16 kV Shutdown Rev. 0012 t Boards PageS of 21 Date ibAbt PREREQUISITES VERIFY this copy of O-SR-3.8.1 Al is the current revision.

OBTAIN a Surveillance Task Sheet (STS) for this procedure

-&/ and Work Activity. (Key Number P1905) _Zz 5.0 SPECIAL TOOLS AND RECOMMENDED EQUIPMENT None

BFN Verification of Offslte Power 0-SR-3.8.1 .A.1 UnIt 0 AvaIlability to 4.16 kV Shutdown Rev. 0012 Boards Page 10 of 21 6.0 ACCEPTANCE CRITERIA

[1] Responses which fail to meet the following acceptance criteria constitute unsatisfactory surveillance proóedure results and require immediate notification of the Unit Supervisor at the time of failure and documentation in accordance with NPG-SPP-06.9.1, Conduct of Testing.

[1.11 Unit 1(2) LCO 3.8.1 Condition A One required ofisite circuit inoperable.

Required Action A.t Verify power availability from the remaining OPERABLE offsite transmission network.

AcceptaiiceCrltedp At least one qualified circuit is available between the offaite transmission network and the onsite Class I E AC Electrical Power Distribution.

11.2] Unit 3 LCO 3.8.1 CondifiojiA One required offsite circuit inoperable.

RetuiredAction A.1 Verify power availability from the remaining OPERABLE ofisite transmission network.

Acceolance Criteria At least one qualified circuit is available between the offsfte transmission network and the onsite Class I E AC Electrical Power Distribution.

[1.3] Unit 1(2) LCO 3.8.1 Conditloria One required Unit 1/2 DG inoperable.

Required Action 8.1 Verify power availability from the offslte transmission network.

Acceptance Criteria At least two qualified circuits are available between the offsite transmission network and the onsite Class I E AC Electrical Power Distribution.

[1.4] UNIT 3 LCO 3.8.1 CojiditionB One required Unit S DG inoperable.

Reouired Action BA Verify power availability from the offsite transmission network.

AcceDJaJlce Criteria At least two qualified circuits are available between the offsite transmission network and the onsite Class I E AC Electrical Power Distribution.

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BFN Verification of Offslte Power 0-SR4.8.1 .A.1 Unit 0 Availability to 4.16 kV Shutdown Rev. 0012 Boards Pagellof2l 6.0 ACCEPTANCE CRITERIA (continued)

[1.9 Unit 1(2) LCO 3.81 Condition G One required offsite circuit inoperable and One required Unit 1 /2 DG inoperable (applicable when only one 4.16 Ky Shutdown Board is affected).

Rectuired ActioiiB,1 Verify power availability from the offsite transmission network.

AcceotanceCritena At least one qualified circuit is available between the offsite transmission network and the onsite Class I E AC Electrical Power Distribution.

[1.6] Unit 3 LCO 3.8.1 CondItion G One required offsite circuit inoperable and One required Unit 3 DG inoperable (applicable when only one 4.16 KV Shutdown Board is affected).

ReciuiredAction B.1 Verify power availability from the offsite transmission network.

Acceptance Ciiteria At least one qualified circuit is available between the offsite transmission network and the onsite Class I E AC Electrical Power Distribution.

[2] Steps which determine the above criteria are designated by (AC) next to the initials blank.

/

BFN VerificatIon of Offslte Power 0-SR4.8.1 .A.1 UnIt 0 AvailabIlity to 4.16 kV Shutdown Rev. 0012 Boards Page 12 of 21 Date PROCEDURE STEPS Initiation and Approvals VERIFY the following Initial conditions:

All Precautions and Limitations in Section 3.0 have been reviewed.

All Prerequisites listed in Section 4.0 are satisfied.

On the Surveillance Task Sheet (STS)

OBTAIN Authorization Signature and Dateflime from the Unit Supervisor to perform this surveillance.

LNRCICJ 1 Unit Two, and Unit Three NOTIFY the Unit One Operators (UOs) this test is commencing. T--1e. wao On the Surveillance Task Sheet (STS)

RECORD the Start Date & lime.

BFN Verification of Offsite Power 0-5R4.8.1 .A.1 UnIt 0 AvailabIlity to 4.16 kV Shutdown Rev. 0012 Boards Page 13 of 21 Date Technical Specification Required Action Determination DENOTE, via the check box, which Technical Specification Required Action is being met by performing this procedure.

A. Unit I Technical Specification 3.8.1 Required Action B.I.

(Requires iWO qualified AC circuits from the ofisite transmission system to the Unit 1/2 4kV Shutdown Bds when one Unit 1 /2 DG inoperable).

B. Unit 2 Technical Specification 3.8.1 Required Action B.1.

(Requires iWO qualified AC circuits from the offsite transmission system to the Unit 1 /24kV Shutdown Bds yhen one Unit 112 DG Inoperable).

Unit 3 Technical SpecificatIon 3.8.1 Required Action B.1.

(Requires TWO qualified AC circuits from the offsite transmission system to the Unit 34kV Shutdown Bds when one Unit 3 DG inoperable).

D. Unit I Technical Specification 3.8.1 Required Action A.I.

(Requires ONE qualified AC circuit from the offsite transmission system to the Unit 1 /2 4kV Shutdown Boards, when one required ofisite circuit inoperable). C E. Unit 2 Technical Specification 3.8.1 Required Action A.1.

(Requires ONE qualified AC circuit from the offsite transmission system to the Unit 1/2 4kV Shutdown Boards, when one required offslte circuit inoperable).

F. Unit 3 Technical Specification 3.8.1 Required Action A.1.

(Requires ONE qualified AC circuit from the offslte transmission system to the Unit 34kV Shutdown Boards, when one required ofisite circuit inoperable). C G. Unit 1(2) Technical Specification 3.8.1 Condition G.1.

(Requires ONE qualified AC circuit from the offsite transmission system to the Unit 1 /24kV Shutdown Boards, when one required offsite circuit inoperable and one Unit I and 2 Diesel Generator inoperable). C H. Unit 3 Technical Specification 3.8.1 Condition G.1.

(Requires ONE qualified AC circuit from the offsite transmission system to the Unit 34kV Shutdown Boards, when one required offsite circuit inoperable and one Unit 3 DIesel Generator inoperable).

BFN Verification of Offslte Power 0-SR4.8.1A.1 UnIt 0 Availability to 4.16 kV Shutdown Rev. 0012 Boards Page 14 of 21 Date Verification of Offslte 500kv and 161kv Sources TVAs Transmission Operator (TOp) is responsible for determining if the transmission grid is configured and operating within established limits that ensure the grids ability to provide QUALIFIED offsite power to Browns Ferry Nuclear Plant.

Southwest TOp phone number is 9-1-888-882-4009.

CONTACT the WA Southwest TOp to VERIFY the transmission grid Is able to provide QUALIFIED offsite power to BFN, In accordance with TRO-TO-SOP-30.128, Browns Ferry Nuclear Plant (BFN) Grid Operating Guide.

,( DOCUMENT the source qualificatIon below.

QUALIFIED UNQUAUFI ED 500KV SOURCE X I6IKVSOURCE 2z,otWL (vi4iI 0 COMPLETE Attachment I, document which subcomponents are credited as satisfying the requirements of a qualified offsite circuit for Unit I, Unit 2, and Unit 3 by marking the subcomponent with a circle around it and placing an initial next to the subcomponent.

1VJcicJL (ft:J(c g.

BFN Verification of Offsite Power 0-SR-3.8.1 Al UnIt 0 AvailabilIty to 4.1$ kV Shutdown Rev. 0012 Boards Pagel5of2l Date Verification of Offelte 500kv and 161kv Sources 0 (continued)

NOTE Specific voltmeters are j listed to allow the performer maximum flexibility when obtaining readings. However, Control Room Indications should be used whenever possible.

[4J IF performing this procedure to satisfy Technical Specification 3.8.1 Required Action A.1 or B.1 or G.1 for Unit I and Unit 2, THEN RECORD voltages for the following boards and CHECK proper voltage is available, (Otherwise NIA.)

A. 4KV SD BD A VOLTAGE Voltage (3950 4400 VOLTS)

- _JVA B. 4KV SD BD B VOLTAGE Voltage pJA (3950 4400 VOLTS)

C. 4KVSDBDCVOLTAGE Voltage i ,& (3950 4400 VOLTS)

D. 4KVSDBDDVOLTAGE Voltage ,J 1 (3950 -4400 VOLTS)

[ BFN Unit 0 Verification of Offslte Power AvaIlability to 4.16 kV Shutdown 0-SR-38.1.A.1 Rev. 0012 S. Boards Paqe 16 of 21 Verification of Offstte 500kv and 161kv Sources 0 (continued)

NOTE Specific voltmeters are listed to allow the performer maximum flexibility when obtaining readings. However, Control Room indications should be used whenever possible.

IF performing this procedure to satisfy Technical SpecificatIon 3.8.1 Required Action A.1 or B.1 or G.l for Unit 3, THEN RECORD voltages for the following boards and CHECK proper voltage Is available, (Otherwise N/A)

A. 4KV SD BD 3EA VOLTAGE Voltage JoRt \,irt (3950 4400 VOLTS)

QDliiJ1f (A(

B. 4KV SD BD 3EB VOLTAGE Vo1Iage VAeiLtU3950 4400 VOLTS) - 1;A!c C. 4KV SD BD 3EC VOLTAGE Voltage i,t (3950 4400 VOLTS)

- t 4

MtkJ 144 D. 4KV SD BD 3ED VOLTAGE Voltage \,trt (3950-4400 VOLTS) t 4

Jj 5 iJ oc,kJ ior 1 ru

BFN Verification of OffsltePower 0-SR4.8.1.A1 Unit 0 AvailabIlity to 4.16 kV Shutdown Rev. 0012 Boards Pagel7of2l Date 7 VerifIcation of Unit I and or Unit 2 Offalte AC Power Circuits 5

Step 7.4(1] and 7.4(2] may be mark S procedure is required to satisfy nit I and 2 TechnIcal SpecificatIon 3.8.1 Required Action A.1 or B.1.

Completed Attachment I is Utilized to EVALUATE offsite circuit availability.

[1] IF performing this procedure to satisfy Unit 1(2) Technical SpecIfication 3.8.1 Required Action B.1 (oneieoulred Uniti and 2 DGjrioperabte), THEN VERIFY at least Unit 1/2 Ofisite AC circuits are determined Operable in Attachment I and the shutdown boards Included in the Operable circuits have proper voltage verified in step 7.3[4].(Otherwise NIA). IL (AC)

[2] IF performing this procedure to satisfy Unit 1(2) Technical Specification 3.8.1 Required Action A.1 (oiieiequired offsite circuit inoperable), THEN VERIFY at least --- Unit 112 Offsite AC circuit is determined Operable in Attachment I and the shutdown boards included in the Operable circuit have proper voltage verified in step 7.3(4]. (Otherwise N/A) hi IS.. (AC)

(3] IF performing this procedure to satisfy Unit 1(2) Technical Specification 3.8.1 Condition G (oiteieciuired offslte_clrcuit inoperable_and one Unit I and 2 DG inoperable. THEN VERIFY at least g Unit 112 Offsite AC circuit is determined Operable in Attachment I and the Shutdown Boards included in the Operable circuit have proper voltage verified in step 7.3[4]. (Otherwise NIA) (AC)

BFN Verification of Offsite Power 0-SR-3.8.l Al UnIt 0 AvailabilIty to 4.16 kV Shutdown Rev. 0012 Boards Page 18 of 21 g Verification of Unit 3 Offsfte AC Power Circuits Date 7.5[1] and 7.5[2J may be mark1i1if this procedure Is required to satisfy 3 TechnIcal Specification 3.8.1 Required Action Al or B.1.

Completed Attachment I is Utilized to EVALUATE offsite circuit availability.

d IF performing this procedure to satisfy Unit 3 Technical Specification 3.8.1 RequIred Action B.1 (one reauiredjJnht 3 DG inoperable), THEN VERIFY at least q Unit 3 Offsite AC circuits are determined Operable in Attachment I and the shutdown boards included in the Operable circuits have proper voltage verified in step 7.3[5]. (Otherwise WA). oCS (AC)

[2] IF performing this procedure to satisfy Unit 3 Technical Specification 3.8.1 Required Action A.1 (oneretuired offsfte circuit inoperable), THEN VERIFY at least g Unit 3 Offsite AC circuit is determined Operable in Attachment I and the shutdown boards included in the Operable circuit have proper voltage verified In step 7.3[5J (Otherwise N/A).

[3] IF performing this procedure to satisfy Unit 3 TechnIcal Specification 3.8.1 CondItion G (one reGuire&offsite circuit inoierable and one Unit3 DG Inoierable. THEN VERIFY at least g Unit 3 Offsite AC circuit is determined Operable in Attachment I and the Shutdown Boards included in the Operable circuit have proper voltage verified In step 7.3[5J. (Otherwise N/A) tJjA (AC)

BFN Verification of Offslte Power 0-SR-3..8.1 Al UnIt 0 AvaIlability to 4.16 kV Shutdown Rev. 0012 Boards Page 19 of 21 Date Common Cause Failure Evaluation and Surveillance Completion EVALUATE the necessity to perform O-Tl-403, Determination of Common Cause Failure for Emergency Diesel Generators, if this surveillance is being performed for an inoperable Diesel Generator.

,gr On the Surveillance Task Sheet (STS) the Completion Date & Time.

REVIEW and COMPLETE the Surveillance Task Sheet (STS) through the Test Director!Lead Performer & Date fields.

NOTIFY the Unit One, Unit Two and Unit Three Operators (UOs) this Surveillance Procedure is complete.

NOTIFY the Unit Supervisor (US) this surveillance procedure is complete and PROVIDE status of any Corrective Actions or unsatisfactory performance.

4-8.0 ILLUSTRATIONSIAflACHMENTS Attachment I Table of Offsite and Onsite Circuits Assigned to Unit 1,2 and 3 w

BFN Verification of Offslte Power 0-SR4.8.1 .A.1 Unit 0 Availability to 4.16 kV Shutdown Rev. 0012 Boards Page 20 of 21 t

Attachment I 0PTp1bi j: Cotvtb,S c&q (Page 1 of 2) VtVfS(O(

O!

Table of OffsIto and Onsite Circuits Asslaned to UnIts 1, 2 and 3 UNITNO. land2 3 QUALIFIED CIRUJT 1 2 1 2 C tIrj USSTIB USST3B 0 USSTICSST USST2B tf2 M CSSTA CSSTA CSSTA p cssia CSSTB CSSTB CSSTB 0 FOR BKR 1412 81CR 1412 81CR 1412 (iRR141 N CSST A 81CR 1414 81CR 1414 KR 1414 81CR E ONLY 81CR 1518 81CR 1518 BKR 1518 81CR 1518 N B 81CR 1516 81CR 1516 BKR 1516 BKRI516 T STARTBUS START BUS IA STARTBUS IA STARTBUS IA 4YThT8iii START 8US 18 STARYBUS 18 STARTBUS 18 STARTBUS 18 0 BKRIII2 E FOR lB BKRIII4 8KR1114 S USST 81CR 1212 C ONLY 29 BKR 1214 BKR 1214 R 8KR1312 BKRI3I2 1 38 i&iii) BKR 1314 4-P FOR 81CR 1424 81CR 1424 81CR 1432 (IkR 1432 T CSST 1A 81CR 1428 81CR 1428 I ONLY 81CR 1524 81CR 1524 81CR 1528 81CR 1528 0 lB 81CR 1528 81CR 1528 N (RVUiTh]) 4KV UNIT BD IA 4KV UNIT SD 3A 4KV UNIT BD 4KV UNIT SD 18 4KV UNIT 8018 CNW 4KV UNIT SD 38 4KVUNITBD2A fUNrTBD2.7 4KVUNITBD2B 4KV UNIT SD 2B BKR 112691612 UNITI&2ONLY BKR1132&1712 BKRII32&1712 BKR 122691722 BKR 123291622 BKR 123291622 SHUTDOWN SD BUS I (SD) BUS SD BUS 2 SD2 UNIT3ONLY 81CR 1326 81CR 1326 BKR1332 SD SD FDR 81CR J614& BKR6 81CR 1614 & 81CR 1616 BKR 1334 & 81CR 1338 iRT334 & BKR1 BKR 1718 & 81CR 1724 KR 17i &8) f1l338 & 81CR i) B)cR1338 & 81CR 1342 4KV CiiiSD BD A& B) 4KV SD SD AS B 4KV SD SD 3EA & 3EB SHUTDOWN 80 4KV 8080 C & D (fSDDC) &3SD 4KV SD BD 3EC & 380 f See Attachment I page 2 for explanation and information for completing the above Table.

BFN Verification of Offslte Power 0-SR4.8.,1 .A.1 Unit 0 Availability to 4.16 kV Shutdown Rev. 0012 Boards Page 20 of 21 Attachment 1 OPTIo&) 2_

olurq If (Page 1 of 2) rtJWCt Table of Offslte and Onsite Circulls Assigned to Units 1. 2 and 3 UNITNO. land2 3 OUAL1FI CIRCUIT - 1 2 1 2 c USSTIB USST3B 0 USSTIcSST USST2B Ii CSSTA CSSTA CSSTA CSSTA P CSSTB CSSTB CSSTB 0 FOR 81CR 1412 81CR 1412 BKR 1412 81CR 1412 N CSST A BKR 1414 81CR 1414 81CR 1414 BKR 1414 8 ONLY 81CR 1518 81CR 1518 fkR1 81CR 1518 N B 81CR 1516 8KR 1515 81CR 1518 81CR 1516 T STARTBUS STARTBUS IA STARTBUS IA START BUS IA START BUS lB STARTBUS 18 STARTBUS lB START BUS 18 D 81CR 1112 8 FOR lB KR114 81CR 1114 S USST BKR 1212 A2i C ONLY 28 BKR 1214 81CR 1214 R BKR 1312 BKR 1312 38 BKR 1314 icRi3]

P FOR 81CR 1424 81CR 1424 T432 81CR 1432 T CSST IA 81CR 1428 81CR 1428 ONLY 81CR 1524 81CR 1524 81CR 1528 81CR 1528 0 lB 81CR 1526 81CR 1526 N cJVUNITBD IA) 4KVUNITBD1A RUNifBD3) 4KV.UNIT BD 4KV UNIT BO 4KVUNITBD 18 4KV UNIT BD lB 4KV UNITBD 38 (4KVUNITBD3B 4KV UNIT SD 2P VLJNFTBDZ 4KVUNITBD2B 4KV UNIT 8028 CKR f126 & iei 81CR 1126 5 1612 UNIT I & 2 ONLY 81CR 1132 & 1712 81CR 1132 5 1712 81CR 1226& 1722 co a 81CR 1232& 1622 BKR1232&1622 SHDO Cjs i) SDEU (SD) BUS SD BUS 2 fSD BUS 2)

UNIT 3 ONLY /KR1328) 81CR 1326 i__

81CR 1332 332 SD BD FDR 81CR SKR 1614 & BICR 181 81CR 1614 & 81CR 1618 334 &BKR133) BKR 1334 & 81CR 1336 BKR 1718& 81CR 1724 CL18 & 81CR i) 81CR 13385 81CR 1342 CBKR 13385 81CR 134) 41W DA&B 4KV SD SD AS B II7BD 3EA &? 4KV SD BD 3EA & 3E8 SHUTDOWN BD 4KV SD BOG & D - YSD BD ç) 4KV SD BD 3EC & 3ED BD 38C & B)

See Attachment I page 2 for explanation and Information for completing the above Table.

BFN Veiiflcatlon of Offsite Power 0-SR4.8.1 Al Unit 0 AvailabIlity to 4.16 kV Shutdown Rev. 0012 Boards Page 21 of 21 Attachment I (Page 2 of 2)

Following statements are applicable for completing Attachment 1:

1. Attachment I documents which subcomponents are credited as satisfying the requirements of a qualified offsite circuit for Unit 1, Units 2 and 3 by the performer of this procedure by marking the subcomponent with a circle around it and by placing an initial next to the subcomponent.

.2. Each subcomponent listed for Unit I and 2 can be marked in only ONE column. For example, subcomponent USST IB can be marked In only one column compared to the two options available.

3. Rows not required to be filled in for Unit 1, Units 2 or 3 are lined out with dashes.

4. 500 kV subcomponents and direct feeds are left justified; 161 kV subcomponents like CSST A and B, and associated breakers are right justified in italics Common subcomponents are centered in the respective blocks for clarity.

5. For an offsite circuit to be qualified at least one subcomponent shall be marked with a circle around it along with the Initial of the performer of the procedure for EACH associated component listed In the Component Description column.

Surveillance Task Sheet (STS)

WO: 111807079 PM#: P1905 0-SR-3.8.1 Al 1

Procedure:

Title:

0-SR4.6.l Al Veilficatlon of Offaite Power Av&Iabflity to 4.16 kV Shutdown Boards dhorizatlon toyfr 7 Date me Data Sheets Attached:

Pert Grp: OPS Unit: 1.2, and 3 LoopIDIv; iotStaft & Time A7flMf Completion ate & Time Test Reason: 3A Diesel Generator Inoperable Due Date:

Frequency: Conditional Tech Spec: ASME Xi:

Applicable Modes: Pert Modes: Model Clearance Required: EQ: LCO entered:

Dry Cask Storage: N Performed By:

Was this a Complete or Partial Performance?

Print Name initial Section Partial [j (Explain Partial In REMARKS below) Complete IJWLL.-

j*Y7 rv4 9,i /7rt./12 r :

i,Pc Were all Tech SpeclTech ROqI1SFSIICoCIODCMIFITe Prot reql t,LJAJ1 ,. S;c,t dL.

1 ,,/ AMSAC acceptance criteria satisfied? Yes [3 No)( NIA [3 p

Were au other acceptance Criteria satisfied? Yes [1 No [3 WA p4(

if all Tech SpeclTech ReqIISFSIICoCIODCMIFIre Prot reqIAMSAC Criteria were not satisfied, was a LCOIODCM actloy required?

(Explain in REMARKS below) Yes No (3 WA LI PWR only.

Subsequent Reviews:

Group: Sinnaturs Test Director eauertormer Date Acceptance Criteria Review: SRO Date & Time PERMANENT COMMENTS:

Independent Reviewer Date & Time nnI..,sns_ I.ItLFDJ-n. /r

- I flU fri.4 .q 1 - -

1e1 (Li ib 4kv Skd.i CA g,( r vot4ç 1S5 44.::4q1 #it rçrd 3cYvoW.

/

CccI S4ep WA RESTRICTED INFORMATION Today, 2012

Browns Ferry Nuclear Plant UnitO Surveillance Procedure O-SR-3.8.1 .A..1 Verification of Offsite Power Availability to 4.16 kV Shutdown Boards Revision 0012 Quality Related Level of Use: Continuous Use Level of Use or Other Information: Key Number P1905 Effective Date: 04-12-2011 Responsible Organization: OPS, Operations Prepared By: Keith Smith Approved By: Keith W. Benefield

BFN Verification of Offafte Power O-SR-3.8.1 .A.1 Unit 0 AvaIlability to 4.16 kV Shutdown Rev. 0012 Boards Page 2 of 21 Current Revision Description Type of Change: Enhancement Tracking Number: 013 PCRs: 11000692 Documentation: None Step 7.3[1] changed TRO-TO-SOP-1O.128 to TRO-TO-SOP-30.128

BFN Verification of Offslte Power 0-SR4.8.1 .A.1 UnIt 0 AvailabilIty to 4.16 kV Shutdown Rev. 0012 Boards Page3of2l Table of Contents 1.0 INrRODUCTION 4 1.1 Purpose 4 1.2 Scope 4 1.3 Frequency 4 1.4 Applicability 4

2.0 REFERENCES

5 2.1 Technical Specifications 5 2.2 UFSAR 5 2.3 Plant Instructions 5 2.4 TVA INSTRUCTIONS 5 2.5 Plant Drawings 6 3.0 PRECAIJ1IONS AND I_IMITATiONS .......fl 7 3.1 General Precautions 7 3.2 Operability and LCOs 7 3.3 Equipment 7 3.4 Qualified Grid Source 8 4.0 PREREQUISES S 5.0 SPECIAL TOOLS AND. RECOMMENDED EQUIPMENT 9 6.0 ACCEPTANCE CRITERIA ........fl.fl... 10 7.0 PROCEDURE STEPS ...* 12 7.1 InItiation and Approvals 12 7.2 Technical Specification Required Action Determination 13 7.3 Verification of Offsite 500kv and 161kv Sources 14 7.4 Verification of Unit I and or Unit 2 Offsite AC Power Circuits 17 7.5 Verification of Unit 3 Offsite AC Power Circuits 18 7.6 Common Cause Failure Evaluation and Surveillance Completion 19 8.0 ILLUSTRTIONSIAITACHMENTS ,, 19 Attachment 1: Table of Ofislte and Onsite CIrcuits Assigned to UnIts 1, 2 and 3 20

BFN Verification of Offslte Power 0$R-3.8.1 Al UnIt 0 Availability to 4.16 kV Shutdown Rev. 0012 t INTRODUCTION Boards Page 4 of 21 1.0 1.1 Purpose This procedure Is performed to verify power availability from the offsite transmission network to the onsite Class I E AC Electrical Power Distribution System in conformance with the requirements specified in Technical Specification 3.8.1 Required Action A.1 and B.1.

1.2 Scope This procedure verifies the availability of qualified circuits between the offsite transmission network and the onsite Class I E AC Electrical Power Distribution System. Qualification and continuity from the offsite electrical power supply to the onsite distribution network Is ensured by determining the:

[1] Qualification of the 500 KV and 161 KV off-site power system.

[2] Qualification of the 500KV and 161 off site power system.

[3] Configuration and operability for each of the four basic Unit 1/2 circuits from the transmission network to the safety related DMsion I and 114kV Shutdown Boards.

[4] Configuration and operability for each of the three basic Unit 3 cIrcuits from the transmission network to the safety related DMslon I and 114kV Shutdown Boards.

[5] Proper voltage on the 4.16 KV shutdown boards.

1.3 Frequency Performanceof this procedure is conditional, dependent on the status of required offslte circuits and Diesel Generators. This procedure shall be performed within one hour from the time:

[1] One required offsite circuit is declared inoperable, or

[21 One required Unit 1/2 DG is dedared inoperable, or

[3] One required Unit 3 DG is declared inoperable.

Then once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter, until each unit (in mode 1, 2 or 3) has two qualified offsite circuits operable and all required DIGs operable.

/

1.4 Applicability The requirements of this procedure are applicable in Modes 1, 2, and 3.

BFN Verification of Offslte Power 0-SR-3.8.1 Al Unit 0 Avallablilty to 4.16 kV Shutdown Rev. 0012 Boards Page 5 of 21

2.0 REFERENCES

21 TechnIcal Specifications Section B3.8.1, AC Sources Operating Section 3.8.1 ,AC Sources Operating 2.2 UFSAR Section 8.1, Summary Description Section 8.2, Generators Section 8.3, Transmission System -

Section 8.4, Normal Auxiliary Power System Section 8.5, Standby A-C Power Supply and Distribution Appendix F, Unit Sharing And Interactions 2.3 Plant Instructions O-GOI-300-4, Switchyard Manual O-OI-57A, Switchyard and 4160V AC Electrical System OPDP-1, Conduct of Operations NPG-SPP-O6.9.1, Conduct of Testing NPG-SPP-06.9.2, Surveillance Test Program 2.4 WA INSTRUCTIONS IGA-6, Inter-group Agreement TRO-TO-SOP-10.128 Browns Ferry Nuclear Plant (BFN) Grid Operating Guide

BFN Verification of Offslte Power 0-SR-3.8..l Al UnIt 0 AvaIlability to 4.16 kV Shutdown Rev. 0012 Boards Paqe 6 of 21 2.5 Plant Drawings 0-1 5E500-1, Key Diagram of Standby Auxiliary Power System 3-1 5E500-3, Key Diagram of Normal & Standby Auxfliary Power System O-45N500, Wiring Diagrams Development Single Line 045E506, Wiring Diagram Main Single Line SH 1161 Ky SWYD

BEN Verification of Offsite Power O-SR-3.81.A.1 Unit 0 AvaIlability to 4.16 kV Shutdown Rev. 0012 Boards Page 7 of 21 3.0 PRECAUTIONS AND UMITATIONS 3.1 General Precautions A. This procedure may be performed in any plant operating condition subject to the approval of the Unit Supervisor (US).

B. In the context of this procedure, equipment tagged and/or de-energized as indicated by indicating lights, control switch positions or indIcating meters in the Control Room is NOT AVAILABLE. Skill of the performer will be utilized to make this determination.

C. Only offsite power delivered to Unit 1/2 Shutdown Boards through their normal feeder breakers can be credited, since common accident signal (GAS) logic will trip the alternate breaker.

3.2 Operability and LCOs A. There are four basic Unit 112 cIrcuits from the transmission network to the safety related Division I and 114kV Shutdown Boards. For Units I and 2:

1. Only two of the four qualified circuits are REQUIRED to be operable.

2. lftwo of the four circuits are operable, then LCO 3.8.1.a Is satisfied.

B. There are three basic Unit 3 circuits from the transmission network to the safety related DMsion I and 114kV Shutdown Boards. For Unit 3:

1. Only two of the three qualified circuits are required to be operable.

2. If two of the three circuits are operable, then LCO 3.8.1 .a is satisfied.

3.3 EquIpment A. Multiple units can daim a 161kV offsite power circuit simultaneously. However, if a load is connected to a 4kV Start Bus, O-Ol-57A will initiate manual actions to disable automatic transfer of selected 4kV Unit Boards and 4kV Common Boards to the 161 kV circuits. The 161 kV source may still be considered operable with a delayed manual transfer.

With the most restrictive manual actions in place, diesel generators would supply the safety related loads needed to mitigate the immediate consequences of an accident or analyzed operational transient. Operators can manually transfer loads to the 4kV start bus to support long term post accident or transient recovery and shutdown.

BEN Verification of Offsite Power O-SR-3.8.1 Al Unit 0 Availability to 416 kV Shutdown Rev. 0012 t 3.4 QualIfied Grid Source Boards Page8of2l A. TVAs Transmission Operator (TOp) is responsible for determining if the transmission grid is configured and operating within established limits that ensure the grids ability to provide QUALIFIED offsite power to Browns Ferry Nuclear Plant.

B. This procedure verifies OPERABILITY for each of the seven basic AC circuits, from the offsite source to 4kV Shutdown boards (four Unit 112 circuits or three Unit 3 circuits). To be OPERABLE, each basic circuit must have a QUALIFIED offsite power source. The Browns Ferry Operator must request the WA Southwestern TOp to determine the QUALIFICATION status of the offsite power source (500kV or 161 kV) when performing this procedure.

C. A color code system is used to communicate the QUALIFICATION status of the offslte power sources, both for current conditions and for postulated grid contingencies. The TOp Will verbally inform Browns Ferry Operations of status color code changes in real-time. The status color code definitions and associated restrictions and requirements are contained in TRO-TO-SOP-10.128, Browns Ferry Nuclear Plant (BFN) Grid Operating Guide.

D. A QUALIFIED offsite circuit may be connected to more than one dMslon of 4kV shutdown boards and not violate separation criteria. A circuit that is not connected to the Division I or 114kV shutdown boards Is required to have the capability to be connected to at least one dMsion of 4kV shutdown boards to be considered OPERABLE.

BFN Verification of Offalte Power 0-SR-3.8.1.A..1 UnIt 0 AvailabilIty to 4.16 kV Shutdown Rev. 0012 Boards Page9of2l Date PREREQUISITES VERIFY this copy of O-SR-3.8.l Al is the current revision. _jz OBTAIN a Surveillance Task Sheet (STS) for this procedure A./ and Work Activity. (Key Number P1905) 5.0 SPECIAL TOOLS AND RECOMMENDED EQUIPMENT None

BFN Verification of Offslte Power O-SR-3.8.1 Al UnIt 0 AvailabilIty to 4.16 kV Shutdown Rev. 0012 Boards Page 10 of 21 6.0 ACCEPTANCE CRITERIA

[I] Responses which fail to meet the following acceptance criteria constitute unsatisfactory surveillance proóedure results and require immediate notification of the Unit Supervisor at the time of failure and documentation in accordance with NPG-SPP-08.9.1, Conduct of Testing.

[1.1] Unit 1(2) LCO 3.8.1 CondltlojiA One required offsite circuit inoperable.

Reouired ActionAl Verify power availability from the remaining OPERABLE offslte transmission network.

AcceotanceCriterta At least one qualified circuit is available between the offslte transmission network and the onsite Class I E AC Electrical Power Distribution.

11.2] Unit 3 LCO 3.8.1 Condition A One required offsite circuit Inoperable.

Reaulred Action A.1 Verify power availability from the remaining OPERABLE offsite transmission network.

Acceptance Criteria At least one qualified circuit is available between the offsite transmission network and the onsite Class I E AC Electrical Power Distribution.

[1.3] Unit 1(2) LCO 3.8.1 Condition B One required Unit 1 12 DG inoperable.

Required ActiojiBi Verify power availability from the offsite transmission network.

Acceptance Critena At least two qualified circuits are available between the offsite transmission network and the onsite Class I E AC Electrical Power Distribution.

[1.4] UNIT 3 LCO 3.8.1 Condition B One required Unit 3 DG Inoperable.

Required Action B+/-i Verify power availability from the offslte transmission network.

Acceptance Criteria At least two qualified circuits are available between the offslte transmission network and the onsite Class IE AC Electrical Power Distribution.

I,

BFN Verification of Offslte Power 0-SR4.8.1 .A.1 UnIt 0 AvallablUty to 4.16 kV Shutdown Rev. 0012 t Boards Page 11 of 21 6.0 ACCEPTANCE CRiTERIA (continued)

[1.5] Unit 1(2) LCO 3.8.1 Condition G One required offsite circuit inoperable and One required Unit 112 DG inoperable (applicable when only one 4.16 KV Shutdown Board is affected).

Reauired Action BA Verify power availability from the ofisite transmission network.

Acceptance Ciiteria At least one qualified circuit is available between the offslte transmission network and the onsite Class I E AC Electrical Power Distribution.

[1.6] Unit 3 LCO 3.8.1 Condition One required offsite circuit inoperable and One required Unit 3 DG inoperable (applicable when only one 4.16 Ky Shutdown Board is affected).

Reauired Action BA Verify power availability from the offsite transmission network.

Acceotance Criteria At least one qualified circuit is available between the offsite transmission network and the onsite Class I E AC Electrical Power Distribution.

[2] Steps which determine the above criteria are designated by (AC) next to the initials blank.

BFN Verification of Offsite Power 0-SR4.8.1.A.1 Unit 0 AvailabilIty to 4.16 kV Shutdown Rev. 0012 Boards Pagel2of2l Date 2 PROCEDURE STEPS Initiation and Approvals VERIFY the following initial conditions:

All Precautions and Limitations in Section 3.0 have been reviewed.

All Prerequisites listed in Section 4.0 are satisfied.

On the Surveillance Task Sheet (STS)

OBTAIN Authorization Signature and DatelTime from the Unit Supervisor to perform this surveillance.

c,cj NOTIFY the Unit One, Unit Two, and Unit Three Operators (UOs) this test is commencing. -S2-16, On the Surveillance Task Sheet (STS)

RECORD the Start Date & Time.

BFN Verification of Offalte Power 0-SR-3.8.1 .A.1 Unit 0 AvailabilIty to 4.16 kV Shutdown Rev. 0012 t Boards Page 13 of 21 Date

, Technical Specification Required Action Determination (I7 DENOTES via the check box, which Technical Specification Required Action is being met by performing this procedure.

A. Unit I Technical Specification 3.8.1 Required Action B.1.

(Requires iWO qualified AC circuits from the offsite transmission system to the Unit 1 /2 4kV Shutdown Bds when one Unit 1 /2 DG inoperable).

B. Unit 2 Technical Specification 3.8.1 Required Action B.1.

(Requires TWO qualified AC circuits from the offsite transmission system to the Unit 112 4kV Shutdown Bds yhen one Unit 112 DG inoperable). £3 Unit 3 Technical Specification 3.8.1 Required Action B.1.

(Requires TWO qualified AC circuits from the offsite transmission system to the Unit 34kV Shutdown Bds when one Unit 3 DG Inoperable).

D. Unit I Technical SpecIfication 3.8.1 Required Action A.1.

41 (Requires ONE qualified AC circuit from the offsite transmission system to the Unit 1 /2 4kV Shutdown Boards, when one required offsite circuit inoperable).

E. Unit 2 Technical SpecIfication 3.8.1 Required Action A.1.

(Requires ONE qualified AC circuit from the offsite transmission system to the Unit 1 /2 4kV Shutdown Boards, when one required offsite circuit inoperable). I]

F. Unit 3 Technical Specification 3.8.1 Required Action A.1.

(Requires ONE qualified AC circuit from the offslte transmission system to the Unit 34kV Shutdown Boards, when one required offsfte circuit inoperable). D G. Unit 1(2) Technical Specification 3.8.1 Condition G.1.

(Requires ONE qualified AC circuit from the offsite transmission system to the Unit 1 /2 4kV Shutdown Boards, when one required offsite circuit Inoperable and one Unit I and 2 Diesel Generator inoperable).

H. Unit 3 Technical Specification 3.8.1 Condition G.1.

(Requires ONE qualified AC circuit from the offsite transmission system to the Unit 34kV Shutdown Boards, when one required offsite circuit inoperable and one Unit 3 Diesel Generator inoperable). C

BFN Verification of Offslte Power 0-SR-3.8..1 Al UnIt 0 AvaIlability to 4.16 kV Shutdown Rev. 0012 Boards Paqe 14 of 21 Date Verification of Offslte 500kv and 161kv Sources TVAs Transmission Operator (TOp) Is responsible for determining if the transmission grid is configured and operating within established limits that ensure the grids ability to provide QUALIFIED offsite power to Browns Ferry Nuclear Plant.

Southwest TOp phone number is 9-1488-882-4009.

CONTACT the WA Southwest TOp to VERIFY the 7 transmission grid is able to provide QUAUFIED offsite power to BFN, in accordance with TRO-TO-SOP-30.128, Browns Ferry Nuclear Plant (BFN) Grid Operating Guide.

[21 DOCUMENT the source qualification below.

QUALIFIED UNQUALIFIED 500KV SOURCE C C 161KV SOURCE C C

[3J COMPLETE Attachment 1, to document which subcomponents are credited as satisfying the requirements of a qualified offsite circuit for Unit 1, Unit 2, and Unit 3 by marking the subcomponent with a circle around it and placing an initial next to the subcomponent.

BFN Verification of Offslte Power 0-SR3.8.1 .A.1

c. UnIt 0 AvailabIlity to 4.16 kV Shutdown Boards Rev. 0012 Pagel5of2l Date 7.3 VerIfication of Offslte 500kv and 161kv Sources (continued)

- NOTE Specific voltmeters are listed to allow the performer maximum flexibility when obtaining readings. However, Control Room indications should be used whenever possible.

[4] IF performing this procedure to satisfy Technical Specification 3.8.1 Required Action A.1 or B.1 or G.1 for Unit I and Unit 2, THEN RECORD voltages for the following boards and CHECK proper voltage Is available, (Otherwise NIA.)

A. 4KVSDBDAVOLTAGE Voltage (3950 4400 VOLTS)

B. 4KV SD BD B VOLTAGE Voltage (3950 4400 VOLTS)

C. 4KVSDBDCVOLTAGE Voltage (3950 4400 VOLTS)

D. 4KV SD BD D VOLTAGE Voltage (3950 4400 VOLTS)

BFN Verification of Offslte Power O-SR-3.8.l Al UnIt 0 Availability to 4.16 kV Shutdown Rev. 0012 Boards Page 16 of 21 Date 1IOAl 7.3 VerifIcation of OffsIte 500kv and 161kv Sources (continued)

NOTE Specific voltmeters are jig.j listed to allow the performer maximum flexibility when obtaining readings. However, Control Room indications should be used whenever possible.

[51 IF performing this procedure to satisfy Technical SpecificatIon 3.8.1 Required Action A.1 or B.1 or G.1 for Unft 3, THEN RECORD voltages for the following boards and CHECK proper voltage is available, (Otheiwise NIA)

A. 4KV SD BD 3EA VOLTAGE Voltage (3950 4400 VOLTS)

B. 4KV SD BD 3EB VOLTAGE Voltage (3950 4400 VOLTS)

C. 4KV SD BD 3EC VOLTAGE Voltage (3950 4400 VOLTS)

D. 4KV SD BD 3ED VOLTAGE Voltage (3950 4400 VOLTS) c V

BEN Verification of OfisltePower 0-SR-3.8.1.A.1 Unit 0 Availability to 416 kV Shutdown Rev. 0012 Boards Page 17 of 21 Date 7.4 Verification of Unit I and or Unit 2 Offslte AC Power Circuits NOTES

1) Step 7.4111 and 7.412) may be marked NIA if this procedure is required to satisfy Unit I and 2 Technical Specification 3.8.1 Required Action A.1 or B.1.

2) Completed Attachment I is Utilized to EVALUATE offsite circuit availability.

[1] IF performing this procedure to satisfy Unit 1(2) Technical SpecIfication 3.8.1 Required Action B.1 Lone reaulred Unit I and 2 DG inoperable), THEN VERIFY at least .q Unit 1/2 Offsite AC circuits are determined Operable in Attachment I and the shutdown boards included in the Operable circuits have proper voltage verified in step 7.3[4].(Otherwlse NIA).

[2] IF performing this procedure to satisfy Unit 1(2) Technical SpecIfication 3.8.1 Required Action A.1 (one reaulred offsite circuit inoperable), THEN VERIFY at least g Unit 1/2 Oftslte AC circuit is determined Operable in Attachment I and the shutdown boards included in the Operable circuit have proper voltage verified in step 7.3(4). (Otherwise NIA)

[3] IF performing this procedure to satisfy Unit 1(2) Technical Specification 3.8.1 Condition G (one retuired offsite circuit inoperableand one Unittand 2 DG inoperable. THEN VERIFY at least Unit 1/2 OffsIte AC circuit is determined Operable In Attachment I and the Shutdown Boards included in the Operable circuit have proper voltage verified in step 7.3[4]. (Otherwise N/A)

BFN Verification of Offsite Power 0-SR-3.8.1.A.1 Unit 0 AvailabilIty to 4.16 kV Shutdown Rev. 0012 Boards Page 18 of 21 Date 7.5 Verification of Unit 3 Offsite AC Power Circuits NOTES

1) Step 7.5[1] and 7.5[2] may be marked N/A if this procedure is required to satisfy Unit 3 Technical Specification 3.8.1 Required Action A.1 or B.1.

2) Completed Attachment I is Utilized to EVALUATE offsite circuit availability.

[13 IF performing this procedure to satisfy Unit 3 Technical Specification 3.8.1 RequIred Action B.I (one reauired Unit 3 DG inoperablei, THEN VERiFY at least Unit 3 Offsite AC circuits are determined Operable in Attachment I and the shutdown boards included in the Operable circuits have proper voltage verified in step 7.3[5]. (Otherwise NIA).

[21 IF performing this procedure to satisfy Unit 3 TechnIcal Specification 3.8.1 RequIred Action A.I (one required offsite circuit inoperabIe, THEN VERiFY at least g Unit 3 Offsite AC circuit is determined Operable in Attachment I and the shutdown boards included in the Operable circuit have proper voltage verified in step 7.3[5] (Otherwise N/A).

[3] IF performing this procedure to satisfy Unit 3 Technical Specification 3.8.1 Condition G (one required offsjtecircuit inoperable and one Unit_3 DG inoperable. THEN VERIFY at least Unit 3 Offsite AC circuit is determined Operable in Attachment I and the Shutdown Boards included in the Operable circuit have proper voltage verified in step 7.3[5]. (Otherwise NIA)

BFN Verification of Offslte Power 0-SR-3.8.1.A.1 UnIt 0 AvailabilIty to 4.16 kV Shutdown Rev. 0012 Boards Page 19 of 21 Date 7.6 Common Cause Failure Evaluation and Surveillance Completion

[1] EVALUATE the necessity to perform O-Tl-403, Determination of Common Cause Failure for Emergency Diesel Generators, if this surveillance is being performed for an inoperable Diesel Generator.

[2] On the Surveillance Task Sheet (STS)

A. RECORD the Completion Date & Time.

B. REVIEW and COMPLETE the Surveillance Task Sheet (STS) through the Test DirectorlLead Performer & Date fields.

[3] NOTIFY the Unit One, Unit Two and Unit Three Operators (UOs) this Surveillance Procedure is complete.

[4] NOTIFY the Unit Supervisor (US) this surveillance procedure is complete and PROVIDE status of any Corrective Actions or unsatisfactory performance.

8.0 ILLUSTRATIONSIATTACHMENTS Attachment I Table of Offsite and Onsite Circuits Assigned to Unit 1, 2 and 3 w

BFN Verification of Offslte Power 0$R-3.61.A.1 UnIt 0 AvaIlability to 4.16 kV Shutdown Rev. 0012 Boards Page 20 of 21 Attachment I (Page 1 of 2)

Table of and fht Circuits Asslaned to Units 1. 2 and 3 UNIT NO. I and 2 QUALIFIO CIRCUIT I 2 I 2 C rj? USSTIB USST3S USST3B 0 ussricssr ussr 29 M cSSTA . CSSTA CSSTA CSSTA p cssra CSSTB CSSTB CSSTB 0 FOR 81CR 1412 81CR 1412 BKR 1412 BKR 1412 N CSST A 21CR 1414 81CR 1414 21CR 1414 81CR 1414 E ONI.Y 81CR 1518 BKR 1518 BKR 1518 81CR 1518 N B 81CR 1516 81CR 1516 21CR 1516 81CR 1516 T START8US STARTBUS IA STARTBUS IA START SUS IA STARTBUS IA STARTBUS lB STARTBUS 18 STARTBUS 18 STARTBUS 18 D 81CR 1112 E FOR lB BKR11I4 BKR1II4

$ USST 81CR 1212 C ONLY 28 BKR 1214 81CR 1214 R BKR 1312 81CR 1312 38 81CR 1314 81CR 1314 p FOR 81CR 1424 81CR 1424 81CR 1432 81CR 1432 T CSST IA 81CR 1428 81CR 1428 om.v 81CR 1524 81CR 1524 81CR 1528 81CR 1528 0 lB BKR 1526 81CR 1525 N (41Wt)iniD]) 4KV UNIT SD IA 4KV UNIT 80 3A 4KV UNIT 80 3A 4KV UNIT SD 4KV UNIT SD lB 4KV UNIT SD lB 4KV UNIT SD 38 4KV UNIT SD 39 4KVUNITBD2A VUNITBD) 4KV UNIT SD 2B 4KV UNIT SD 22 gKR1126&181) 81CR 1126& 1612 UNFTI&2ONLY BKR1132&1712 BKR1132&1712 81CR 1226 & 1722 R122iii BKR1232&1622 BKR 123281622 SHUTDOWN SD BUS I (SD) BUS SD BUS 2 SD2 UNIT 3 ONLY BKR 1326 91CR 1328 BKR1332 81CR 1332 SD 80 FDR 81CR 1CR16I4& 81CR ite 81CR 1614 & 81CR 1616 BICR 1334 & 21CR 1338 81CR 1334 & 81CR 1336 81CR 1718 & 81CR 1724 LLKR 171 &BK72 81CR 1338 & 81CR 1342 81CR 1338 & BKR 1342 4KV ThCV SD SD A&) 4KV SD BDA & B 4KV SD BD 3E & 3EB 4KV SD SD 3EA & 328 SHU1DI so 4KV SD SD C & D (4KVSDBDC&PJ 4KVSDBD3EC&3ED 4KVSDBD3EC&3ED See Attachment I page 2 for explanation and information for completing the above Table.

w

BFN Verification of Offaite Power 0-SR4.8.1.A.1 UnIt 0 AvailabilIty to 4.16 kV Shutdown Rev. 0012 Boards Page 21 of 21 Attachment I (Page 2 of 2)

Following statements are applicable for completing Attachment I:

1. Attachment I documents which subcomponents are credited as satisfying the requirements of a qualified offsite circuit for Unit 1, UnIts 2 and 3 by the performer of this procedure by marking the subcomponent with a circle around it and by placing an initial next to the subcomponent.

.2. Each subcomponent listed for Unit I and 2 can be marked in only ONE column. For example, subcomponent USST IB can be marked in only one column compared to the two options available.

3. Rows not required to be filled in for Unit 1, Units 2 or 3 are lined out with dashes.

4. 500 kV subcomponents and direct feeds are left justified; 161 kV subcomponents like CSST A and B, and associated breakers are right justified in italics; Common subcomponents are centered in the respective blocks for clarity.

5. For an offslte circuit to be qualified at least one subcomponent shall be marked with a circle around It along with the initial of the performer of the procedure for EkC}1 associated component listed in the Component Description column.

Surveillance Task Shet (STS)

WO:

Procedure:

Title:

111807079 PM#:

0-SR.3.B,1 Al P1905 0-SR-3.8.1.A.1 Verification of Offslte PowerAvallability to 4.16kV Shutdown Boards Oats Sheets Attached:

t orlzatlon to Begi 7 Ø 7

IA D & Time i

Pert Grp: OPS Unit 1,2, and 3 LoopJDlv:

ThDAb1at/tR Start 0 & Time Et( Completion Date & Time Test Reason: 3A Diesel Generator Inoperable Due Date:

Frequency: Conditional Tech Spec: ASME XI:

Applicable Modes: Pen Modes: Model Clearance Required: EQ; LCO entered:

Dnj Cask Storage: N Performed By:

Was tills S Complete or Partiai Performance?

Print Name ainnahirn initial Section (Explain Partial In REMARKS below) Complete 3 Partial (3 i-,b4 ;,7 oI 77fr) i nk Were all Tech SpeclTech ReqIISFSIIC0CIODCMIFIre Prot reql

/ F AMSAC* acceptance criteria satisfied? Yes LI No II WA [3 Were all other acceptance Criteria satisfied? Yes 3 No LI WA LI if all Tech SpeclTech ReqflSFSIICoCIODCMIFIre Prot FeqIAMSAC Criteria were not satisfied, was a LCOIODCM action required?

(ExplaIn in REMARKS below) Yes (3 No (1 WA (3 PWR only.

Subsequent Reviews:

Group: Sisnature Test Director Lead Performer Date Acceptance Criteria Review: SRO Date & Time PERMANENT COMMENTS:

Independent Reviewer Data & Time REMARKS:

V WA RESTRICTED INFORMATION Today, 2012

F i N AL Admin RO PAGE 1 OF 10 OPERATOR:

RO SRO DATE:

JPM NUMBER: Admin RO Alb TASK NUMBER: Conduct of Operations TASK TITLE: 2-SR-2 ICS Computer points K/A NUMBER: 2.1.19 K/A RATING: RO 3.9 PRA: N/A TASK STANDARD: Perform Operator logs using ICS screens in accordance with 2-SR-2 Instrument Checks and Observations for log tables 1.1, 1.6, 1.25, and 1.30.

Verify acceptance criteria are satisfied in accordance with notes.

LOCATION OF PERFORMANCE: Unit 2 Simulator (ICS computer tenninal)

REFERENCES/PROCEDURES NEEDED: 2-SR-2 Rev 73 VALIDATION TIME: 20 minutes MAX. TIME ALLOWED: (Completed for Time Critical JPMs only)

PERFORMANCE TIME:

COMMENTS:

Additional comment sheets attached? YES NO RESULTS: SATISFACTORY UNSATISFACTORY SIGNATURE: DATE:

EXAMINER

INITIAL CONDITIONS: You are a Unit Operator assigned to Unit 2, and it is Friday morning at 0800. 2-SR-2, Instrument Checks and Observations, is being performed. All 2-SR-2 instrument checks and observations are complete with the exception of table 1.1, 1.6, 1.25, and 1.30.

INITIATING CUE: The Unit Supervisor directs you as the Unit Operator to complete 2-SR-2 for tables 1.1, 1.6, 1.25 and 1.30, utilizing only the ICS computer to obtain data.

Admin RO Aib PAGE 3 OF 10 Simulator INITIAL CONDITIONS: You are a Unit Operator assigned to Unit 2, and it is Friday morning at 0800. 2-SR-2, Instrument Checks and Observations, is being performed. All 2-SR-2 instrument checks and observations are complete with the exception of table 1.1, 1.6, 1.25, and 1.30.

INITIATING CUE: The Unit Supervisor directs you as the Unit Operator to complete 2-SR-2 for tables 1.1, 1.6, 1.25 and 1.30, utilizing only the ICS computer to obtain data.

Admin RO Aib PAGE 4 OF 10 START TIME____

Performance Step 1: Critical Not Critical X Refers to 2-SR-2, Instrument Checks and Observations, table 1.1 TABLE 1.1 CORE THERMAL POWERAND CORE POWER DISTRIBUTION DAY SHIFT WEEK: to APPLICABILIT: Model when 25% RTP Record toe readings as soon as possible after the generator breaker has been closed.

Criteria Source: 3.2.1.1;_3.2.2:1;_3.2.3.1;_DEFINITIONS SECTION_1.1_- FSAR 3.7.7 LOCAl ION: CS Computer (Case Summary CSUMI_______

- Review Inalals Core Percent TIME Thermal Power LIMIT MFLCPR MAPRAT MFDLRX LiMIT Unit DAY Note 2 Power (MWt) (% RTP) (AC) (Note 3) (Note 3) (Note 3) (AC) Operator Unit Supvr 0800 1000

. 1200 Fnday -

1600 1800 0800 1000 1200 Saturday -

1600 1000 Notes Notes 1&2 3,4,&5 1000 1200 Sunday ---

1600 18U0 0800 1000 1200 Monday 1400 1600 1800 NO] tS ARE FOLLOWING THE TABLE!

Standard:

Selects SR-2 Group Display from the Group Display menu OR types the code CSUM on ICS computer to obtain data and completes table 1.1 Data for Friday at 0800, Records approximate values of 3456 for MWt, 100% for RTP, .892 for MFLCPR, .667 for MAPRAT and .763 for MFDLRX.

SAT_ UNSAT N/A

Admin RO Aib PAGE 5 OF 10 Performance Step 2: Critical Not Critical (1) Compliance with the Licensed Power Limit (LPL) (3458 Mwt) is demonstrated by the following process:

A. No actions are allowed that would intentionally raise core thermal power above 3458 Mwt for any period of time. Small, short-term fluctuations in power that are not under the direct control of the unit operator are not considered intentional.

B. Closely monitor the thermal power during steady-state power operation with the goal of maintaining the two hour average at or below 3458 Mwt. If the core thermal power average for a 2-hour period is found to exceed 3458 Mwt, Operations take timely action to ensure that thermal power is less than or equal to 3458 MWt.

(This is implemented by taking action when any running average less than or equal to the 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months average exceeds 3458 Mwt.)

C. The core thermal power for an 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period (8 hr average) is not to exceed 3458 Mwt.

D. If an evolution is expected to cause a transient increase in reactor power that could exceed 3458 Mwt, action should be taken to lower core power prior to performing the evolution.

E. If power is > 3463, REDUCE power.

F. If power is 3458 to 3463 MWt after allowing time for recent perturbations to settle, REDUCE power and EVALUATE the trend.

0. If any running 30 mm average, 1 hr average, or 2 hr average is > 3458 MWt, REDUCE power.

(2) Core Thermal Power is normally recorded every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months when required. However, these readings may be marked N/A during TIP trace runs, control rod pattern adjustments, or anytime Core Monitoring System is blocked and/or <25%

power. The Reactor Engineer is responsible for monitoring Core Thermal Limits. Monitoring of Core Thermal Power and other Core Thermal Limits is recommended following completion of planned rise in power and following any unexpected power change. If core monitoring software becomes unavailable, the Shift Manager and Reactor Engineer shall determine the appropriate frequency for monitoring Core Thermal Power but should not exceed 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , using backup core monitoring computer, and taking into consideration current core conditions and margin to thermal limits.

Power changes should not normally be made without the core monitoring software being available.

(3) Consult the Reactor Engineer when value 0.9 85. Refer to 0-TI-248 for Administrative Limits.

(4) If any Turbine Bypass valve(s) are inoperable or a Recirculation Loop is out of service, Contact the Reactor Engineer and Refer To the COLR for Turbine Bypass Out of Service (TBOOS) or Single Loop Operation (SLO) limits which must be applied.

(5) MAPRAT within limits is used to verify that all APLHGRs are within the limits specified within the COLR.

MFDLRX within limits is used to verify that all LHGRs are within the limits specified within the COLR.

MFLCPR within limits is used to verify that all MCPRS are within the limits specified within the COLR.

Standard:

Initial for Unit Operator for Friday at 0800 when acceptance criteria is verified in accordance with above notes.

SAT_ UNSAT_ N/A COMMENTS:_______________________________

Admin RO Aib PAGE 6 OF 10 Performance Step 3: Critical Not Critical X Refers to 2-SR-2, Instrument Checks and Observations, table 1.6 TABLE 1.6 HEAT BALANCE RELATED CS ALARM SETPOINTS (Note 1) DAY SHIFT WEEK: to_______________

APPLICABILITY: Made I vAen 25% RTP Record the readings as soon as possible after the generator breaker has been closed, Cdteda Source: BFPER9519I4 LOCAT0N: ICS Computer Review Inftals ICS Points HI and HI HI alarm setpoints listed in 3-48A 3-46B 3-50A 3-SOB NSSOOI7 MAX Table 1.B.1 & 1.B.2 are NOT exceeded. (Note 3) Unit

(°F) (°F) (°F) (°F) (°F) DEV SAT/ UNSATIN!A UO Fdday Saturday Sunday 2°F Monday (Note 2)

Tuesday Wednesday Thursday (1( The computer points listed in Table 1.8. and l.B.2 are inputs to the CS Core Themial Power Heat Balance calculations. The points are rnonifored to ensure the inputs are in agreement and to ensure the license limits for themral power are maintained. In addition to the above, these points should be monfored any time reactor power changes are performed.

(2) A diiterence between Feedwaterteniperature points 3-48A, 3-48B, 3-50k 3-508, and NSSOO17 of greater than 2 degrees will require the notitcahon of Site Engineedng and suspending any nse in power untl the discrepancy is resolved.

(3) An alarm setpoint being eoceeded will require notifying the Unit Supervisor immediately and, faction cannot be taken immediately to return the value to within limits, Site Engineering will be notihed for assistance.

TABLE 1.8.1 TABLE lR2 ICS POINT DESCRIPTION HI ALARM HI HI ALARM ICS POINT DESCRIPTION HI ALARM HI HI ALARM CALCO2O Rx Power 30 Mm Avg. 3458 3463 3-48A FWTemp 382 386 CALCO21 Rx Power 1 Hr. Avg. 3458 3461 3-48B FWTemp 382 386 CALCO83 Rx Power 2 Hr. Avg. 3458 3459 3-50A FWTenip 382 386 CALCO98 Generator Power 1185 1158 3-SOB FWTen 382 386 CALCO26 Efficiency 35 36 NSSOOI7 Avg. FWTemp. 382 386 CALCO27 Load Line N/A 113.6 CONSO400 Total RWCU Flow 0.15 N!A CALCO24 RxPower% 100.2 100.5 Standard:

Selects SR-2 Group Display from the Group Display menu OR types the specific codes for each ICS point into the Single Value Display (for example: 3-48A, 3-48B, etc...) and completes table 1.6 Data for Friday. Records 377.2 for listed ICS points SAT UNSAT N/A COMMENTS:

Admin RO Alb PAGE 7 OF 10 Performance Step 4: Critical Not Critical (1) The computer points listed in Table l.B.l and l.B.2 are inputs to the ICS Core Thermal Power Heat Balance calculations. The points are monitored to ensure the inputs are in agreement and to ensure the license limits for thermal power are maintained. In addition to the above, these points should be monitored any time reactor power changes are performed.

(2) A difference between Feedwater temperature points 3-48A, 3-48B, 3-50A, 3-50B, and NSSOO17 of greater than 2 degrees will require the notification of Site Engineering and suspending any rise in power until the discrepancy is resolved.

(3) An alarm setpoint being exceeded will require notifying the Unit Supervisor immediately and, if action cannot be taken immediately to return the value to within limits, Site Engineering will be notified for assistance.

TABLE 1.81 ICS POINT DESCRIPTION HI ALARM HI HI ALARM CALGO2O Rx Power 30 Mm Avg. 3458 3483 CALC21 Rx Power i F-fr. ft&v. 41 CALCO83 Rc Power 2 Hr. vg. 3458 3459 CALCO8 Generator Power 1 185 11 0 CALCO2S Efficenoy 35 38 CALCO27 LoadLne NIA 113.6 CALCO24 xPower% 1002 100.

TA8LE 12 IC POINT ZECRIPTTON HI ALARM HI HI ALARM 3-48A FW Temp 382 -388 4 rw Tiip 3-5A FWTemp 386 3-S FW Temp 382 388 NSSD17 Av FWTrnp.. 382 388 CONCDC Total RWCU Flow 15 NSA Standard:

Documents Sat and initials for Unit Operator for Friday when Maximum Deviation between Feedwater temperature computer points are within 2 degrees (Note 2) and the conditions of Note 3 are satisfied lAW with tables 1.B.l and 1 .B.2.

SAT UNSAT_ N/A COMMENTS:_____________________________

Admin RO Aib PAGE 8 OF 10 Performance Step 5: Critical Not Critical X Refers to 2-SR-2, Instrument Checks and Observations, table 1.25 TABLE 1.25 LPRM INSTRUMENTATION DAY SHIFT WEEK: lv APPLICABILITY: Modes I &2 Readings are required at all times.

Criteria Source: Technical Requirements Manual TSR 3.3.5.3 LOCATION: Panel 2-9-14 and ICS Computer Review Initials

LPPAI5 BYPASSED TotalS #01 LPRM i (

LPRM5 readings APRM LPRM APRM LPRM APRM LPRM APRM LPRM Bypassed 03% on ICS MP3( 0EV All Data DAY TIME #2 #2 #4 #4 #3 #3 #1 #1 (Note 2) (Note 3) (AC) SAT/UNSAT UO Unit Sopor Friday 0800 Saturday 0800 Sunday 0800 Monday 222. (Note 4)

Tuesday 0800 Wednesday 0800 Thursday 0800 Standard:

Clicks on Live LPRM Display in the Nuclear Heat Balance menu and completes table 1.25 Data for Friday, #LPRMs reading <3% on ICS. Records ZERO SAT_ UNSAT N/A COMMENTS:________________________________

Performance Step 6: Critical Not Critical X (1) Record number of LPRMs bypassed in the four APRM and LPRM cabinets as observed at Panel 2-9-14.

Add these values together and record as Total # LPRMs Bypassed.

(2) Less than 20 LPRMs in OPERATE or Less than 3 per level for any APRM will result in a Rod Block and a trouble alarm on the display panel. This does not yield an automatic APRM trip, but does, however, make the associated APRM 1NOP.

(3) Record number of LPRMs reading less than 3% on the LPRM printout or display on ICS.

(4) MAX DEV is not required to be met when the APRMs are downscale; however, unexpected inconsistencies should be reported to the Reactor Engineer. The total number of LPRMs bypassed shall equal the number of LPRMs reading less than 3% on ICS.

Standard:

Documents Sat and initials for Unit Operator for Friday when the conditions of Note 4 are satisfied.

SAT_ UNSAT N/A COMMENTS:

Admin RO Alb PAGE 9 OF 10 Performance Step 7: Critical X Not Critical Refers to 2-SR-2, Instrument Checks and Observations, table 1.30 TABLE 1.30 REACTOR VESSEL STEAIVI DOME PRESSURE INSTRUMENTATION DAY SHIFT WEEK 10 APPLICABILITY: Modes 1 & 2 Reangs are reqred at all tsdes.

Suiveillance Requirenients: 3.3.1.1.1(13), 3.3.3.1.1, 3.4.10.1 LOCATION: ICS (Note 1 & 4) 2-9-86 2-9-85 2-9-84 2-9-83 ReVIew InliaIs MAX 0 C B A MAX Reference TIME DEV DEV MAX AJI Data Leg (Note 4) 3-74A 3-74B (AC) 2-PIS-3-22D 2-PIS-3-22C 2-PIS-3-22BB 2-PIS-3-22AA (AC) LIMIT SATIUNSAT UO Unit Supor Fdday 0804]

Saturday 0800 Sunday 0800 40ps 60 psig Note 3 No fl d ay (Note 2) (Note 2) Note 5 Tuesday 0800 Wednesday 0800 Thursday 0800 Standard:

Selects SR-2 Group Display from the Group Display menu OR types the specific codes for each ICS point into the Single Value Display (for example: 3-74A, 3-74B, etc...) and completes table 1.30 Data for Friday. Records approximately 1050 psig for ICS point 3-74A and approximately 1005 psig for ICS point 3-74B.

SAT_ UNSAT N/A COMMENTS:________________________________

Adinin RO Alb PAGE 10 OF 10 Performance Step 8: Critical Not Critical (1) These readings may be obtained from ICS using the Single Value Display or from the ATU output voltage translated into a PRESSURE Signal for the specific instruments. For ICS, type in SVD for Single Value Display, enter the point desired as 3-74A, record reading, select F4, enter 3 -74B, and record the second reading.

(2) 3-74A and 3-74B have a Maximum allowable deviation of 40 psig, AND 2-PIS-3-22D, 2-PIS-3-22C, 2-PIS-3-22BB, & 2-PIS-3-22AA, have a Maximum allowable deviation of 60 psig. No comparison is required between the 3-74A(B) and 2-PIS 22D(C)(BB)(AA).

(3) 3-74A and 3-74B SHALL be l 050 psig. 2-PIS-3-22D, 2-PIS-3-22C, 2-PIS-3-22BB, &

2-PIS-3-22AA SHALL be l090 psig.

(4) 3-74A and 3-74B are to be recorded at 0800. The Auxiliary Instrument Room readings are not required to be taken at precisely 0800.

(5) Following a change to Reactor Power or Pressure, verify the Steam Dome Limits are within the 0-TI-248, Administrative Limits and Design Analysis Limits (Appendix 5)

Standard:

Reviews notes and documents UNSAT and initials for Unit Operator for Friday when the conditions of Notes 2 and 3 are reviewed.

SAT_ UNSAT N/A COMMENTS:________________________________

END OF TASK STOP TIME

S C) ,4isiier e.j iN.

I BFN Instrument Checks and Observations 2-SR-2 Unit 2 Rev. 0073 Page 21 of 148 Attachment 2 (Page 1 of 86)

Surveillance Procedure Data Package - Modes 1,2, & 3 DAY SHIFT WEEK:

TABLE 1.1 CORE THERMAL POWER AND CORE POWER DIST BUTtON APPLICABILITY: Model when 25% RTP Record the readings as soon as possible after the generator breaker has been dosed.

Criteria Source: 3.2.1.1;_3.2.2.1;_3.2.3.1;_DEFINITIONS SECTION_1.1_- FSAR 3.7.7 Review Initials LOCATiON: ICS Computer (Case Summary CSUM)_______

Core Percent Power LIMIT MFLCPR MAPRAT MFDLRX LIMIT Unit TIME Thermal Unit Supvr

(% RTP) (AC) (Nole 3) (Note 3) (Note 3) (AC) Operator DAY Note 2 Power (MWt)

0800 3( Q.1 12471 t.714 1000

. 1200 Fnday 1400 1600 1800 0800 1000 1200 Saturday 1600 Notes Notes 1800 l&2 3,4,&5 0800 1000 1200 Sunday 1400 1600 1800 0800 1000 1200 Monday 1400 1600 1800 r i t ARE FOLLJVVIIai, THE TABLE!

Aver ke%i I BFN Instrument Checks and Observations 2-SR-2 Unit 2 Rev. 0073 Page 22 of 148 Attachment 2 (Page 2 of 86)

Surveillance Procedure Data Package - Modes 1,2, & 3 TABLE 1.1 CORE THERMAL POWER AND CORE POWER DISTRIBUTION DAY SHIFT WEEK: 1kc tiek to kK4- t)e k APPLICABILITY: Model when 25% RTP Record the readings as soon as possible after the generator breaker has been closed.

Criteria Source: 3.2.1.1; 3.2.2.1; 3.2.3.1;_DEFINITIONS SECTION_1.1_-_FSAR 3.7.7 Review Initials LOCATION: ICS Computer (Case Summary CSUM)_______

Core Percent Power LIMIT MFLCPR MAPRAT MFDLRX LIMIT Unit TIME Thermal Operator Unit Supvr

(% RTP) (AC) (Note 3) (Note 3) (Note 3) (AC)

DAY Note 2 Power (MWt) 0800 1000 1200 Tuesday 1400 1600 1800 0800 1000 Notes Notes 1200 ednesday 1&2 3,4,&5 1600 1800 0800 1000 1200 Thursday 1400 1600 1800 NOTES ARE ON THE FOLLOWING PAGEI

.)k: 4rwer \<e.1 BFN Instrument Checks and Observations 2-SR-2 UnIt 2 Rev. 0073 Page 23 of 148 Attachment 2 (Page 3 of 86)

Surveillance Procedure Data Package Modes 1, 2, & 3 -

(1) ComplIance with the Licensed Power Limit (LPL) (3458 Mwt) is demonstrated by the following process:

of time. Small, short-term fluctuations in power that are not A. No actions are allowed that would intentionally raise core thermal power above 3458 Mwt for any period under the direct control of the unit operator are not considered intentional.

two-hour average at or below 3456 Mwt. If the core thermal B. Closely monitor the thermal power during steady-state power operation with the goal of maintaining the timely action to ensure that thermal power is less than or equal to 3458 MWt. (This is power average for a 2-hour period is found to exceed 3458 Mwt, Operations take action when any running average less than or equal to the 2 hour average exceeds 3458 Mwt.)

implemented by taking C. The core thermal power for an 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period ( 8 hr average) is not to exceed 3458 Mwt.

should be taken to lower core power prior to performing the D. If an evolution is expected to cause a transient increase in reactor power that could exceed 3458 MM, action evolution.

E. If power is > 3463, REDUCE power.

EVALUATE the trend.

F. If power is 3458 to 3463 MWt after allowing time for recent perturbations to settle, REDUCE power and G. If any running 30 mm average, 1 hr average, or 2 hr average is> 3458 MWt, REDUCE power.

be marked NIA during TIP trace runs, control rod pattern adjustments.

(2) Core Thermal Power is normally recorded every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months when required. However, these readings may for monitoring Core Thermal Limits. Monitoring of Core Thermal or anytime Core Monitoring System is blocked andlor < 25% power. The Reactor Engineer is responsibte d following completion of planned rise in power and following any unexpected power change. If core monitoring Power and other Core Thermal Limits is recommende for monitoring Core Thermal Power but should not exceed the appropriate frequency software becomes unavailable, the Shift Manager and Reactor Engineer shall determIne margin to thermal limits. Power changes should not normally be 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , using backup core monitoring computer, and taking into consideration current core conditions and made without the core monitoring software being available.

(3) Consult the Reactor Engineer when value 0.985. Refer to O-Tl-248 for Administrative Limits.

Engineer and Refer To the COLR for Turbine Bypass Out of (4) If any Turbine Bypass valve(s) are inoperable or a Recirculatlon Loop is out of service, Contact the Reactor Service (TBOOS) or Single Loop Operation (SLO) limits which must be applied.

COLR.

(5) MAPRAT within limits is used to verify that all APLHGRs are within the limits specified within the MFDLRX within limits is used to verify that all LHGRs are within the limits specified within the COLR.

COLR.

MFLCPR within limits Is used to verify that all MCPRs are within the limits specified within the

%:C4 f1J ey

BFN Instrument Checks and Observations 2-SR-2 Unit 2 Rev. 0073 Page 30 of 148 Attachment 2 (Page 10 of 86)

Surveillance Procedure Data Package - Modes 1,2, & 3 TABLE 1.6 HEAT BALANCE RELATED ICS ALARM SETPOINTS (Note 1) DAY SHIFT WEEK: t 1h [AJe k to Mex[ Lk k.

APPLICABILITY: Mode 1 when 25% RTP Record the readings as soon as possible after the generator breaker has been dosed.

Criteria Source: BFPER95I9I4 Review Initials LOCATION: ICS Computer ICS Points HI and HI HI alarm setpoints listed in NSSOOI7 MAX Table 1.B.1 & 1.B.2 are NOT exceeded. (Note 3) Unit 3-48A 3-48B 3-50A 3-50B

(°F) DEV SAT I UNSAT I NIA UO Supvr

(°F) (°F) (°F) (°F)

Friday 377. 2s. 317. El 77 77* 2.

Saturday Sunday 2°F Monday (Note 2)

Tuesday Wednesday Thursday Balance calculations. The points are monitored to ensure tho Inputs are In agreement and to (1) The computer points lisied in Table I .B.1 and I .B.2 are inputs to the IC Core Thermal Power Heat be monItored any time reactor power changes are performed.

ensure the lIcense limits for thermal power are maintained. In addition to the above, these points should Feedwater temperature poInts 3-48A, 3-488, 3-50A, 3-50B, and NSSOOI7 of greater than 2 degrees will require the notification of Site Engineenng and suspending any rise (2) A difference between In power until the discrepancy Is resolved.

and, if action cannot be taken Immediately to return the value to within limits, Site Engineering will be (3) An alarm setpoint being exceeded will require notifyIng the Unit Supervisor immediately notified for assIstance.

TABLE 1.B.2 TABLE 1.B.1 HI HI ALARM ICS POINT DESCRIPTI ON HI ALARM HI HI ALARM ICS POINT DESCRIPTION HI ALARM -

CALCO2O Rx Power 30 Mm Avg. 3458 3463 3-48A FW Temp I 382 386 386 Rx Power 1 Hr. Avg. 3458 3461 3-488 FWTemp j 382 CALCO21 FWTemp j 382 386 Rx Power 2 Hr. Avg. 3458 3459 3-50A CAL.C083 FW Temp 382 386 CALCO98 GeneratorPower 1185 1190 3-SOB j 36 NSSOOI7 Avg. FW Temp. j 382 386 CALCO26 Efficiency 35 113.6 CONSO400 Total RWCU Flow L 0.15 N1A CALCO27 Load Line NIA CALCO24 Rx Power % 100.2 100.5

c:c* A,ier keyi.U $

BFN Instrument Checks and Observations 2-SR-2 Unit 2 Rev. 0073 Page 47 of 148 Attachment 2 (Page 27 of 86)

Surveillance Procedure Data Package Modes 1,2, & 3 TABLE 1.25 LPRM INSTRUMENTATION DAY SHIFT -

WEEK A 4C 1 k.. . to APPLICABILITY: Modes I & 2 Readings are required at all times.

Criteria Source: Technical Requlrementi Manual TSR 3.3.5.3 Review Initials LOCATION: Panel 2-9-14 and ICS Computer

LPRMs BYPASSED Total # # of LPRM (Note I) LPRMs readings APRM LPRM APRM LPRM APRM LPRM Bypassed 3% on ICS MAX DEV Au Data APRM LPRM (AC) SAT/IJNSAT UO Unit Supvr

2 #2 #4 #4 #3 #3 #1 #1 (Note 2) (Note 3)

DAY TIME Fnday 0800 0 95 0 ç 5 Ø Saturday 0800 Sunday 0800 0 Monday 0800 (Note 4)

Tuesday 0800 Wednesday 0800 Thursday 0800 2-9-14. Add these values together and record as Total # LPRMs Bypassed.

(1) Record number of LPRMs bypassed in the four APRM and LPRM cabinets as observed at Panel Less than 20 LPRMs in OPERATE or Less than 3 per level for any APRM will result in a Rod Block and a trouble alarm on the display panel. This does not yield an (2) automatic APRM trip, but does, however, make the associated APRM INOP.

(3) Record number of LPRMs reading less than 3% on the LPRM printout or display on ICS.

should be reported to the Reactor Engineer. The total number of (4) MAX DEV is not required to be met when the APRMs are downscale; however, unexpected Inconsistencies LPRMs bypassed shaH equal the number of LPRMs reading less than 3% on ICS.

) 44 Ap1Ler k BFN Instwment Checks and Observations 2-SR-2 Unit 2 Rev. 0073 Page 53 of 148 Attachment 2 (Page 33 of 86)

Surveillance Procedure Data Package Modes 1, 2, & 3 -

TABLE 1.30 REACTOR VESSEL STEAM DOME PRESSURE INSTRUMENTATION DAY SHIFT WEEK: 1k5 kkek &ex1- U)ee APPLICABILITY: Modes I & 2 ReadTngs are required at all times.

Surveillance Requirements: 3.3.1.1.1(13), 3.3.3.1 .1. 3.4.10.1 2-9-85 2-9-84 2-9-83 Review InitIals LOCATION: ICS (Note 1 & 4) 2-9-86 MAX D C B A MAX 0EV MAX All Data Reference TIME 0EV -

UO Unit Supvr 2-PIS-3-22C 2-PIS-3-22BB 2-PIS-3-22M (AC) LIMIT SATIUNSAT Leg (Note 4) 3-74A 3-748 (AC) 2-PIS-3-220 Friday 0800 fc) iac i-r /L;Lk Saturday 0800 Sunday 0800 60 psig Note 3 40 psig M 0 nd ay 0800 (Note 2) Note 5 (Note 2)

Tuesday 0800 Wednesday 0800 Thursday 0800 voltage translated into a PRESSURE Signal for the specific instruments.

(I) These readings may be obtained from ICS using the Single Value Display from the ATU output select F4, enter 3-74B, record the second reading.

For ICS, type in SVD for Single Value Display, enter the point desired as 3-74A, record reading,

, 2-PIS-3-22BB, & 2-PIS-3-22AA, have a Maximum allowable deviation of (2) 3-74A and 3-74B have a Maximum allowable deviation of 40 psig, AND 2-PIS-3-22D, 2-PIS-3-22C 60 psig. No comparison Is required between the 3-74A(8) and 2-PIS-3-22D (C)(BB)(AA ).

SHALL be 1090 psig.

(3) 3-74A and 3-74B SHALL be 1050 psig. 2-PIS-3-22D, 2-PIS-3-22C, 2-PIS-3-22BB, & 2-PIS-3-22AA Room readings are not required to be taken at precisely 0800.

(4) 3-74A and 3-74B are to be recorded at 0800. The Auxiliary Instrument verify the Steam Dome Limits are within the 0-Tt-248, Administrative Limits and Design Analysis Limits (Appendix S)

(5) Following a change to Reactor Power or Pressure,

I11I1_ L Main Alarms Graphics Trends Points Zoom/Layers Print Help 26-APR-2012 16:56:43 L*EECT F1JN(:. CSUM TRIGGER: CASE SUt+1RY pxa LAST POWERPLEX MONITOR CASE POWERPLEX HEAT BALANCE NOT UPDATING Date fl Date Ti1T Ti n REACTOR CONDITIONS CORE ThERMAL POL[R / CORE FLOW CTP (MWt) Rated CTP (MWL) Rated (M) Rated CTP CALCULATED FRM WT MLB/HR Rated Z Rated WT MLB/HR DHS B11J1LB WTSUB MLB/HR CAVEX MWTflITh WTF LAG EFF LOAD LINE IL CRD LOAD LINE(CTP, WT)

XENON 1kJRTh I i K-EFF PO[RPLEX DATA FILE READ STATUS CORE THERMLL LIMITS DATA CONSTANTS FOR ICS NSP6 PROGRAM Value IX JY K MFLCPR MAPRAT *1 VALUES FR1 LAST PPLX MONITOR CASE MFDLRX VALUES FR1 LAST PPLX HEAT BALANCE P-PCs

-RE&

P-PCFC CANCEL ESC)

F1=SET RATJ I F34!STOF4 LF4=J I LPOINTJ 3PP I ft/BAC C PU PU RUVEJ N U2 Sim TTTI4) LJ( , 4/wi ri I SIC LVI i

r.. POINTDY - -

ADIx1 Main Alarms Graphicc Trends Points ZoomlLayers Print Help PROCFSSLNG prini. request submilted to PR1{[COLOR 26-APR-2012 16:56:43

)RHt S[ L [CT FUNC. KF Y OR F URN ON (:0U [)

GROUP DISPLAY FOR @SR-2 Page 1 of 1 [uMrrs]

INSTRUMENT CHECKS Update rate 1.0 seconds PID QUAL VALUE UNITS DESCRIPTION CALCO2O (U(1L) MWT REACTOR POWER,NSSS - 30 MIN AVG CALCO21 (U1)D 156 MWT REACTOR POWER,NSSS - 1 HR AVG CALCO83 coon .156 MWT REACTOR POWER,NSSS - 2 HR AVG CALCO98 (U() I W() MWE MAIN GENERATOR POWER (FILTERED)

CALCO26 ((X)ti 218P Y EFFICIENCY (%)

CALCO27 1uUI I H) 3 LOAD LINE CALCO24 (0(II) IU() (1 REACTOR POWER, PERCENT RATED 3 48A

- ( ( II 3/1 2 D EG F RFW LI NE A TEMP (1 0 F 2) 34813 t1)0I) .?1 ? DEG F RFW LINE A TEMP (2 OF 2) 3-bOA (()t1f) 3/7.2 DEG F RFW LINE B TEMP (1 OF 2) 3-bOB (.(XE) 31/.? DEG F RFW LINE B TEMP (2 OF 2)

NSSOO17 (-tX 1 3/1 2 DEC F RFW TEMP TO REACTOR (AVG)96-14A ()0I 3M? MW RECIRC VFD A-OUTPUT POWER 96-1413 (;il 2.89 MW RECIRC VFD B-OUTPUT POWER CONSO400 (-00D 0. 1 2 MLB/HR TOTAL RWCU FLOW FOR NSSS TEST2500 GCX[ 120. I DEC F BULK VOLUMETRIC AVG DW TEMP 3-74A Cool) bOb PSIG RX PRESSURE-WIDE RANGE 3-74B 0001) 0O PSIG RX PRESSURE-WIDE RANGE METO48 ((X)[) 6O.() DEG F INTAKE RIVER TEMP METO4I (-(.X)1) h88 DEG F UPSTREAM FLOW-WEIGHTED 24HR TEMP ICALj RATE F3=HISTORY4 L S

T P

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1

I BFN Instrument Checks and Observations 2-SR-2 Unit 2 Rev. 0073 Page 21 of 148 Attachment 2 (Page 1 of 86)

Surveillance Procedure Data Package - Modes 1, 2, & 3 TABLE 1.1 CORE THERMAL POWER AND CORE POWER DISTRIBUTION DAY SHIFT WEEK: 13L-raeek. to iitI. 4 IAJh APPLICABILITY: Model when 25% RTP Record the readings as soon as possible after the generator breaker has been closed.

Cilteria Source: 3.2.1.1;_3.2.2.1;_3.2.3.1;_DEFINITIONS SECTION_1.1_- FSAR 3.7.7 Review Initials LOCATION: ICS Computer (Case Summary CSUM)_______

Core Percent Power LIMIT MFLCPR MAPRAT MFDLRX LIMIT Unit TIME Thermal Operator Unit Supvr

(% RTP) (AC) (Note 3) (Note 3) (Note 3) (AC)

DAY Note 2 Power (MWI) 0800 1000

. 1200 Fnday 1400 1600 1800 0800 1000 1200 Saturday 1400 1600 Notes Notes 1800 1&2 3,4,&5 0800 1000 1200 Sunday 1400 1600 1800 0800 1000 1200 Monday 1400 1600 1800 NOTES ARE FOLLOWING THE TABLEI

it BFN Instrument Checks and Observations 2-SR-2 Unit 2 Rev. 0073 Page 22 of 148 Attachment 2 (Page 2 of 86)

Surveillance Procedure Data Package - Modes 1,2, & 3 TABLE 1.1 CORE THERMAL POWER AND CORE POWER DISTRIBUTION DAY SHIFT WEEK: iii;s I,.-

WIFk 1 toJ.)CX. kd APPLICABILITY: Model when 25% RTP Record the readings as soon as possible after the generator breaker has been closed.

Criteria Source: 3.2.1.1;_3.2.2.1;_3.2.3.1;_DEFINITIONS SECTION_1.1_- FSAR 3.7.7 Review Initials LOCATION: ICS Computer (Case Smmary CSUM) -

Core Percent Power LIMIT MFLCPR MAPRAT MFDLRX LIMIT Unit TIME Thermal (AC) Operator Unit Supvr Note 2 Power (MWt) (% RTP) (AC) (Note 3) (Note 3) (Note 3)

DAY 0800 1000 1200 Tuesday 1400 1600 1800 0800 1000 Notes Notes 1200 3, 4, & 5 Wednesday 1400 1 &2 1600 1800 0800 1000 1200 Thursday 1400 1600 1800 NOTES ARE ON THE IOLLOWING PAGE!

1 4

4 I

O O4 iZ 7 BFN Instrument Checks and Observations 2-SR-2 Unit 2 Rev. 0073 Page 23 of 148 Attachment 2 (Page 3 of 86)

Surveillance Procedure Data Package Modes 1, 2, & 3 -

(1) Compliance with the Licensed Power Limit (LPL) (3458 Mwt) Is demonstrated by the following process:

A. No actions are allowed that would intentionally raise core thermal power above 3458 Mwt for any period of time. Small, short-term fluctuations in power that are not under the direct control of the unit operator are not considered intentional.

goal of maintaining the Iwo-hour average at or below 3458 Mwt. If the core thermal B. Closely monitor the thermal power during steady-state power operation with (he power average for a 2-hour period is found to exceed 3458 Mwt, Operations take timely action to ensure that thermal power is less than or equal to 3458 MWt. (This is average exceeds 3458 Mwt.)

Implemented by taking action when any running average less than or equal to the 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months C. The core thermal power for an 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period (8 hr average) is not to exceed 3458 Mwt.

exceed 3458 Mwt, action should be taken to lower core power prior to performing the D. If an evolution is expected to cause a transient increase in reactor power that could evolution.

E. If power is > 3463, REDUCE power.

REDUCE power and EVALUATE the trend.

F. If power is 3458 to 3463 MWL after allowing time for recent perturbations to settle, REDUCE power.

G. If any running 30 mm average, 1 hr average, or 2 hr average is >3458 MWt, readings may be marked NIA during TIP trace runs, control rod pattern adjustments, (2) Core Thermal Power is normally recorded every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months when required. However, these Reactor Engineer is responsible for monitoring Core Thermal Umlts. Monitoring of Core Thermal or anytime Core Monitoring System is blocked and!or < 25% power. The Limits is recommende d following completion of planned rise in power and following any unexpected power change. If core monitoring Power and other Core Thermal Engineer shall determine the appropriate frequency for monitoring Core Thermal Power but should not exceed software becomes unavailable, the Shift Manager and Reactor core conditions and margin to thermal limits. Power changes should not normally be 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , using backup core monitoring computer, and taking into consideration current made without the core monitoring software being available.

(3) Consult the Reactor Engineer when value 0.985. Refer to 0-Tl-248 for Administrative Limits.

Contact the Reactor Engineer and Refer To the COLR for Turbine Bypass Out of (4) If any Turbine Bypass valve(s) are Inoperable or a Recirculation Loop is out of service, Service (TBOOS) or Single Loop Operation (SLO) limits which must be applied.

within the COLR.

(5) MAPRAT within limits is used to verify that all APLHGRs are within the limits specified the COLR.

MFDLRX within limits is used to verify that all LHGRs are within (he limits specified within within the COLR.

MPLCPR within limits is used to verify that all MCPRS are within the limits specified

a(i# ffMdo-4

BFN Instrument Checks and Observations 2-SR-2 Unit 2 Rev. 0073 Page 30 of 148 Attachment 2 (Page 10 of 86)

Surveillance Procedure Data Package Modes 1,2, & 3 -

TABLE 1.6 HEAT BALANCE RELATED ICS ALARM SETPOINTS (Note 1) DAY SHIFT WEEK; lWs 1 L 1 ,ik to AC) Wetk APPLICABILITY: Model when 25% RTP Record the readings as soon as possible after the generator breaker has been closed.

Criteria Source: BFPER9519I4 Review Initials LOCATION: ICS Computer ICS Points HI and HI HI alarm setpoints listed In 3-50A 3-SOB NSSOO1 7 MAX Table I .B.1 & I .B.2 are NOT exceeded. (Note 3) Unit 3-48A 3-48B (CF) (°F) 0EV SAT / UNSAT / N/A UO Supvr

(°F) (°F) (°F)

Friday Saturday Sunday 2°F Monday (Note 2)

Tuesday Wednesday Thursday calculations. The points are monitored to ensure the Inputs are in agreement and to (1) The computer points llsLed in Table 1.B.1 and 1.B.2 are Inputs to the ICS Core Thermal Power Heat BalancemonItored any time reactor power changes are performed.

ensure the license limits icr thermal power are maintained. In addition to the above, these points should be greater than 2 degrees will require the notification of Site Engineering and suspending any rise (2) A difference between Feedwater temperature points 348A, 348B, 3-50A, 3-508, and NSSOO17 of In power until the discrepancy is resolved.

be taken immediately to return the value to within limits, Site Engineering will be (3) An alarm setpoint beIng exceeded will require notifying the Unit Supervisor immediately and, If action cannot notified for assistance.

TABLE I .B.2 TABLE 1.8.1 HI HI ALARM ICS POINT DESCRIPTION HI ALARM HI HI ALARM ICS POINT DESCRIPTION HI ALARM 3463 3.48A FWTemp 382 386 CALCO2O Rx Power 30 Mm Avg. 3458 3458 3461 3-48B AN Temp 382 386 CALCO2I Rx Power 1 Hr. Avg. 382 386 3458 3459 3-50A FW Temp CALCO83 Rx Power 2 Hr. Avg. 382 386 Generator Power 1185 1i90 3-SOB FW Temp CALCO98 Avg. FWTemp. 382 386 EfficIency 35 36 NSSOOI7 CALCO26 0.15 NIA Load Line NfA 113.6 CONSO400 Total RWCU Flow CALCO27 CALCO24 Rx Power % 100.2 100.5

JE*( S-f c f(%c.4 I BFN Instrument Checks and Observations 2-SR-2 Unit 2 Rev. 0073 Page 47 of 148 Attachment 2 (Page 27 of 86)

Surveillance Procedure Data Package Modes 1, 2, & 3 TABLE (.25 LPRM INSTRUMENTATION DAY SHIFT WEEK: kc4 !)ek APPLICABILITY: Modes I & 2 Readings are required at all times.

Criteria Source: Technical Requirements Manual TSR 3.3.5.3 Review Initials LOCATION: Panel 2.9-14 and ICS Computer

LPRMs BYPASSED Total # # of LPRM (Note 1 LPRMS readings LPRM APRM LPRM APRM LPRM Bypassed 3% on ICS MAX 0EV All Data APRM LPRM APRM SATIUNSAT UO Unit Supvr

2 #4 #4 #3 #3 #1 #1 (Note 2) (Note 3) (AC)

DAY TIME #2 -

Friday 0800 tZ (% ci 0 Saturday 0800 Sunday 0800 Monday 0800 (Note 4)

Tuesday 0800 Wednesday 0800 Thursday 0800 Panel 2-9-14. Add these values together and record as Total # LPRMs Bypassed.

(1) Record number of LPRMs bypassed in the four APRM and LPRM cabinets as observed at Rod Block and a trouble alarm on the display panel. This does not yield an (2) Less than 20 LPRMs in OPERATE or Less than 3 per level for any APRM will result in a automatic APRM trip, but does, however, make the associated APRM INOP.

(3) Record number of LPRMs reading less than 3% on the LPRM printout or display on ICS.

inconsistencies should be reported to the Reactor Engineer. The total number of (4) MAX DEV is not required to be met when the APRMs are downscale; however, unexpected LPRMs bypassed shall equal the number of LPRMs reading less than 3% on (CS.

1 V BFN Instrument Checks and Observations 2-SR-2 Unit 2 Rev. 0073

- Page 53 of 148 Attachment 2 (Page 33 of 86)

Surveillance Procedure Data Package Modes 1,2, & 3 -

TABLE 1.30 REACTOR VESSEL STEAM DOME PRESSURE INSTRUMENTATION DAY SHIFT WEEK 1h lMik Oe,c4- (_titek APPLICABILITY: Modes I & 2 Readings are required at all times.

Surveillance Requirements: 3.3.1.1.1 (f3), 3.3.3.1.1

3.4.10.1 2-9.86 2-9-85 2-9-84 2-9-83 Review Initials LOCATION: ICS (Note I & 4)

MAX D C B A MAX DEV DEV MAX All Data Reference TIME SATIUNSAT LJO Unit Supvr (Note 4) 3-74A 3-748 (AC) 2-PIS-3-22D 2-PIS-3-22C 2-PIS-3-22BB 2-PIS-3-22A4 (AC) LIMIT Leg Friday 0800 fD35 Saturday 0800 Sunday 0800 40 psi 9 60 psig Note 3 M on d ay 0800 (Note 2) (Note 2) Note 5 Tuesday 0800 Wednesday 0800 Thursday 0800 into a PRESSURE Signal for the specific instruments.

(1) These readings may be obtained from ICS using the Single Value Display g from the ATU output voltage translated enter the point desired as 3-74A, record reading, select F4, enter 3-74B, record the second reading.

For ICS, type in SVD for Single Value Display, B, & 2-PIS-3-22A A, have a Maximum allowable deviation of (2) 3-74A and 3-74B have a Maximum allowable deviation of 40 psig, AND 2-PIS-3-22D, 2-PIS-3-22C, 2-PIS-3-22B 60 psig. No comparison is required between the 3-74A(B) and 2-PIS-3-22D (C)(BB)(AA ).

(3) 3-74A and 3-74B SHALL be 1050 psi . 2-PIS-3-22D, 2-PIS-3-22C, 2-PIS-3-22B5. & 2-PIS-3-22AA SI-tALL be 1090 psig.

9 taken at precisely 0800.

(4) 3-74A and 3-74B are to be recorded at 0800. The Auxiliary Instrument Room readings are not required to be Pressure, verify the Steam Dome Limits are within the O-TI-248, Administrati ve Limits and Design Analysis Limits (Appendix S)

(5) Following a change to Reactor Power or

(

(.

Admiri RO Alb PAGE 1 OF 10 OPERATOR:

RO SRO DATE:

JPM NUMBER: Admin RO Alb TASK NUMBER: Conduct of Operations TASK TITLE: 3-SR-2 ICS Computer points K/A NUMBER: 2.1.19 K/A RATING: RO 3.9 PRA: N/A TASK STANDARD: Perform Operator logs using ICS screens in accordance with 3-SR-2 Instrument Checks and Observations for log tables 1.1, 1.6, 1.25, and 1.30.

Verify acceptance criteria are satisfied in accordance with notes.

LOCATION OF PERFORMANCE: Unit 3 Simulator (ICS computer terminal)

REFERENCES/PROCEDURES NEEDED: 3-SR-2 Rev 70 VALIDATION TIME: 20 minutes MAX. TIME ALLOWED: (Completed for Time Critical JPMs only)

PERFORMANCE TIME:

COMMENTS:

Additional comment sheets attached? YES NO RESULTS: SATISFACTORY UNSATISFACTORY SIGNATURE:__________________ DATE:_______

EXAMINER

INITIAL CONDITIONS: You are a Unit Operator assigned to Unit 3, and it is Friday morning at 0800. 3-SR-2, Instrument Checks and Observations, is being performed. All 3-SR-2 instrument checks and observations are complete with the exception of table 1.1, 1.6, 1.25, and 1.30.

INITIATING CUE: The Unit Supervisor directs you as the Unit Operator to complete 3-SR-2 for tables 1.1, 1.6, 1.25 and 1.30, utilizing only the ICS computer to obtain data

Admin RO Alb PAGE 3 OF 10 Simulator INITIAL CONDITIONS: You are a Unit Operator assigned to Unit 3, and it is Friday morning at 0800. 3-SR-2, Instrument Checks and Observations, is being performed. All 3-SR-2 instrument checks and observations are complete with the exception of table 1.1, 1.6, 1.25, and 1.30.

INITIATING CUE: The Unit Supervisor directs you as the Unit Operator to complete 3-SR-2 for tables 1.1, 1.6, 1.25 and 1.30, utilizing only the ICS computer to obtain data

Admin RO Aib PAGE 4 OF 10 START TIME____

Performance Step 1: Critical Not Critical X Refers to 3-SR-2, Instrument Checks and Observations, table 1.1 TABLE 1.1 CORE THERMAL POWER AND CORE POWER DISTRIBUTION DAY SHIFT WEEK: to____________

APPLICABILITY: Model when 25% RTP (Refer To P&L Step 3.6A)

RECORD the readings as soon as possible after the generator breaker has been dosed.

Cdtdaa Source: 3.2.1.1; 3.2.2.1; 3.2.3.1; DEFINITIONS SECTION 1.1_- FSAR 3.7.7 LOCATION: ftDS Computer (Case Summary CSUM)

- Review Initials TIME Core Thermal Percent Power LIMIT MFLCPR MAPRAT MFDLRX LIM[ Unft Unit DAY Note 2 Power (MWI) (% RTP) JL Note 3 Note 3 Note 3 JL Operator 0800 1000 1200 Fnday 1400____

1600 1800 0800 1000 1200 Saturday 1600 1800 Notes I Notes 3,4,&

1000 Sunday 1600 1800 0800 1000 Monday --

1600 1800 NOTES it<E FOLLOWING 1 HE TABLE!

Standard:

Selects SR-2 Group Display from the Group Display menu OR types the code CSUM on ICS computer to obtain data and completes table 1.1 Data for Friday at 0800, Records approximate values of 3456 for MWt, 100% for RTP, .876 for MFLCPR, .766 for MAPRAT, and .838 for MFDLRX SAT_ UNSAT N/A COMMENTS:________________________________

Admin RO Aib PAGE 5 OF 10 Performance Step 2: Critical Not Critical X (1) Compliance with the Licensed Power Limit (LPL) (3458 Mwt) is demonstrated by the following process:

A. No actions are allowed that would intentionally raise core thermal power above 3458 Mwt for any period of time. Small, short-term fluctuations in power that are not under the direct control of the unit operator are not considered intentional.

B. Closely monitor the thermal power during steady-state power operation with the goal of maintaining the two-hour average at or below 3458 Mwt. If the core thermal power average for a 2-hour period is found to exceed 3458 Mwt, Operations take timely action to ensure that thermal power is less than or equal to 3458 MWt.

(This is implemented by taking action when any running average less than or equal to the 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months average exceeds 3458 Mwt.)

C. The core thermal power for an 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period ( 8 hr average) is not to exceed 3458 Mwt.

D. If an evolution is expected to cause a transient increase in reactor power that could exceed 3458 Mwt, action should be taken to lower core power prior to performing the evolution.

E. IF power is > 3463, REDUCE power.

F. IF power is 3458 to 3463 MWt afler allowing time for recent perturbations to settle, REDUCE power and EVALUATE the trend.

G. IF any running 30 mm Avg, 1 hr average, or 2 hr average is > 3458 MWt, REDUCE power.

(2) Core Thermal Power is normally recorded every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months when required. However, these readings may be marked N/A during TIP trace runs, control rod pattern adjustments, or anytime Core Monitoring System is blocked andlor <25%

power. The Reactor Engineer is responsible for monitoring Core Thermal Limits. Monitoring of Core Thermal Power and other Core Thermal Limits is recommended following completion of planned rise in power and following any unexpected power change. If core monitoring software becomes unavailable, the Unit Supervisor/SRO and Reactor Engineer shall determine the appropriate frequency for monitoring Core Thermal Power but should not exceed 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , using backup core monitoring computer, and taking into consideration current core conditions and margin to thermal limits. Power changes should not normally be made without the core monitoring software being available.

(3) Consult Reactor Engineer when value 0.985. Refer to 0-TI-248 for Administrative Limits.

(4) If any Turbine Bypass valve(s) are inoperable or a Recirculation Loop is out of service, contact the Reactor Engineer and refer to the COLR for Turbine Bypass Out of Service (TBOOS) or Single Loop Operation (SLO) limits which must be applied.

(5) MAPRAT within limits is used to verify that all APLHGRs are within the limits specified within the COLR.

MFDLRX within limits is used to verify that all LHGRS are within the limits specified within the COLR.

MFLCPR within limits is used to verify that all MCPRS are within the limits specified within the COLR.

Standard:

Initial for Unit Operator for Friday at 0800 when acceptance criteria is verified in accordance with above notes.

SAT_ UNSAT N/A COMMENTS:_______________________________

Admin RO Aib PAGE 6 OF 10 Performance Step 3: Critical Not Critical X Refers to 3-SR-2, Instrument Checks and Observations, table 1.6 TABLE 1.6 HEAT BALANCE RELATED ICS ALARM SE[POINTS (Note 1) DAY SHIFT WEEK:

APPLICABILITY: Model tien 25% RTP(ReferTo P&L Step 3.6A)

RECORD the readings as sn as possible after the generator breaker has been closed.

Cdtetia Source: BFPER9519I4 LOCATION; ICS Corsputer Redew Initials CS Poin Verity HI and HI HI alanii setpoints listed in MAX DEV Table 1.B.1 & 1.B.2 are NOT exceeded. (Note 3) Unit 3-48A (°F) 3A8R (°P) 3-56A (°F) 3-508 (°F) NSSOO1J (°F) Note 2 SAT) IINSAT I N/A 110 Friday Saturday Sunday Monday 2F Tuesday

)ednesday Thursday Standard:

Selects SR-2 Group Display from the Group Display menu OR types the specific codes for each ICS point into the Single Value Display (for example: 3-48A, 3-48B, etc...) and Completes table 1.6 Data for Friday. Records 377.2 for listed ICS points SAT_ UNSAT N/A COMMENTS:_______________________________

Admin RO Aib PAGE 7 OF 10 Performance Step 4: Critical Not Critical X (1) The computer points listed in Table 1.B.l and 1.B.2 are inputs to the ICS Core Thermal Power Heat Balance calculations. The points are monitored to ensure the inputs are in agreement and to ensure the license limits for thermal power are maintained. In addition to the above, these points should be monitored any time reactor power changes are performed.

(2) A difference between Feedwater temperature points 3-48A, 3-48B, 3-50A, 3-50B, and NSSOO17 of greater than 2 degrees will require the notification of Site Engineering and suspending any rise in power until the discrepancy is resolved.

(3) An alarm setpoint being exceeded will require notifying the Unit Supervisor immediately and, if action cannot be taken immediately to return the value to within limits, Site Engineering will be notified for assistance.

TABLE 1B1 IC POINT DE9CRPTION RI ALARM R H ALARM CALCO2O Rc Power 30 Mm Avg 3458 3483 CALCO21 Rx Power 1 Hr Avg. 3488 3481 CALCO83 Rx Power 2 Hr Avg. 3488 3489 CALCOQ8 Gnertor Pwr 11 11 O CALCO2 Efficency 38 38 CALCO2I Load Lne NIA 11 36 CALCO24 Rx Power % 10O2 1OO6 TABLE LB2 IGS POINT DE8CRIPTiON H ALARM HI HI ALARM a-48A FWTmp 382 3-48B FWTmp 382 B6 3-DA FWTmp 382 a8 3-505 FWTmp 382 3813 N330017 Avg. AN Temp. 382 3813 COP1S04D TatI RWCU FIw 0,158 NIA Standard:

Documents Sat and initials for Unit Operator for Friday when Maximum Deviation between Feedwater temperature computer points are within 2 degrees (Note 2) and the conditions of Note 3 are satisfied JAW with tables l.B.l and l.B.2. S SAT_ UNSAT N/A COMMENTS:_____________________________

Admin RO Aib PAGE 8 OF 10 Performance Step 5: Critical Not Critical X Refers to 3-SR-2, Instrument Checks and Observations, table 1.25 TABLE 125 LPRM INSTRUMENTATION DAY SHIFT WEEK:

APPLICABILITY: Modes 1 & 2 Readings ore required at all times.

(Reter To P&L Step 3.GA(

Criteria Source: TecEnical Requirements Manual TSR 3.3.9-3 LOCATION: Panel 3-9-14 and ICS Computer ReVere lrribaIs

LPRM5 BYPASSED (Note I ( Total B # LPRM5 LPRM5 reading MAX 0EV APRM LPRM APR11 LPRM APRM LPRM APR11 LPRM Bypassed 3% on ICS (AC) All Data DAY TIME #2 #2 #4 #4 #3 #3 #1 #1 (Note 2) (Note 3) (Note 4( SATIUNSAT UO Unit Sopor Friday 0800 Saturday 0800 Sunday 0880 Monday 0900 Tuesday 0800 Wednesday 0800 Thursday 0800 Standard:

Clicks on Live LPRM Display in the Nuclear Heat Balance menu and completes table 1.25 Data for Friday, #LPRMs reading <3% on ICS. Records ZERO SAT_ UNSAT N/A COMMENTS:________________________________

Performance Step 6: Critical Not Critical X (1) Record number of LPRMs bypassed in the four APRM and LPRM cabinets as observed at Panel 3-9-14.

add these values together and record as Total # LPRMs Bypassed.

(2) Less than 20 LPRMs in OPERATE or Less than 3 per level for any APRM will result in a Rod Block and a trouble alarm on the display panel. This does not yield an automatic APRM trip, but does, however, make the associated APRM llTOP.

(3) Record number of LPRMs reading less than 3% on the LPRM printout or display on ICS.

(4) MAX DEV is not required to be met when the APRMs are downscale; however, unexpected inconsistencies should be reported to the Reactor Engineer. The total number of LPRMs bypassed shall equal the number of LPRMs reading less than 3% on ICS.

Standard:

Documents Sat and initials for Unit Operator for Friday when the conditions of Note 4 are satisfied.

SAT UNSAT_ N/A COMMENTS:________________________________

Admin RO Alb PAGE 9 OF 10 Performance Step 7: Critical X Not Critical Refers to 3-SR-2, Instrument Checks and Observations, table 1.30 TABLE 1.36 REACTOR VESSEL STEAM DOME PRESSURE INSTRUMENTATION DAY SHIFT VEE to_______________

APPLICABILITY: Modes 1 & 2 (ReferTo P81 Step 36A)

Readings are reqi.dred at all tunes.

Surveillance Requirenents: 3.3.1 .1.1(f3), 3.3.3.1.1, 3.4.16.1 LOCATION: CS (Notes 1 & 4) 3-9-86 3-9-85 3-9-84 3-9-83 Revtuw In1iatu MAX D C B A MAX Reference TIME 0EV DEV MAX Ail Data Leg (Note 4) 3-74A 3-748 (AC) 3-PIS-3-22D 3-PIS-3-22C 3-PIS-3-22BB 3-PIS-3-22AA (AC) LIMIT SATIUNSAT UO Unit Sopor fliday 6860 Saturday 6800 Sunday (1800 40ps 69 psig (Note 3)

Monda 6800 (Note 2) (NoteS)

(NoIe 2)

Tuesday 0800 VAidnesday 6800 Thursday 6800 Standard:

Selects SR-2 Group Display from the Group Display menu OR types the specific codes for each ICS point into the Single Value Display (for example: 3-74A, 3-74B, etc...) and completes table 1.30 Data for Friday. Records approximately 1050 psig for ICS point 3-74A and approximately 1005 psig for ICS point 3-74B.

SAT_ UNSAT N/A

Admin RO Alb PAGE 10 OF 10 Performance Step 8: Critical Not Critical (1) These readings may be obtained from ICS using the Single Value Display or from the ATU output voltage translated into a PRESSURE Signal for the specific instruments.

For ICS, type in SVD for Single Value Display, enter the point desired as 3-74A, record reading, select F4, enter 3-74B, record the second reading.

(2) 3-74A and 3-74B have a Maximum allowable deviation of 40 psig, AND 3-PIS-3-22D, 3-PIS-3-22C, 3-PIS-3-22BB, & 3-PIS-3-22AA, have a Maximum allowable deviation of 60 psig. No comparison is required between the 3-74A(B) and 3-PIS 22D(C)(BB)(AA).

(3) 3-74A and 3-74B SHALL be 1050 psig. 3-PIS-3-22D, 3-PIS-3-22C, 3-PIS-3-22BB, &

3-PIS-3-22AA SHALL be S 1090 psig.

(4) 3-74A and 3-74B are to be recorded at 0800. The Auxiliary Instrument Room readings are not required to be taken at precisely 0800.

(5) Following a change to Reactor Power and/or Pressure, verify the Steam Dome Limits are within the 0-TI-248, Administrative Limits and Design Analysis Limits (Appendix 5)

Standard:

Reviews notes and documents UNSAT and initials for Unit Operator for Friday when the conditions of Notes 2 and 3 are reviewed.

SAT_ UNSAT N/A COMMENTS:________

END OF TASK STOP TIME

Aiver y BFN Instrument Checks and Observations 3-SR-2 Unit 3 Rev. 0070 Page 20 of 146 Attachment 2 (Page 1 of 86)

Surveillance Procedure Data Package - Modes 1, 2, & 3 TABLE 1.1 CORE THERMAL POWER AND CORE POWER DISTRIBUTION DAY SHIFT WEEK: 7S 0 ,fe,id CJe k4tL APPLICABILITY: Mode I when 25% RTP (Refer To P&L Step 3.6A)

RECORD the readings as soon as possible after the generator breaker has been dosed.

rlterIa Source: 3.2.1.1;_3.2.2.1;_3.2.3.1;_DEFINITIONS SECTION_1.1_- FSAR 3.7.7 ICS Computer (Case Summary CSUM) Review Initials LOCATION: -

Core Thermal Percent Power LIMIT MFLCPR MAPRAT MFDLRX LIMIT Unit Unit TIME Supvr Note 2 Power* (MWt) (% RTP) (AC) Note 3 Note 3 Note 3 (AC) Operator DAY 0800 346. JoO. 0 iW

. 1200 Fnday 1400 1600 1800 0800 1000 1200 Saturday 1400 1600 Notes iouu notes 1 0800 &2 1000 1200 Sunday 1400 1600 1800 0800 1000 1200 Monday 1400 1600 1800 NOTES ARE FOLLOWING IHE TABLE!

r 1

A y BFN Instrument Checks and Observations 3-SR-2 Unit 3 Rev. 0070 Page 21 of 146 Attachment 2 (Page 2 of 86)

Surveillance Procedure Data Package - Modes 1,2, & 3 TABLE 1.1 CORE THERMAL POWER AND CORE POWER DISTRIBUTION DAY SHIFT WEEK: lkc i,-ieeI to ,Je,I- u..ek APPLICABILITY: Mode 1 when 25% RTP (Refer To P&L Step 3.6A)

RECORD the readings as soon as possible after the generator breaker has been closed.

Criteria Source: 3.2.1.1;_3.2.2.1;_3.2.3.1;_DEFINITIONS_SECTION_1.1_- FSAR 3.7.7 ICS Computer (Case Summary CSUM) Review Initials LOCATION: -

Percent Power LIMIT MFLCPR MAPRAT MFDLRX LIMIT Unit Unit TIME Core Thermal (MWt) RTP) (AC) Note 3 Note 3 Note 3 (AC) Operator Supvr DAY Note 2 Power (%

0800 1000 1200 Tuesday 1400 1600 1800 0800 1000 Notes 1200 Notes I 3,4,&

Wednesday 1400 &2 1600 1800 0800 1000 1200 Thursday 1400 1600 1800 NOTES ARE ON THE FOLLOWING PAGEI

A1w frey BFN Instrument Checks and Observations 3-SR-2 Unit 3 Rev. 0070 Page 22 of 146 Attachment 2 (Page 3 of 86)

Surveillance Procedure Data Package Modes 1,2, & 3 -

(1) Compliance with the Licensed Power Limit (LPL) (3458 Mwt) is demonstrated by the following process:

A. No actions are allowed that would intentionally raise core thermal power above 3458 Mwt for any period of time. Small, short-term fluctuations in power that are not under the direct control of the unit operator are not considered intentional.

6. Closely monitor the thermal power during steady-state power operation with the goal of maintaining the two-hour average at or below 3458 Mwt. If the core thermal power average for a 2-hour period is found to exceed 3458 Mwt, Operations take timely action to ensure that thermal power is less than or equal to 3458 MWt. (This is implemented by taking action when any running average less than or equal to the 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months average exceeds 3458 MWL)

C. The core thermal power for an 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period (8 hr average) is not to exceed 3458 Mwt.

0. If an evolution Is expected to cause a transient increase in reactor power that could exceed 3458 Mwt, action should be taken to lower core power prior to performing the evolution.

E. IF power is > 3463, REDUCE power.

F. IF power is 3458 to 3463 MWt after allowing time for recent perturbations to settle, REDUCE power and EVALUATE the trend.

G. IF any running 30 mm Avg, 1 hr average, or 2 hr average is> 3458 MWt, REDUCE power.

(2) Core Thermal Power is normally recorded every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months when required. However, these readings may be marked NIA during TIP trace runs, control rod pattern Monitoring of adjustments, or anytime Core Monitoring System is blocked andlor < 25% power. The Reactor Engineer is responsible for monitoring Core Thermal Limits.

Core Thermal Limits is recommende d following completion of planned rise in power and following any unexpected power change. If core Core Thermal Power and other but shall determine the appropriate frequency for monitoring Core Thermal Power monitoring software becomes unavailable, the Unit Supervisor/SRO and Reactor Engineer changes should not exceed 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , using backup core monitoring computer, and taking Into consideration current core conditions and margin to thermal limits. Power should not normally be made without the core monitoring software being available.

(3) Consult Reactor Engineer when value 0.985. Refer to 0-Tl-248 for Administrative Limits.

Bypass Out of (4) If any Turbine Bypass valve(s) are inoperable or a Recirculation Loop is out of service, contact the Reactor Engineer and refer to the COLR for Turbine Service (TBOOS) or Single Loop Operation (SLO) limits which must be applied.

(5) MAPRAT within limits is used to verify that all APLHGRs are within the limits specified within the COLR.

MFDLRX within limits is used to verify that all LHGRs are within the limits specified within the COLR.

MFLCPR within limits is used to verify that all MCPRs are within the limits specified within the COLR.

) yAver 2 BFN Instrument Checks and Observations 3-SR-2 Unit 3 Rev. 0070 Page 29 of 146 Attachment 2 (Page 10 of 86)

Surveillance Procedure Data Package Modes 1, 2, & 3 -

TABLE 1.6 HEAT BALANCE RELATED ICS ALARM SETPOINTS (Note 1) DAY SHIFT WEEK: 711(S tJtt k

0 J 4

.. I (A1Ik APPLICABILITY: Mode I when 25% RTP(Refer To P&L Step 3.6A)

RECORD the readings as soon as possible after the generator breaker has been closed.

Criteria Source: BFPER95I914 Review Initials LOCATION: ICS Computer ICS Points Verify HI and HI HI alarm setpoints listed in MAX 0EV Table I .8.1 & I .B.2 are NOT exceeded. (Note 3) Unit 3-50B (°F) NSSOOI7 (°F) Note 2 SAT! UNSAT I N/A UO Supvr 3.48A (°F) 3-48B (°F) 3-50A (°F)

Friday 772.. 377 ?77. A7 I,,4&

Saturday Sunday 2°F Monday Tuesday Wednesday Thursday The points are monitored to ensure the Inputs are In agreement and to (1) The computer points lIsted In Table 1.8.1 and 1.8.2 are tnputs lo the ICS Core Thermal Power Heat Balance calculations.

limits for thermal power are maintained. In addition to the above, these points should be monitored any time reactor power changes are performed.

ensure the license require the notification of Site Engineering and suspending any rise temperature points 3-48A, 3-48B. 3-50A. 3-508, and NSSOO17 of greater than 2 degrees will (2) A difference between Feedwater In power until the discrepancy Is resolved. Immediately to return the value to within limits, Site Engineering will be (3) An alarm solpoint being exceeded will require notifying the Unit Supervisor immediately and, If action cannot be taken notified for assistance.

TABLE 1.8. TABLE 1.B.2 HI ALARM HI HI ALARM ICS POINT DESCRIPTION HI ALARM HI HI ALARM ICS POINT DESCRIPTION 3463 3-48A AN Temp 382 386 CALCO2O Rx Power 30 Mm Avg. 3458 3461 3-488 AN Temp 382 386 CALCO21 Rx Power 1 Hr. Avg. 3458 3458 3459 3-50A AN Temp 382 386 CALCO63 Rx Power 2 Hr. Avg. 386 1185 1190 3-SOB FW Temp 382 CALCO98 Generator Power 386 35 36 NSSOOI7 Avg. AN Temp. 382 CALCO26 EfficIency 113.6 CONSO400 Total RWCIJ Flow 0.168 N/A CALCO2T Load line NIA -

CALCO24 Rx Power % 100,2 100.5

)E ,t1frer frey& I BFN Instrument Checks and Observations 3-SR-2 Unit 3 Rev. 0070 Page 46 of 146 Attachment 2 (Page 27 of 86)

Surveillance Procedure Data Package Modes 1, 2, & 3 -

DAY SHIFT WEEK: -7k 1)(LL tn I)X, LLok TABLE 1.25 LPRM INSTRUMENTATION APPLICABILITY: Modes I & 2 Readings are required at all times.

(Refer To P&L Step 3.6A)

Criteria Source: Technical Requirements Manual TSR 3.3.5.3 Review Initials LOCATION: Panel 3.9-14 and ICS Computer

LPRMs BYPASSED (Note 1) Total # # LPRMs LPRMS reading MA)( DEV APRM LPRM APRM LPRM APRM LPRM Bypassed 3% on ICS (AC) All Data APRM LPRM UO Unit Supvr

2 #4 #4 #3 #3 #1 #1 (Note 2) (Note 3) (Note 4) SAT/UNSAT DAY TIME #2 Friday 0800 (25 5 0 g5 S 5

çZ 41 (;I Saturday 0800 Sunday 0800 0

Monday 0800 Tuesday 0800 Wednesday 0800 Thursday 0800 values together and record as Total # LPRMs Bypassed.

(1) Record number of LPRMs bypassed in the four APRM and LPRM cabinets as observed at Panel 3-9-14. add these the display panel. This does not yield an (2) Less than 20 LPRMs in OPERATE or Less than 3 per level for any APRM will result in a Rod Block and a trouble alarm on automatic APRM trip, but does, however, make the associated APRM INOP.

(3) Record number of LPRMs reading less than 3% on the LPRM printout or display on ICS.

(4) MAX DEV is not required to be met when the APRMs are downscale; however, unexpected inconsistenci es should be reported to the Reactor Engineer. The total number of LPRMs bypassed shall equal the number of LPRMs reading less than 3% on ICS.

-t& ,4vswer key BFN Instrument Checks and Observations 3-SR-2 Unit 3 Rev. 0070 Page 52 of 146 Attachment 2 (Page 33 of 86)

Surveillance Procedure Data Package Modes 1,2, & 3 -

TABLE 1.30 REACTOR VESSEL STEAM DOME PRESSURE INSTRUMENTATION DAY SHIFT WEEK llitS LAA to ,J e (.Jee 1.

APPLICABILITY: Modes I & 2 (Refer To P&L Step 3.6A)

Readings are required at all times.

Surveillance Requirements: 3.3.1.1.1 ((3), 3.3.3.1.1, 3.4.10.1 3-9-86 3-9-85 3-9-84 3-9-83 Review Initials LOCATION: ICS (Notes 1 & 4)

MAX D C B A MAX 0EV DEV MAX All Data Reference TIME UO Unit Supvr 3-74B (AC) 3-PIS-3-22D 3-PIS-3-22C 3-PIS-3-2288 3-PIS-3-22AA (AC) LIMIT SAT/UNSAT Leg (Note 4) 3-74A Friday 0800 /oc, fpp /o.?5 /o3 /c-3 /o3 %.4r 1,i;dc Saturday 0800 Sunday 0800 40 pslg 60 pslg (Note 3)

Monda (Note 2) (Note 2) (Note 5)

Tuesday 0800 Wednesday 0800 Thursday 0800 for the specific instruments.

(1) These readings may be obtained from ICS using the Single Value Display from the ATU output voltage translated into a PRESSURE Signal reading.

record reading, select F4, enter 3-74B, record the second For ICS, type in SVD for Single Value Display, enter the point desired as 3-74A°,

A, have a Maximum allowable deviation of (2) 3-74A and 3-74B have a Maximum allowable deviation of 40 psig, AND 3-PIS-3-22D, 3-PIS-3-22C, 3-PIS-3-22BB, & 3-PIS-3-22A 60 psig. No comparison is required between the 3-74A(B) and 3-PIS-3-22D (C)(BB)(AA ).

(3) 3-74A and 3-748 SHALL be 1050 psig. 3-PIS-3-22D, 3-PIS-3-22C, 3-PIS-3-22BB, & 3-PIS-3-22AA SHALL be 1090 psig.

(4) 3-74A and 3-74B are to be recorded at 0800. The Auxiliary Instrument Room readings are not required to be taken at precisely 0800.

Design Analysis Limits (Appendix 5)

(5) FollowIng a change to Reactor Power and/or Pressure, verify the Steam Dome Limits are within the 0-.TI-248, Administrative Limits and

-. IxI Mn Akrrn Gr.phics Trcnd5 Points ZoomJLyer Prut He 23APR-2O12 15:36:27 II SELECT FUNC. KEY OR TURN-ON CODE CSUM 11111111 IiW Ihr TRIGGER: 20k CASE

SUMMARY

b f3ppxa LAST POWERPLEX MONITOR CASE POWERPLEX HEAT BALANCE Date 1 /31 /12 Date 1/31/12 Time 22 : 4 Time 22:13:26 REACTOR CONDITIONS CORE THERMAL POWER / CORE FLOW CTP 3456.1 (MWt) 99.9 Rated CIP 0,0 (MWt) 0.0 % Rated 0/

1150.2 (MWe) 99.1 10 Rated CTP CALCULATED FROM I I[AT BALANCE WT 81.0 ML B/HR 31 9 . Rated WT 0.0 MLB/HR 0.0 % Rated DHS 30.6 BTtJ/LB WTSUB 0.0 MLB/HR CAV EX 1582/.0 MWT/MTU WTFLAG 0 EFF 33.3 LOAD LINE 110.3 CRD 0.052 LOAD LINE(CTP, Wf) 0.()

XENON WORTH 0. 00 K-EFF 1 02.10 POWERPLEX DATA FILE READ STATUS CORE THERMAL LIMITS DATA CONSTANTS FOR ICS NSP6 PROGRAM Value IX JY K 15 24 CONSI AtFI S RI Al) SUCCE SSF UI l.Y MFLCPR 0.876 t1APRAT 0. 766 31 18 VALUES FROM LAST PPLX MONITOR CASE MFDLRX 0.838 35 18 1 VALUES LEAD SUCCESSFULLY VALUES FROM LAST PPLX HEAT BALANCE P-PCS 2.2(1 35 50 1 35 5(1 4 VAI UFS kLAn SUCCE 5SF UI LY P-PCFC 2.20 orTjj 1 T044 UK= 004/wi n=1 SEC 1VL= 3 PR IM/BACK CPU S

iiIx1 11n Alerms Grephics Trends Pok*s ZoomlLeyers Print Help 23-APR-2012 15:36:27 L11 SELECT FUNC. KEY OR TURN-ON CODE GD GROUP DISPLAY FOR (aSR-2 Page 1 of 1 INSTRUMENT CHECKS Update rate 1.0 seconds PID QUAL VALUE UNITS DESCRIPTION CALCO2O GOOD 3-456 MWT REACTOR POWER,NSSS - 30 MIN AVG CALCO21 GOOD 3456 MWT REACTOR POWER,NSSS - 1 HR AVG CALCO83 GOOD 34.56 MWT REACTOR POWERNSSS - 2 HR AVG CALCO98 GOOD 1150 MWE MAIN GENERATOR POWER (FILTERED)

CALCO26 GOOD 33.277023 EFFICIENCY (Z)

CALCO27 GOOD 110.3 LOAD LINE CALCO24 GOOD 100.0 9i REACTOR POWER, PERCENT RATED 3-48A DALM 377.2 DEG F RFW LINE A TEMP (1 OF 2) 3-48B GOOD 377.2 DEG F RFW LINE A TEMP (2 OF 2) 3-50A GOOD 377.2 DEG F RFW LINE B TEMP (1 OF 2) 3-SOB GOOD 377.2 DEG F RFW LINE B TEMP (2 OF 2)

NSSOO17 GOOD 377.2 DEG F RFW TEMP TO REACTOR (AVG)96-14A GOOD 3,07 MW RECIRC VFD A-OUTPUT POWER 96-lAB GOOD 2.85 MW RECIRC VFD B-OUTPUT POWER CONSO400 GOOD 0.143 MLB!HR TOTAL RWCU FLOW-FOR NSSS TEST2SOO GOOD 119.0 DEG F BULK VOLUMETRIC AVG DW TEMP 3-74A GOOD 1050 PSIG RX PRESSURE-WIDE RANGE 3-74B GOOD 1005 PSIG RX PRESSURE-WIDE RANGE g1 L1 FS=BISTORY1 [FPTSJ Zj IIIIfi!J IIZ1FL]jJrro44 WKOO4/qin=1SEC LVL=3 PRIM/E3ACKCPU S RUN Si

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4*1 Sf W t iov- ø BFN Instrument Checks and Observations 3-SR-2 Unit 3 Rev. 0070 Page 20 of 146 Attachment 2 (Page 1 of 86)

Surveillance Procedure Data Package - Modes 1, 2, & 3 TABLE 1.1 CORE THERMAL POWER AND CORE POWER DISTRIBUTION DAY SHIFT WEEK: (,.fek to i%JPYJ- iJk APPLICABILITY: Model when 25% RTP (Refer To P&L Step 3.6A)

RECORD the readings as soon as possible after the generator breaker has been closed.

Criteria_Source: 3.2.1.1;_3.2.2.1;_3.2.3.1;_DEFINITIONS SECTION_1.1_-_FSAR 3.7.7 Review Initials LOCATION: ICS Computer (Case Summary CSUM) -

Percent Power LIMIT MFLCPR MAPRAT MFDLRX LIMIT Unit Unit TIME Core Thermal Supvr Power (MWt) (% RTP) (AC) Note 3 Note 3 Note 3 (AC) Operator DAY Note 2 0800 1000 1200 Friday 1400 1600 1800 0800 1000 1200 Saturday 1400 1600 Notes 1800 Notes 1 3 4 &

0800 &2 5 1000 1200 Sunday 1400 1600 1800 0800 1000 1200 Monday 1400 1600 1800 NOTES ARE FOLLOWING THE TABLE!

Y Sfv&i Woi BFN Instrument Checks and Observations 3-SR-2 UnIt 3 Rev. 0070 Page 21 of 146 Attachment 2 (Page 2 of 86)

Surveillance Procedure Data Package - Modes 1,2, & 3 TABLE 1.1 CORE THERMAL POWER AND CORE POWER DISTRIBUTION DAY SHIFT WEEK: ThIS LJee k.4o Jcf tJee APPLICABILITY: Model when 25% RTP (Refer To P&L Step 3.6A)

RECORD the readings as soon as possible after the generator breaker has been closed.

Criteria Source: 3.2.1.1; 3.2.2.1; 3.2.3.1;_DEFINITIONS SECTION_1.1_- FSAR 3.7.7 ICS Computer (Case Summary CSUM) Review Initials LOCATION: -

TIME Core Thermal Percent Power LIMIT MFLCPR MAPRAT MFDLRX LIMIT Unit Unit Power (MWt) (% RTP) (AC) Note 3 Note 3 Note 3 (AC) Operator Supvr DAY Note 2 0800 1000 1200 Tuesday 1400 1600 1800 0800 1000 Notes 1200 Notes I 3,4,&

Wednesday 1400 &2 1600 1800 0800 1000 1200 Thursday 1400 1600 1800 NOTES ARE ON THE FOLLOWING PAGEI

S Le 1 7 7 BFN Instrument Checks and Observations 3-SR-2 Unit 3 Rev. 0070 Page 22 of 146 Attachment 2 (Page 3 of 86)

Surveillance Procedure Data Package Modes 1, 2, & 3 -

(1) Compliance with the Ucensed Power Limit (LPL) (3458 Mwt) is demonstrated by the following process:

in power that are not A. No actions are allowed that would intentionally raise core thermal power above 3458 Mwt for any period of time. Small, short-term fluctuations under the direct control of the unit operator are not considered intentional.

the core thermal B. Closely monitor the thermal power during steady-state power operation with the goal of maintaining the two-hour average at or below 3458 Mwt. If power average for a 2-hour period is found to exceed 3458 Mwt, Operations take timely action to ensure that thermal power is loss than or equal to 3458 MWt. (This is implemented by taking action when any runnIng average less than or equal to the 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months average exceeds 3458 Mwt.)

C. The core thermal power for an 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period (8 hr average) Is not to exceed 3458 Mwt.

prior to performing D. If an evolution is expected to cause a transient increase in reactor power that could exceed 3458 Mwt, action should be taken to lower core power the evolution.

E. IF power is >3463, REDUCE power.

F. IF power is 3458 to 3463 MWt after allowing time for recent perturbations to settle, REDUCE power and EVALUATE the trend.

G. IF any running 30 mm Avg. 1 hr average, or 2 hr average is> 3458 MWt, REDUCE power.

Core Thermal Power is normally recorded every 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months when required. However, these readings may be marked N/A during TIP trace runs, control rod pattern (2)

Thermal Limits. Monitoring of adjustments, or anytime Core Monitoring System is blocked and/or 25% power. The Reactor Engineer is responsible for monitoring Core Limits is recommende d following completion of planned rise in power and following any unexpected power change. If core Core Thermal Power and other Core Thermal for monitoring Core Thermal Power but monitoring software becomes unavailable, the Unit Supervisor/SRO and Reactor Engineer shall determine the appropriate frequency limits. Power changes should not exceed 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , using backup core monitoring computer, and taking into consideration current core conditions and margin to thermal should not normally be made without the core monitoring software being available.

(3) Consult Reactor Engineer when value 0.985. Refer to 0-Tl-248 for Administrative Limits.

to the COLR for Turbine Bypass Out of (4) If any Turbine Bypass valve(s) are inoperable or a Recirculation Loop is out of service, contact the Reactor Engineer and refer Service (TBOOS) or Single Loop Operation (SLO) limits which must be applied.

(5) MAPRAT within limits is used to verify that all APLHGRs are within the limits specified within the COLR.

MFDLRX within limits is used to verify that all LHGRs are within the limits specified within the COLR.

MFLCPR within limits is used to verify that all MCPRs are within the limits specified within the COLR.

& 9vo( Whd0L4 i 0 2 BFN Instrument Checks and Observations 3-SR-2 Unit 3 Rev. 0070 Page 29 of 146 Attachment 2 (Page 10 of 86)

Surveillance Procedure Data Package Modes 1, 2, & 3 -

TABLE 1.6 HEAT BALANCE RELATED ICS ALARM SETPOINTS (Note 1) DAY SHIFT WEEK: 7lit Wee k:.. to ikx 1- ,ek APPLICABILITY: Mode I when 25% RTP(Refer To P&L Step 3.6A)

RECORD the readings as soon as possible after the generator breaker has been closed.

Criteria Source: BFPER95I9I4 Review Initials LOCATION: ICS Computer ICS Points Verify HI and HI HI alarm setpoints listed in MAX DEV Table I .B.1 & I .B.2 are NOT exceeded. (Note 3) Unit 3-50A (°F) 3-50B (°F) NSSOOI 7 (°F) Note 2 SAT I UNSAT I N/A UO Supvr 3-48A (°F) 3-48B (°f)

Friday Saturday Sunday 2°F Monday Tuesday Wednesday Thursday are monitored to ensure the inputs are in agreement and to (I) The computer points Ilsied in Table I.B; and I .B.2 are inputs to the IC Core Thermal Power Heat Balance calculations. The paintsreactor power changes are performed.

ensure the license lImits for thermal power are maintained. In addition to the above, these points should be monitored any timerequire the notification of Site Engineering and suspending any rise (2) A difference between Feedwater temperature points 3-48A, 3.48B. 3-50A, 3-SOB, and NSSOO17 of greater than 2 degrees will In power until the disaepancy is resolved. the value to within limits, Site Engineering will be (3) An alarm setpoint being exceeded will require notifying the Unit Supervisor Immediately and, If action cannot be taken immediately to return notified for assistance.

TABLE 1.B.1 TABLE I.B.2 DESCRIPTION HI ALARM HI HI ALARM ICS POINT DESCRIPTION Hi ALARM Hi HI ALARM ICS POINT 3458 3463 3-48A FWTemp 382 386 CALCO2O Rx Power 30 Mm Avg.

3458 3461 348B FW Temp 382 386 CALCO21 Rx Power 1 Hr. Avg.

3458 3459 3-BOA FW Temp 382 386 CALCO83 Rx Power 2 Hr. Avg. 386 Generator Power 1185 1190 3-BOB FW Temp 382 CALCO98 382 386 CALCO26 Efficiency 35 36 NSSOOI7 Avg. FW Temp.

N/A 113.6 CONSO400 Total RWCU Flow 0.168 N/A CALCO27 Load Une CAL.C024 Rx Power % 100.2 100.5

s (cc,SoQ+ -

F BFN Unit 3 Instrument Checks and Observations 3-SR-2 Rev. 0070 Page 46 of 146 Attachment 2 (Page 27 of 86)

Surveillance Procedure Data Package Modes 1, 2, & 3 TABLE 125 LPRM INSTRUMENTATION DAY SHIFT WEEK: 1 L4Ctk to fk)4 LkeL.

APPLICABILITY: Modes I & 2 Readings are required at all times.

(Refer To P&L Step 3.6A)

Criteria Source: Technical Requirements Manual TSR 3.3.5.3 Review Initials LOCATION: Panel 3.9-14 and ICS Computer

LPRM5 BYPASSED (Note 1) Total # # LPRMs LPRMs reading MAX DEV APRM LPRM APRM LPRM APRM LPRM Bypassed 3% on ICS (AC) All Data APRM LPRM UO Unit Supvr

2 #2 #4 #4 #3 #3 #1 #1 (Note 2) (Note 3) (Note 4) SATIUNSAT DAY TIME Friday 0800 (7) 0 0 Saturday 0800 Sunday 0800 0

Monday 0800 Tuesday 0800 Wednesday 0800 Thursday 0800 add these values together and record as Total # LPRMs Bypassed.

(1) Record number of LPRMs bypassed in the four APRM and LPRM cabinets as observed at Panel 3-9-14.

Block and a trouble alarm on the display panel. This does not yield an (2) Less than 20 LPRMs in OPERATE or Less than 3 per level for any APRM will result in a Rod automatic APRM trip, but does, however, make the associated APRM INOP.

(3) Record number of LPRMs reading less than 3% on the LPRM printout or display on ICS.

es should be reported to the Reactor Engineer. The total number of (4) MAX DEV is not required to be met when the APRMs are downscale; however, unexpected inconsistenci LPRMs bypassed shall equal the number of LPRMs reading less than 3% on ICS.

%SM- f-1oiSocMEY BFN Instrument Checks and Observations 3-SR-2 Unit 3 Rev. 0070 Page 52 of 146 Attachment 2 (Page 33 of 86)

Surveillance Procedure Data Package Modes 1, 2, & 3-TABLE 1.30 REACTOR VESSEL STEAM DOME PRESSURE iNSTRUMENTATION DAY SHIFT WEEK: 1v5 tAfeL. f\i ex

- Week 4

APPLICABILITY: Modes I & 2 (Refer To P&L Step 3.6A)

Readings are required at all times.

SuTveillance Requirements: 3.3.1 .1.1(f3), 3.3.3.1 .1, 3.4.10.1 3-9-86 3-9-85 3-9-84 3-9-83 Review Initials LOCATION: ICS (Notes 1 & 4)

MAX D C B A MAX DEV DEV MAX All Data Reference TIME (AC) LIMIT SATIUNSAT UO Unit Supvr (Note 4) 3-74A 3-74B (AC) 3-PIS-3-22D 3-PIS-3-22C 3-PIS-3-22BB 3-PIS-3-22AA Leg FrIday 0800 /035 i0S Ic) /c3 Saturday 0800 Sunday 0800 40 psig 60 psig (Note 3)

M a nd ay 0800 (Note 2) (Note 2) (Note 5)

Tuesday 0800 Wednesday 0800 Thursday 0800 into a PRESSURE Signal for the specific instruments.

(I) These readings may be obtained from ICS using the Single Value Display from the ATU output voltage translated F4, enter 3-74B, record the second reading.

For ICS, type in SVD for Single Value Display, enter the point desired as 3-74A, record reading, select B, & 3-PIS-3-22AA, have a Maximum allowable deviation of (2) 3-74A and 3-748 have a Maximum allowable deviation of 40 psig, AND 3-PIS-3-22D, 3-PIS-3-22C, 3-PIS-3-22B 60 pslg. No comparison is required between the 3-74A(B) and 3-PIS-3-22D(C)(BB)(AA ).

3-74A and 3-748 SHALL be 1050 psig. 3-PIS-3-22D, 3-PIS-3-22C, 3-PIS-3-22BB, & 3-PIS-3-22AA SHALL be 1090 psig.

(3) not required to be taken at precisely 0800.

(4) 3-74A and 3-74B are to be recorded at 0800. The Auxiliary Instrument Room readings are Administrative Limits and Design Analysis Limits (Appendix 5)

(5) Following a change to Reactor Power and/or Pressure, verify the Steam Dome Limits are within the 0-TI-248,

FINAL Admiri SRO Alb PAGE 1 OF 6 OPERATOR:

RO___ SRO DATE:

JPM NUMBER: Admin SRO Aib TASK NUMBER: Conduct of Operations TASK TITLE: NRC Event Notification K/A NUMBER: 2.1.18 K/A RATING: SRO 3.8 PRA: 1.5% CDF Contribution TASK STANDARD: Determine NRC Event Notification requirements and Technical Specification actions required.

LOCATION OF PERFORMANCE: Class Room REFERENCES/PROCEDURES NEEDED: NPG-SPP-03 .5 VALIDATION TIME: 10 minutes MAX. TIME ALLOWED: (Completed for Time Critical JPMs only)

PERFORMANCE TIME:

COMMENTS:

Additional comment sheets attached? YES NO RESULTS: SATISFACTORY___ UNSATISFACTORY SIGNAIlJRE: DATE:

EXAMINER

INITIAL CONDITIONS: Unit 1 is in Mode 1 at 100% Reactor Power. 1-SR-3.5.1.1(HPCI),

MAINTENANCE OF FILLED DISCHARGE PIPiNG, is in progress and it is discovered that 1-FCV-73-44, HPCI PUMP iNJECTION VALVE, failed to open from the Control Room with handswitch, 1 -HS-73-44A.

4ITIATING CUE: As the Shift Manager, evaluate these plant conditions for appropriate 5

11 notifications and technical specification actions, if any, and document your conclusions on the correct form(s), if necessary. The valve failed to open 30 minutes ago.

Admin SRO Aib PAGE 3 OF 6 Class Room INITIAL CONDITIONS: Unit 1 is in Mode 1 at 100% Reactor Power. 1-SR-3.5.1.1(HPCI),

MAINTENANCE OF FILLED DISCHARGE PIPING, is in progress and it is discovered that 1-FCV-73-44, HPCI PUMP INJECTION VALVE, failed to open from the Control Room with handswitch, 1 -HS-73-44A.

INITIATING CUE: As the Shift Manager, evaluate these plant conditions for appropriate notifications and technical specification actions, if any, and document your conclusions on the correct form(s), if necessary. The valve failed to open 30 minutes ago.

Admin SRO Aib PAGE 4 OF 6 START TIME Performance Step 1: Critical X Not Critical Refers to Technical Specification Section 3.5.1 ECCS cperating 3.5.1 3.5 Ei.4EFtG E1iCY CcDE COOLING SYSTEfvIS (ECcS) AND I CACTO COIB ISDI_AT I N COcL.I MG (FtCI) SYSTEfvl 3.5.1 DCS Operating LCO 3.5.1 Each ECCS injection/spray subsystem and the At..itomatic DepreasL.Jriatior1 System (ADS) function cf six safety/relief valves shall be EIRABLB APLIcAILITV: rvcDE 1, IVBDDES 2 and 3. except high pressure coolant injectori (II PCI) and ADS valves are not reqLiired to be O6RABL6 with reactor steam dome pressl..lre 1 50 psig.

ACTI ON S LCO 30.4.b is not applicable te HFCL ECCS - Operating 3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION Ti ME C. I-IPC1 System inoperable. C.1 Verify by administrative Immediately means RCIC System is 0 P E RAE LB.

AND C.2 Restore HPCI System to 14 days OPERABLE status.

Standard:

Determines that Tech Spec LCO 3.5.1 is applicable and the plant is not in compliance.

Determines Condition C applies and the required action is to verify by administrative means that RCIC is OPERABLE and restore HPCI to OPERABLE status within 14 days.

SAT_ UNSAT N/A COMMENTS:______________________________

Admin SRO Aib PAGE 5 OF 6 Performance Step 2: Critical X Not Critical Evaluates NPG-SPP-03 .5 Appendix A: 3.1.D.4. (4)

4. §50.72(b)(3)(v) Any event or condition that at the time of discovery could have prevented the fulfillment of the safety function of structures or systems that are needed to:

(A) Shut down the reactor and maintain it in a safe shutdown condition; (B) Remove residual heat; (C) Control the release of radioactive material; or (D) Mitigate the consequences of an accident.

Standard:

Determines an 8-Hr Non-Emergency notification is required.

SAT_ UNSAT N/A COMMENTS:________________________________

Examiner Note: When/If candidate determines that NPG-SPP-03.5-1 NRC Form 361, Event Notification Worksheet is required (Attachment 1 ofNPG-SPP-03 .5),

then provide candidate with a blank copy of the form.

Performance Step 3: Critical X Not Critical Completes Attachment 1, NPG-SPP-3.5-l NRC Event Notification Worksheet Standard:

Under Event Classification a check in box for 50.72 Non-Emergency SAT_ UNSAT N/A COMMENTS:____________________

Admin SRO Aib PAGE 6 OF 6 Performance Step 4: Critical X Not Critical Complete Attachment 1, NPG-SPP-3.5-1 NRC Event Notification Worksheet Standard:

Under 8-Hr Non-Emergency 10CFR5O.72 (b) (3) a check in the box (v) (D) Accident Mitigation AIND SAT UNSAT N/A COMMENTS:_______________________________

Performance Step 5: Critical Not Critical Complete NPG-SPP-3.5-l NRC Event Notification Worksheet Standard:

Power/Mode Before will be 100%/Mode 1; Power/Mode After will be 100%/Mode 1 and a brief description stating that the HPCI Pump Injection Valve failed to open, therefore affecting accident mitigation.

SAT UNSAT N/A _COMMENTS:_____________________________

CUE: JPM complete once an entry is made in description block on first page, Additional Information page not required to be completed.

END OF TASK STOP TIME

AAscr ke NPG Standard Regulatory Reporting Requirements NPG-SPP-03.5 Programs and Rev. 0003 Processes Page 90 of 91 Attachment I (Page 4 of 5)

NPG-SPP-03.5-1 - NRC Form 361, Event Notification Worksheet NRC EVENT NOTIFICATION WORKSHEET Page 1012 U.S. NUCLEAR REGULATORY COMMISSION OP.R.13QNS CENTER NRC EVENT NO11FICATION WORKSHEET EN I )( X )C..

NRC OPERATION TELEPHONE NUMBER: PRIMARY 301-816-5100 OR 800-532-3489, BACKUP -1151) 301-951.0500 or 800.449-3694 (2nd) 301415.0550 AND (3rd) 301-415-0553 N IFICATION Zbrrc4 EVENTTI ME

& ZONE FACILITY EVENT ATE R NIZATION POWERIMODE BEFO I S.- I UN T NAME r

CALLER POWERIM000 I L CK#

)

4frLZ5- 1oy NT CSSIFICAIIONS O%/Iio(f 1-Hr Non-Ems 4

10 CFR 50 72(bNl) ti (O)(A) Safe CopsSIlIr AlMA E]TGENEBAI. EMERGENCY GenIASEC I] I TSDewlnIion ADEV ,Q (v)B) RHRCepabl0l PJNB

] SITE AREA EMERGENCY SF1AAEC 4-Hr Non.Emersncy 10 CFR 50.72(b2) I] (v)(C) Conlrol cC Rad Release AINC C1J ALERT ALEIAAEC CI (I) TSRoquIiedSlD ASHU (uXO) AccIdenI50igIlon A1ND til UNUSUAl. EVENT j 50.72 NO*EMERGENCY (ISO next UNUAEC COSIIMS) 0000 (3

C (loXA ECCS Oleclonpeb RCA (1yMB)

(,d)

RPS OGete Aduollce (warn)

NoliScaIjon ACCS ARPS APSE I]

(dl) OPuSe Ilrdlcel Lcd Ccmmf*suliResp BD.Oay OpIjionel 10 CFR 50.73(nHl)

AMED Dj pI.rvsIc SEcuRin a3.71)

QJ MATERiAIJEXPOSIJI1E B??? - 9-Hr Non.EmeiGeflCy 10 CFR 60.?2(bXS) CI bWcIId Specllled S AcIuSIIOn AINV CIJ FITNESS FOR DUTY HFIT (3 (H)(B) Degraded CoodSari P580 Other Unspedfled RequIrement (IdentIfy) j1 Other UnepedSed Reqid, (see led cclarnri) (111(8) UTVZOPd1IIOO AUNA HOME t] INFOR ION ONtY NW (inKS) Ep S)Meor Aclupllon P50 DESCRIPTION cIj51e; Systems olfeded. uduStlons & theIr hIrtlellog eigndu news. Sliest cloned enpierd. ec torelatarn or piamied, eM. (Costhruoor. pups 2)

/1M41 1

( pt loss of 1ii,Lt hPc I Iij who t

I; i WPc( 5 rtirl /b &

4, ,i;,ck ,1 t4e,i t i4ia k1 t

psvrZi7

,tes ,1tY( SLIrZ ;,-

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5pecad01 3.l iitt(

1 7c

&c,,Dn1 t 4choi c! MCA NOTIFICATIONS I YES NO WIU BE I AnythIng Unusual or NM Yes (Explain a b ore) No NRC RESIDENT I (3 13 I ursterntoost STATE(S) Did AS Sygienrie FunctionAl No(Exptein oboes)

(3 OtheIGOV Agendes Ci I Modec(Opcrdtcnjj UrrttConeded:

I A I ESIIIESOd 9E .L__j RosiariDular_jiJj Add11tonal WOos pageS?

ics_ta MedIalPreea ReleaSe Page 1 o12 NPG-SPP-03.5-1 [08-06-20101

/

NPG Standard Regulatory Reporting Requirements NPG-SPP-03.5 Programs and Rev. 0003

Processes Page 90 of 91 Attachment I (Page 4 of 5)

NPG-SPP-03.5-1 - NRC Form 361, Event Notification Worksheet NRC EVENT NOTIFICATION WORKSHEET Page 1 of 2 U.S. NUCLEAR REGULATORY COMMISSION OPERATIONS CENTER NRC EVENT NOTIFICATION WORKSHEET EN 6 NRC OPERATION TELEPHONE NUMBER: PRIMARY 301-816-5100 OR 800-532-3489, BACKUP -(1811301-951-0500 or 800-449-3694 (2ndj 301-415-0550 AND (3edJ 301-415-0553 NOTIFICATION TIME FACILITY OR ORGANIZATION UNIT NAME OF CALLER CALL BACK 0 EVENT TIME & ZONE EVENT DATE POWERIMODE BEFORE POWERIMODE AFTER EVENT CLASSII ATIONS 1-nT 000-urnnrqency 1ull-I W.1c1u1114 19 MIA) 881. SID CapabSty AINA I2CMCDAI flStflflCW! GerilMEC DI TSDe46lon ADEV a (.)(B) RHR cBPObIIIY *188 E snrn,89.c A__u. 1=...t..a......y ffl tCO On a (oRC) C° AINC C PLERT Dim ASHU a 1.110) °--- AIND L

I:

UNUSUAl. SVSNI p44Y8lCAI eeimrr. 71 UNUIAAEC (IiA14A4flillI DD II I ntat Fl 146181 RPS A6UOIIOO F 461 toc.aml atYc ARPS APRE I-I Ci 1,411 (dlii vu.uoy tJllIlZS 01001002 L 1,O2WWfl51Ha.P onaonaI lu urn ou.iaiaijii Stalin AC MAISNUIUCArSAlUN Rm

- - - Hr Non-Emerqency ID CFR 60.72IbN3) 19 I- 1V000 0em a70251n?Wazar AINV r

-e I

FITNESS FOR DUTY LJWOT UrrIpOstitno 1139113.

INFORMATION ONLY 300 a.i a.....,

HFIT Nr rt 19 Li AM tines 9-)A)

Dno,ndod Condition Ua.nniozedcortdltlon opoolItna System Aotustton ADEG AUNA AESF Fl I a

Other UnspecIfied Requirement Ødentlty)

NONE NONR ioctude: ....a.. aduO9OflSA thefT tnOluilng 51911513. collIes. 51IeCI 01 OvOfli On p1510,5180113 laZe. or plattrtoa. etc. (Uonumae on page 2)

NUIWICA11ONS I YES I NO I WILLBE I An Ping UtltiIUoIOr Not U ye. (Explain above) C No NRC RES1DEIT STATs)

LOCAL Q

i Ei1EZI i g i NEOd?

046*2 Systems Function As Required? C Yes C No(Expfeln above) eSter 005 AgencIes a I a a Mode a! Opelollon I Esthnalad RoobS Cal.:

I AddttOozl INFO cii ON.

page2T Medess RdeaZe U l Conetied:

Page 1 of2 NPG-SPP-03.5-I (08-08-20101

NPG Standard Regulatory Reporting Requirements NPG-SPP-03.5 Programs and Rev. 0003 Processes Page 91 of 91 Attachment I (Page 5 of 5)

NPG-SPP-03.5-1 - NRC Form 361, Event Notification Worksheet NRC EVENT NOTIFICATiON WORKSHEET Page 2 of 2 RADIOLOGICAL RELEASES: CHECK OR FILL IN APPLICABLE ITEMS (specific detallstexplanaflons should be covered In event description)

Liquid Release I Gaseous Release Unplanned Release Planned Release I [I Oneoinq I TenTIIneIed Monitored I Unmonitored OlTalta Release T.S. Exceeded I RN Alaims I Areas EVacUated Personnel Exposed or Cormlnaied OfVsIte Protective AetIos Reco,rancnded I State r,ase path In desc-rs Release Pete (CUsec) % T. S. Limit HOO Guide Total Activity (CI) $ T.S. Limit HOO Guide Noble Gas 0.1 ClIsec 1000 CI IodIne 10 uClisec 0.01 Cl Patticulate luClisec -__________ lmCI Liquid (excluding trtWm A 10 uCIimtn 0.1 Ci dlssojved noble gases)

Lhiuld(irlthnn) -_____________

0.2CIhnin ad Total ActMty Plant Stack CondeneerlAlr Elector Main Steam Line SO Blowdown Other RAD Monitor Readlnqs:

AIa,m Setpolnls:

% T.S. Limit (71 açØkabie)

RCS or SO Tube Leaks: Check or Fill In Appikeble amos: (speciEs datalls!asplanations should be covardhv event descrIption)

LOCATION OF THE LEAK (e.g., SOE v&va pipe, etc.)

LEAK RATE UNITS: gmlgpd T. S. LIMITS SUDDEN OR LONG TERM DEVELOPMENT LEAK START DATE TIME COOLANT PRIMARY. SECONDARY-ACTIVITY & UNITS LIST OF SAFETY RELATED EQUIPMENT NOT OPERATIONAL EVENT DESCRIPTION (Continued flom page 1)

Page 2 of 2 NPG-SPP-03.5-1 108.06-20101 V

FINAL Admin RO A2 PAGE 1 OF 9 OPERATOR:

RO___ SRO DATE:

JPM NUMBER: RO A2 TASK NUMBER: Equipment Control TASK TITLE: 3-SI-4.7.A.2.A Primary Containment Nitrogen Consumption and Leakage KIA NUMBER: 2.2.12 KJA RATING: RO 3.7 SRO 4.1 PRA:

TASK STANDARD: Perform section 7.8 of 3-SI-4.7.A.2.A and determine Average Nitrogen Leakage does not meet Acceptance Criteria LOCATION OF PERFORMANCE: Classroom REFERENCES/PROCEDURES NEEDED: 3-SI-4.7.A.2.A VALIDATION TIME: 10 minutes MAX. TIME ALLOWED:

PERFORMANCE TIME:

COMMENTS:

Additional comment sheets attached? YES NO RESULTS: SATISFACTORY UNSATISFACTORY SIGNATURE: DATE:

EXAMiNER

IMTIAL CONDITIONS: You are an extra Operator. The time is 2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months . The plant is in Mode I. 3-SI-4.7.A.2.A, Primary Containment Consumption and Leakage, is in progress and has been completed thru section 7.7.

iNITIATING CUE: The Unit Supervisor (US) directs you to complete 3-SI-4.7.A.2.A, Primary Containment Consumption and Leakage.

Admin RO A2 PAGE 3 OF 9 Class Room INITIAL CONDITIONS: You are an extra Operator. The time is 2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months . The plant is in Mode 1. 3-SI-4.7.A.2.A, Primary Containment Consumption and Leakage, is in progress and has been completed thru section 7.7.

INITIATING CUE: The Unit Supervisor (US) directs you to complete 3-SI-4.7.A.2.A, Primary Containment Consumption and Leakage.

Admin RO A2 PAGE 4 OF 9 START TIME Performance Step 1: Critical Not Critical X 7.8 Average Nitrogen Consumption and Leakage 7.8.1 Attachment 7 Section A Net Nitrogen Leakage

[1] Total Drywell Control Leakage, RECORD the Total Drywell Control Air Leakage from Attachment 2 in the Gas Addition to the Drywell table.

Standard:

3 for Total Drywell Control Air Leakage on Refers to Attachment 2 and records 1017.40 ft Attachment 7 SAT UNSAT N/A COMMENTS:________________________________

Performance Step 2: Critical Not Critical X

[2] Cumulative Nitrogen Makeup, RECORI) the total cumulative nitrogen makeup from Attachment 4 Section A in the Gas Addition to the Drywell table.

Standard:

3 for cumulative nitrogen makeup on attachment Refers to Attachment 4 and records 9912 ft 7

SAT UNSAT N/A COMMENTS:

Admin RO A2 PAGE 5 OF 9 Performance Step 3: Critical X Not Critical

[3] CALCULATE the Total Gas Addition as follows:

ADD all the Gas addition types together from the Gas Addition Table and RECORD the sum as the Total Gas Addition in the Gas Addition to the Drywell table.

Standard:

Adds the Total Drywell Control Air Leakage and the Cumulative Nitrogen Makeup and determines the Total Gas Addition is 10929.40 &.

SAT_ IJ1JSAT N/A COMMENTS:_______________________________

Performance Step 4: Critical Not Critical X

[4] Total Drywell and Suppression Chamber Temperature Correction, -

RECORD the TOTAL VENTiNG CORRECTION from Attachment 3, Section A in the Correction Factor table.

Standard:

Refers to Attachment 3 and records 0 & for Total DW and SC Temperature Correction on Attachment 7 SAT_ UNSAT_ N/A COMMENTS:

Admin RO A2 PAGE 6 OF 9 Performance Step 5: Critical Not Critical X

[5] Total Suppression Chamber Level Correction, RECORD the total Suppression Chamber level correction from Attachment 1, Section A in the Correction Factor table.

Standard:

3 for Total DW and SC Temperature Refers to Attachment I and records (-)682.35 ft Correction on Attachment 7 SAT_ UNSAT N/A COMMENTS:_______________________________

Performance Step 6: Critical Not Critical X

[6] Total Venting Correction using 3-FIC 84-20, RECORD the total Drywell Venting Correction from Attachment 5, Section A in the Correction Factor table.

Standard:

Refers to Attachment 5 and records 0 & for Total Venting Correction using 3-FIC 84-20 on Attachment 7 due to no venting performed during previous 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SAT UNSAT N/A COMMENTS:_______________________________

Admin RU A2 PAGE 7 OF 9 Performance Step 7: Critical Not Critical X

[7] Total Alternate Venting Correction, RECORD the total Drywell Venting Correction from Attachment 6, Section B in the Correction Factor table.

Standard:

3 for Total Alternate Venting Correction on Refers to Attachment 6 and records 0 ft Attachment 7 due to no venting performed during previous 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SAT_ UNSAT_ N/A COMMENTS:________________________________

Performance Step 8: Critical X Not Critical

[8] CALCULATE the the Total Correction Factor as follows:

ADD all the Correction Factor Types together from the Correction Factor Table and RECORD the sum as the Total Correction Factor in the Correction Factor table.

Standard:

Adds the Total Suppression Chamber Level Correction, the Total Venting Correction using 3-FTC 84-20, and the Total Alternate Venting Correction together and determines the Total Correction Factor is (-)682.35 &

SAT_ UNSAT N/A COMMENTS:________________________________

Admin RO A2 PAGE 8 OF 9 Performance Step 9: Critical X Not Critical

[9] CALCULATE the Net Nitrogen Leakage as follows:

Total Gas Addition for the Net Nitrogen Leakage and SUBTRACT the Air Temperature calculation and SUBTRACT the Total Correction Factor.

Standard:

Subtracts the Total DW and SC Temperature Correction and the Total Correction Factor from the Total Gas Addition and determines the Net Nitrogen Leakage 10929.40 ft3 0 ft 3 (-)682.35 ft 3 = 11611 +/- 1.0 ft 3

SAT_ UNSAT N/A COMMENTS:______________________________

Admin RO A2 PAGE 9 OF 9 Performance Step 10: Critical X Not Critical 7.8.2 Attachment 7 Section B Average Nitrogen Leakage Cue: There is an identified Procedure Error, Section 7.8.2 [1] should read: MULTIPLY the net nitrogen leakage from Attachment 7, Section A, (Nitrogen Leakage table), by (1.136/Hours during the day).

[1] MULTIPLY the net nitrogen leakage from Attachment 6 (should read Attachment 7), Section A, (Nitrogen Leakage table), by (1.13 6/Hours during the day).

[2] RECORD the result on the Average Nitrogen Leakage line.

Standard:

Multiplies Net Nitrogen Leakage of 11611 +/- 1.0 & (obtained from Attachment 7, Section A) by 1.136 and divides by 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to determine an Average Nitrogen Leakage of 549.62 +/- 2.0 SCFH. Determines that the Average Nitrogen Leakage is greater than 542 SCFH (AC) and does not initial for the Acceptance Criteria. Checks No on the Surveillance Task Sheet (STS) for Were all Tech Spec/Tech Req/ISFSIJCoC/ODCM/Fire Prot reqt AMSAC* acceptance criteria satisfied.

SAT_ UNSAT N/A _COMMENTS:________________________________

END OF TASK STOP TIME

S 1

A Surveillance Task Sheet (STS)

WO: 111807079 PM#: P3402 Procedure: 3-SI-4.7.A.2.A

Title:

3-Si-4.7.A.2A PRIMARY CONTAINMENT NITROGEN CONSUMPTION AND LEAKAGE horizaVontoIriSRO t7 05 Time tJ& -

Data Sheets Attached:

Pert Grp: OPS UnIt: 3 LoopIDIv z:2a Start & Time D1iE/1ii Completlo Date & lime Test Reason: Conditional Due Date:

Frequency: 1 Days Tech Spec: ASME Xl:

Applicable Modes: Pert Modes: Model Clearance Required: LCO entered:

Dry CaskStorage: N Performed By:

Was this a Complete or Partial Performance?

Print Name /?anaturv Initial Section (Explain Partial In REMARKS below) Complete Partial LI f,ps 44 74 Were all Tech SpeclTech ReqIISFSIJCoCIODCMIFIre Prot reql AMSAC acceptance criteria satisfied? Yes (3 No NIA I) ct Cr 4 Were all other acceptance Criteria satisfied? Yes(J No(]

it all Tech SpeclTech ReqflSFSIIC0C$ODCMIFIre Prot reqIAMSAC Criteria were not satisfied, was a LCOIODCM actioj) required?

(Explain In REMARKS below) Yes No (3 WA (3 PWR only.

Subsequent Reviews:

Group: Slansture JfA Tets Irector Lea Vertomler Date Acceptance Criteria Review: SRO Date & lime PERMANENT COMMENTS:

Independent Reviewer Date & Time REMARKS: W 4 i1 (CfgC.. 1LO4 i1 cc(o( ,lvg z 1 4vrcci si,ppj L&k rer t,a floje,k1 (Avry) w WA RESTRICTED INFORMATION Today, 2012

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 36 of 37 Attachment 7 (Page 1 of 2)

Average Nitrogen Consumption and Leakage Date:

lr-/)Ll

Net Nitrogen Leakage (Section 7*8)

- J1SUM all Gas additions to obtain the Total Addition:

Gas Additidn to the Drywell Total Drywell Control Air Leakage IQl7 4p ft3 Attachment 2, Section A Cumulative Nitrogen Makeup + ii I 3 Attachment 4, Section A ft Total Gas Addition = icM Ia ft3 f

A 7 ir Temperature Correction 1 Air Temperature Total DW and SC Temperature Correction j 2J 3 Attachment 3, Section A ft

,j1SUM all the Correction Factors to obtain a Total Correction Factor:

Correction Factor Total Supp Chamber Level Correction 4 ft Attachment 1, Section B Total Venting Correction using 3-FIC 84-20 (75 3 Attachment 5, Section A ft Total Alternate Venting Correction + (Z 3 Attachment 6, Section B ft Total Corrction Factor = 3 ft

,ICALCULATE Net Nitrogen leakage:

Total Gas Addition Total DW and SC Tempe Correction

- Total Correction Factor Nitrogen Leakae

{

Total Gas Addition /G$4oft (Step I above)

Total DW and SC Temperature Correction -

f ft

(

3 Step 2 above)

Total Correction Factor - 36 ft (Step 3 above) 3 Net Nitrogen Leakage ( /I I, 7ft a, 7

1(1L +/-/,f

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 37 of 37 Attachment 7 (Page 2 of 2)

Average Nitrogen Consumption and Leakage Date: 7t)ti(

/PTtS)

For calculation purposes, a day coiist-ef2-hours. During the days when the time changes to Daylight Savings Time (DST) 23-hours will be used. When returning to C ntral Standard Time (CST) 25-hours will be used.

2 The average nitrogen leakage (adjusted) must be <542 SCFH (Step 6.OA.1). Notify

1 the Unit Supervisor (US) if the nitrogen leakage exceeds 542 SCFH (Refer to 3-AOl-64-7 and Tech Specs 3.6.1.1 .).

verage Nitrogen Leakage (Section 7.8.2)

CALCULATE the Average Nitrogen Leakage Net nitrogen Ieakagexl.136 Avg. Nitrogen Leakage = * =

Hours during the day ft Ava Nitrogen Leakage =

Avg. Nitrogen Leakage SCFH uo IV

(

+-- 4kW Surveillance Task Sheet (STS)

W0 111807079 PM P3402 Procedure: 3-SI-4.T.A.2.A

Title:

3.S1.4;7.A.2.A PRIMARY CONTAINMENT NITROGEN D& I (.i41 CONSUMPTION AND LEAKAGE ftorizationto BIii:/

7 Datet Time Data Shasta Attached:

PefGrp OPS Unte 3 LoOplDIv:

lest Reason: CondItIonal Completion Date & Time Due Date:

Fruquancy 1 Days Tech Spec: ASME XI:

Ap Modom Pmf Modes: Model Clearance Required: EQ LCO entered:

Dry Cask Storags: N Peiformed B pglnt IJno IntfIaI Was this a Complete orPeitlal Performance?

(Explain Partial In REMARKS below) Complete t J Partial (1 Wemafl Tech SpeclTech ReqII8FSUCoCIODCMIF1re Prot reql AMSAC acceptance criteria satisfied? Yes (J No K J WA II Wore all other acceptance Criteria satisfied? Yesti Not] NIA(J If all Tech SpeclTech ReqIISFSIICoCIODCMIFIre Prof reqIAMSAC Criteria wore not satisfied 1 was a LCOJODCM action required?

(Explain In REMARKS below) Yes (J No [] WA (I w FWR only.

Subsequent Reviews:

Group:

Test Director Lead Performer Date Acceptance Criteria Review: SRO Date & Time PERMANENT COMMENTS:

Independent Reviewer Date & lime REMARKS:

WA RESTRICTED INFORMATION Today, 2012

Browns Ferry Nuclear Plant Unit 3 Surveillance Instruction 3-Sl-4.7.A.2.A Primary Containment Nitrogen Consumption and Leakage Revision 0024 Quality Related Level of Use: Continuous Use Level of Use or Other Information: Key Number P3402 Effective Date: 02-29-2012 Responsible Organization: OPS, Operations Prepared By: J D Savage Approved By: Jeffery D. Morrison

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 2 of 37 Current Revision Description Type of Change: Enhancements. Tracking Number: 028 PCRs: 11000391 PERs none Documentation None Minor changes to correct typos and align step with attachments. This PCR was written for lii but applies to U3 also.

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 3 of 37 Table of Contents

1.0 INTRODUCTION

5 1.1 Purpose 5 1.2 Scope 5 1.3 Frequency 5

2.0 REFERENCES

6 2.1 Technical Specifications 6 2.2 Technical Requirements Manual TRM - 6 2.3 Final Safety Analysis Report 6 2.4 Plant Instructions 6 2.5 Plant Drawings 7 2.6 Plant Generated Calculations 7 2.7 Miscellaneous 7 3.0 PRECAUTIONS AND LIMITATIONS 8 3.1 General Precautions 8 3.2 Operability and LCOs 8 3.3 Equipment 8 3.4 Initiation/Isolation/Trips 8 3.5 Interlocks 8 3.6 Performance Testing 9 4.0 PREREQUiSITES 11 5.0 SPECIAL TOOLS AND EQUIPMENT RECOMMENDED 11 6.0 ACCEPTANCE CRITERIA 11 7.0 PROCEDURE STEPS 12 7.1 Initial Requirements And Notifications 12 7.2 Data Collection As Close To Midnight (0000 Hour) As Possible 13 7.3 Suppression Chamber Level 15 7.3.1 Attachment 1 Section A- Suppression Chamber Level Corrections Data 15 7.3.2 Attachment I Section B Total Suppression Chamber Level Correction 15 7.4 Calculating the Drywell Control Air leakage 16

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 4 of 37 Table of Contents (continued) 7.4.1 Attachment 2 Calculate the Drywell Control Air Line A leakage 16 7.4.2 Attachment 2- Calculate the Drywell Control Air Line B leakage 16 7.4.3 Calculate The Total Drywell Control Air Leakage 16 7.5 Air Temperature Correction 17 7.5.1 Attachment 3 Section A Drywell and Suppression Chamber Data 17 7.6 Nitrogen Makeup 18 7.6.1 Attachment 4- Section A Nitrogen Makeup Data

- 18 7.7 Containment Venting 21 7.7.1 Attachment 5 Section A Containment Venting Data using 3-FIC-84-20 21 7.7.2 Attachment 6 Section A Alternate Containment Venting Data 22 7.7.3 Attachment 6 Section B Alternate Containment Venting Correction 23 7.8 Average Nitrogen Consumption And Leakage 24 7.8.1 Attachment 7 Section A Net Nitrogen Leakage

- - 24 7.8.2 Attachment 7- Section B Average Nitrogen Leakage

- 25 7.9 Completion And Notifications 26 8.0 ILLUSTRATIONSIATTACHMENTS 26 Attachment 1: Suppression Chamber Level Correction 27 Attachment 2: Drywell Control Air Leakage Correction 28 Attachment 3: Containment Air Temperature Correction 29 Attachment 4: Nitrogen Makeup Correction 31 Attachment 5: Containment Venting Correction 32 Attachment 6: Alternate Venting Correction 33 Attachment 7: Average Nitrogen Consumption and Leakage 36

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 5 of 37

1.0 INTRODUCTION

1.1 Purpose This Surveillance Instruction provides the necessary steps to monitor the primary containment nitrogen consumption rate (i.e., primary containment system leakage) in compliance with the requirements in Technical Specification 3.6.1.1 and TRM 3.6.2, and 3.6.5.

1.2 Scope Primary containment nitrogen consumption is monitored to determine the average daily nitrogen consumption. Corrections are made for Suppression Chamber level changes and DrywelllSuppression Chamber venting that may occur. The average nitrogen leakage is calculated using data gathered during the day of this test.

For calculation purposes, a day consist of 24-hours. During the days when the time changes to Daylight Savings Time (DST) 23-hours will be used. When returning to Central Standard Time (CST) 25-hours will be used.

1.3 Frequency This Surveillance Instruction shall be performed each day (24-hour duration except the days converting to Daylight Saving Time and returning to Central Standard Time) and reviewed each shift while the reactor is in the RUN mode (Mode 1) and primary containment is inerted.

This procedure is initially started when the conditions are met during Reactor Startup and remains in process until the following Midnight (2400 Hours).

This procedure should be initiated at Midnight (0000 Hours) and remain in process for a 24 Hour period (until the following Midnight (2400 Hours)) or when conditions are no longer met during Reactor Shutdown per Tech Specs..

BFN Primary Containment Nitrogen 3-Si-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 6of37

2.0 REFERENCES

2.1 Technical Specifications Section 3.6.1.1, Primary Containment 2.2 Technical Requirements Manual TRM -

Section 3.6.2, Oxygen Concentration Monitors Section 3.6.5, Nitrogen Makeup to Containment 2.3 Final Safety Analysis Report Section 5.2.2.8, Primary Containment-Safety Design Basis Section 5.2.3.8, Containment Inerting System Section 5.2.4.5, Primary Containment Leakage Analysis Section 5.2.5.1, Primary Containment Integrity and Leak-Tightness Table 5.2-1, Principal Design Parameters and Characteristics of Primary Containment 2.4 Plant Instructions 3-AOI-64-7, Primary Containment N 2 Usage High O-OI-57C, 208/1 20V AC Electrical System Operating Instructions 3-01-64, Primary Containment System Operating Instructions 3-01-84, Containment Atmosphere Dilution System NPG-SPP-06.9.1, Conduct of Testing NPG-SPP-06.9.2, Surveillance Test Program

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 7 of 37 2.5 Plant Drawings I -47E61 0-76-1, Mechanical Control Diagram Containment Inerting System 3-47E61 0-64-1, 2, 3, Mechanical Control Diagram Primary Containment System 3-47E610-76-1, Mechanical Control Diagram Containment Inerting System 1 -47E860-1, Flow Diagram Containment Inerting System 3-47E860-1, Flow Diagram Containment Inerting System 2.6 Plant Generated Calculations PGC-003-064-0, Change in Torus Free Volume Per I of Water Level 2.7 Miscellaneous BFPER970886, Calculating Leakage when CAD is cross-tied to Drywell Control Air

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 8 of 37 3.0 PRECAUTIONS AND LIMITATIONS 3.1 General Precautions A. This procedure should be initiated at Midnight (0000 Hours) and remain in process for a 24 Hour period (until the following Midnight (2400 Hours)).

B. If it is necessary to begin a new revision to the procedure before the time period is completed, then the appropriate data must be transferred to the new document and the two procedures maintained together.

C. For an INDEPENDENT REVIEWER signature, the STA or SRO cannot perform any actions or signoffs in the body of the procedure. This will ensure an adequate review of the procedure.

3.2 Operability and LCOs A. If Nitrogen leakage exceeds 542 SCFH, 3-AOl-64-7 and TECH SPECS must be referred to for further action.

1. 2 makeup to the primary containment is > 542 scth, If 24-Hour average N then Primary Containment must be declared INOP immediately.

(Refer to LCO 3.6.1.1.)

B. If the nitrogen consumption demonstrates a trend that will be greater than 542 SCFH for the 24-hour period, notify the Unit Supervisor (US) immediately.

3.3 Equipment A. When a Drywell Control Air Totalizer is mop, the DWCA System Engineer will use the AUO Rounds to determine the average flow to be used for N2 Drywell Control Air Flow.

B. When a Drywell Control Air Totalizer is INOP and a break or a leak occurs in the drywell from an air line, then the number of times the drywell is vented will rise based upon the severity of the leak or break. System Engineering should monitor and address any raise in Venting Requirements to determine if it is caused by a Drywell Control Air Line leak or due to atmospheric conditions.

3.4 lnitiationllsolationlTrips None 3.5 Interlocks None

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 9 of 37 3.6 Performance Testing A. Since changes in Suppression Chamber level change the Suppression Chamber free volume, the Torus atmospheric pressure will change, although nitrogen may not have been lost or added.

1. The Suppression Chamber level may change for any number of events such as venting the drywell/suppression chamber, pumping down the Suppression Chamber, MSRVs Leakage or testing Core Spray, RHR, HPCI, or RCIC Systems.

2. The correction for level changes is based on the assumption that the Suppression Chamber level change is relatively small (-1 to -7.25 indicated level) allowing the effect of Suppression Chamber curvature to be neglected. Therefore, the 909.8 cubic feet change in volume per one inch change in Suppression Chamber level is assumed constant.

B. Changes in either the Drywell or Suppression Chamber Air Temperature would cause a change in Containment Pressure under idea conditions. Due to the continuous Drywell Control Air addition and possible venting during the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period the changes in containment pressures may not be as expected.

Therefore when a change of more than 2 °F in either area occurs a Temperature Correction will be performed for that areas Air Temperature, otherwise zero 0 will be used for the correction factor.

C. For Sections 7.5and 7.7.2 if one pressure indicator and/or differential indicator is inoperable, (NA the appropriate column on the Attachment, note the mop indicator on Attachment 3 and 6, and delete dividing by 2 for that particular term in the equation.)

D. Attachment 3, Section B should be used to calculate the venting correction factor when any of the following instrumentation is unavailable.

1. Both DRYWELL PRESSURE, 3-Pl-64-135 and 3-Pl-64-136

2. DRYWELL TEMPERATURE, 3-TI-64-52AB E. Attachment 4, Section B should be used to calculate the venting correction factor when any of the following instrumentation is unavailable.

1. Both DRYWELL PRESSURE, 3-Pl-64-1 35 and 3-Pl-64-1 36

2. Both DW/SUPPR CHBR DIFF PRESS, 3-PDI-64-137 and 3-PDI-64-138

3. DRYWELL TEMPERATURE, 3-Tl-64-52AB

4. SUPPR POOL WATER LEVEL, 3-Ll-64-54A and 3-Ll-64-66

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 10 of 37 3.6 Performance Testing (continued)

F. Drywell/Suppression Chamber venting may be required to maintain Drywell pressure within limits during changes in barometric pressure, maintenance on Drywell Delta P Air Compressors, or other similar events. When using the Alternate Venting Correction equation in Attachment 6, the following assumptions are used.

1. The Drywell free volume is 159,000 cubic feet.

2. The Suppression Chamber free volume is 126,200 cubic feet at -1 inches (3-Ll-64-54A or 66, Suppr Pool Water Level), and an additional 909.8 cubic feet of free volume for each inch that water level is lowered.

3. The actual venting process is a rapid event so barometric pressure changes can be neglected.

4. The average Drywell temperature change is represented by DRYWELL TEMPERATURE indicator 3-Tl-64-52AB, and DRYWELL TEMPERATURE/PRESSURE recorder 3-XR-64-50.

5. Drywell and Suppression Chamber nitrogen pressures are low enough to use the ideal gas law as a model, i.e.

=l_[PBTA1XV

[ A B]

Where: =

0 V Venting Correction

=

8 P Drywell or Suppression Chamber pressure before venting PA= Drywell or Suppression chamber pressure after venting

=

8 T Drywell or Suppression Chamber temperature before venting TA Drywell or Suppression Chamber temperature after venting V= Total free volume of Drywell or Suppression Chamber

6. The Suppression Chamber water and atmospheric temperatures are in equilibrium.

BFN Primary Containment Nitrogen 3-S14.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 11 of 37 Date:

PREREQUISITES VERIFY this instruction to be the most current revision.

OBTAIN a Surveillance Task Sheet (STS) for this procedure and Work Activity. (Key Number P3402)

VERIFY Cabinet 2, Panel 9-9 is energized in accordance with

-- 0-Ol-57C, 208/1 20V AC Electrical System Operating Instruction.

SPECIAL TOOLS AND EQUIPMENT RECOMMENDED

,CaIcuIator ACCEPTANCE CRITERIA Responses which fail to meet the following acceptance criteria constitute

/ unsatisfactory surveillance instruction results and require the immediate notcation of the Unit Supervisor at the time of failure:

Nitrogen makeup to the primary containment, averaged over 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months f (corrected for Suppression Chamber level changes and Drywell/Suppression Chamber venting) is less than 542 standard cubic feet per hour (SCFH).

(I Steps which determine the above criteria are designated by (AC) next to the

/ initials blank.

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 12 of 37 Date:

This procedure should be initiatedght which is represented as (0000 Hours) and remain in process for a 24 Hour period (until the following Midnight which is represented as (2400 Hours)). These times are used to represent the difference from the start and the completion of this SR and may not match the proper military times that is used by the electronic narrative logs.

If it is necessary to stop this procedure and recommence with a new revision before the time period is completed, the appropriate data must be transferred to the new document and the two procedures maintained together..

PROCEDURE STEPS Initial Requirements And Notifications VERIFY the Precautions and Limitations in Section 3.0 have been reviewed.

VERIFY the Prerequisites in Section 4.0 are satisfied.

On the Surveillance Task Sheet (STS)

OBTAIN Authorization Signature and Date/Time from the Unit Supervisor/SRO to perform this surveillance.

On the Surveillance Task Sheet (STS)

RECORD the Start Date & Time.

RECORD the date on each data sheet Attachments I through 7.

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 13 of 37 Date:

This procedure should be initiated by the midnight shift Unit Supervisor or by the Unit Supervisor of any shift meeting the requirements of Section 1.3.

For the first run of the 24-hour period, the previous cumulative total is zero since totals are not carried over from the previous 24-hour test.

7 Data Collection As Close To Midnight (0000 Hour) As Possible RECORD on Attachment I Part A, the initial Suppression Pool

)C/ Level (0000 Hour), in column (I) for each of the following instruments (if available) on Panel 9-3.

SUPPR POOL WATER LEVEL, 3-Ll-64-54A

SUPPR POOL WATER LEVEL, 3-Ll-64-66 on Attachment 2 in the INITIAL column, the 1RECORD Drywell Control Air Loop A flow from the N2 Containment Inerting system, from one of the following:

DWCA FLOW ELEMENT HEADER A, 3-FIQ-032-0092 (Rx Bldg El 565 R16 S Line).

OR

Average flow as determined by the DWCA System Engineer if 3-FIQ-032-0092 is INOP.

(Reference Step 3.3A) je RECORD on Attachment 2 in the INITIAL column, the

)C- Drywell Control Air Loop B flow from the N2 Containment Inerting system, from one of the following:

DWCA FLOW ELEMENT HEADER B, 3-FIQ-032-0075 (Rx Bldg El 565 R20 Q Line).

OR

Average flow as determined by the DWCA System Engineer if 3-FIQ-032-0075 is INOP.

(Reference Step 3.3A)

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 14 of 37 Date: eqe;:

$ Data Collection As Close To Midnight (0000 Hour) As Possible (continued)

RECORD on Attachment 3 in the 0000 Hours the following data.

Drywell Pressure 3-Pl-64-135

Drywell Pressure 3-P1-64-136

Drywell Temperature 3-Tl-64-52AB

Drywell Differential Pressure 3-DPI-64-1 37

Drywell Differential Pressure 3-DPI-64-1 38

SUPP CHBR TEMP, 3-TE-64-52B on SUPPRESSION CHAMBER TEMPERATURE/PRESSURE, 3-XR-64-52 (point 1)

BFN Primary Containment Nitrogen 3-St-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 15 of 37 The correction for level changes is based on the assumption that the Suppression Chamber level change is relatively small (-1 to -7.25 indicated level) allowing the effect of Suppression Chamber curvature to be neglected. Therefore, the 909.8 cubic feet change in volume per one inch change in Suppression Chamber level is assumed constant.

Suppression Chamber Level Attachment I Section A- Suppression Chamber Level Corrections Data At the beginning of the surveillance (0000 hours0 days 0 hours 0 weeks 0 months ), RECORD the Suppr Pool

,X_...

Water Level from indicators 3-LI-64-54A and 3-Ll-64-66 on Panel 9-3, in column (1) for each available instrument.

At the end of the surveillance (2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months ), RECORD the Suppression Chamber level from indicators 3-Ll-64-54A and 3-LI-64-66 on Panel 9-3, in column (2), for each available instrument.

IF both instruments are available, 3-Ll-64-54A and 3-LI-64-66, THEN SUBTRACT column (2) from column (1) to determine the amount of change in Suppression Chamber level and RECORD in column (3) (negative numbers are possible).

For each instrument 3-Ll-64-54A and 3-LI-64-66, CALCULATE the change in ic Suppression Chamber free volume as standard cubic feet (SCF) by multiplying column (3) by column (4) (909.8 ftlin.) and RECORD in 3

column (5).

.2 Attachment I - Section B Total Suppression Chamber Level Correction

IF both (64-54A & 64-66) instrument are available, THEN ADD column (5) for each instrument and DIVIDE by two (for calculating the average) and RECORD results as the Total Suppression Chamber Level Correction blank.

IF an instrument is unavailable, THEN USE only the operable instrument and ENTER the column (5) value for the operable instrument as Total Suppression Chamber Level Correction blank.

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 16 of 37 Calculating the Drywell Control Air leakage Attachment 2 - Calculate the Drywell Control Air Line A leakage At the beginning of the surveillance (0000 hours0 days 0 hours 0 weeks 0 months ), RECORD the DWCA FLOW ELEMENT HEADER A, 3-FIQ-032-0092 in the column (2) INITIAL (0000 hours0 days 0 hours 0 weeks 0 months ).

At the end of the surveillance (2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months ), RECORD the DWCA FLOW

- ELEMENT HEADER A, 3-FIQ-032-0092 in the Column (1) ENDING (2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months )

CALCULATE the daily difference for Drywell Control Air Loop A, 3-FIQ-032-0092.

Column (1) Column (2)

- = Difference (Column 3)

Attachment 2 - Calculate the Drywell Control Air Line B leakage At the beginning of the surveillance (0000 hours0 days 0 hours 0 weeks 0 months ), RECORD the DWCA FLOW ELEMENT HEADER B, 3-FIQ-032-0075 in the column (2) INITIAL (0000 hours0 days 0 hours 0 weeks 0 months ).

At the end of the surveillance (2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months ), RECORD the DWCA FLOW X ELEMENT HEADER B, 3-FIQ-032-0075 in the Column (1) ENDING (2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months )

,1CALCULATE the daily difference for Drywell Control Air Loop A, 3-FIQ-032-0075.

Column (1) - Column (2) = Difference (Column 3)

,CaIculate The Total Drywell Control Air Leakage

. SUM the Drywell Control Air Loop A, 3-FIQ-032-0092 Difference and Drywell Control Air Loop B, 3-FIQ-032-0075 Difference.

3-FIQ-032-0092 (Difference) + 3-FIQ-032-0075 (Difference) = Total

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 17 of 37 Date:

V Air Temperature Correction 3- Section A - Drywell and Suppression Chamber Data Aftachment At the beginning of the surveillance (0000 hours0 days 0 hours 0 weeks 0 months ), RECORD on

). Attachment 3 in the 0000 Hours the following data.

DRYWELL PRESSURE 3-Pl-64-1 35

DRYWELL PRESSURE 3-Pl-64-136

DRYWELL TEMPERATURE 3-Tl-64-52AB

DW/SUPPR CHBR DIFF PRESS 3-DPI-64-137

DW/SUPPR CHBR DIFF PRESS 3-DPI-64-138

SUPP CHBR TEMPI 3-TE-64-52B on SUPPRESSION CHAMBER TEMPERATURE/PRESSURE, 3-XR-64-52 (point 1)

At the end of the surveillance (2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months ), RECORD on

,&. Attachment 3 in the 2400 Hours the following data.

DRYWELL PRESSURE 3-Pl-64-135

DRYWELL PRESSURE 3-Pl-64-136

DRYWELL TEMPERATURE 3-TI-64-52AB

DW!SUPPR CHBR DIFF PRESS 3-DPI-64-137

DW/SUPPR CHBR DIFF PRESS 3-DPI-64-138

SUPP CHBR TEMP, 3-TE-64-52B on SUPPRESSION CHAMBER TEMPERATURE/PRESSURE, 3-XR-64-52 (point 1)

Suppression Pool Level 3-Ll-64-54A or 3-Ll-64-66 IF the Drywell Temperature has changed by 2°F or more, THEN PERFORM the calculation using Section B for Drywell and enter the result in column (8) of Section A. (Otherwise enter 0 (Zero) for the calculation.)

IF the Suppression Chamber Air Temperature has changed by 2°F or more,

)L- THEN PERFORM the calculation using Section C for Suppression Chamber and enter the result in column (9) of Section A. (Otherwise enter 0 (Zero) for the calculation.)

Calculate the Total Correction Factor as follows SUM the Drywell (Column 8) and Suppression Chamber (Column 9) and entering the results in Column (10).

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 18 of 37

) Stopwatch may be used to perform Section 7.6.1.

(Nitrogen flow should be less than 60 SCFM in accordance with 3-01-64, Primary

/ Containment when performing Section 7.6.1.

Nitrogen Makeup Attachment 4- Section A Nitrogen Makeup Data IF Makeup is from the Nitrogen Storage Tank, THEN.

PERFORM the following during Nitrogen additions:

01 In EVENT Column, RECORD N2 Tank.

In column (1), RECORD the time each nitrogen addition begins.

In column (2), RECORD the nitrogen makeup duration, in minutes, from the chart of DW/SUPPR CHBR N2 MAKEUP FLOW/PRESS recorder, 3-XR-076-0014 on Panel 9-3 or from stopwatch.

In column (3), RECORD the nitrogen makeup flow in cubic feet per K. minute as indicated by the Red Pen on DW/SUPPR CHBR N2 MAKEUP FLOW/PRESS, 3-XR-076-0014 on Panel 9-3.

CALCULATE the amount of nitrogen, in cubic feet (ft ), added during 3

the run by multiplying column (2) by column (3) and RECORD in column (4).

CALCULATE the total cumulative nitrogen use in cubic feet for the 24-hour period of this test by adding the latest entry in column (4) to the previous cumulative total in column (5) and RECORD the new cumulative total in column (5).

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 19 of 37 Attachment 4- Section A Nitrogen Makeup Data (continued)

[QCIC) IF CAD is cross-tied to Drywell Control Air, THEN PERFORM the following: (REFER TO 3-01-84) [BFpER95O93S]

[2.1] In EVENT Column, RECORD CADIDCA.

[2.2] In Column (1), RECORD the time CAD was cross-tied to Drywell Control Air on the CAD/DCA line provide.

[2.3] In Column (2), RECORD the duration in minutes that CAD was cross-tied to Drywell control air.

[2.4] OBTAIN calculated Total Leakage(CFM) from Site Engineering.

[2.5] In Column (3), RECORD the calculated Total Leakage(CFM) obtained from Site Engineering.

[2.6] CALCULATE the amount of nitrogen added during the period by multiplying columns (2) and (3) and RECORD in column (4).

[2.7] CALCULATE the total cumulative nitrogen use in cubic feet for the 24-hour period of this test by adding the latest entry in column (4) to the previous cumulative total in column (5) and RECORD the new cumulative total in column (5).

BFN Primary Containment Nitrogen 3-Sl-4.7A2.A Unit 3 Consumption and Leakage Rev. 0024 Page 20 of 37 Attachment 4 Section A Nitrogen Makeup Data (continued)

Measure the CAD addition using a stop watch.

5Use a separate Event Column for each CAD TRAIN if both trains are being used at the

) same time.

J3 IF CAD is aligned to Containment other than Section 7.6.1[2), THEN PERFORM the following for any CAD additions.

[3.1] In EVENT Column, RECORD CAD/CONT

[3.2] In column (1), RECORD the time each CAD addition begins.

[3.3] In column (2), RECORD the CAD addition duration, in minutes from the stopwatch.

[3.4] In column (3), RECORD the CAD makeup flow in cubic feet per minute for each CAD train being used:

CAD A N2 SYSTEM FLOW

O-FI-84-713, CAD A N2 SYSTEM FLOW, on 3-PNL-9-54.

OR

O-FI-84-7, CAD LINE A N2 FLOW, on (Unit 1) PNL-9-54 CAD B N2 SYSTEM FLOW

O-Fl-84-1 8/3, CAD B N2 SYSTEM FLOW, on 3-PNL-9-55.

OR

O-FI-84-18, CAD B N2 SYSTEM FLOW, on (Unit 1) PNL-9-55.

[3.5] CALCULATE the amount of nitrogen, in cubic feet (ft ), added during 3

the run by multiplying column (2) by column (3) and RECORD in column (4).

[3.6] CALCULATE the total cumulative nitrogen use in cubic feet for the 24-hour period of this test by adding the latest entry in column (4) to the previous cumulative total in column (5) and RECORD the new cumulative total in column (5).

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 21 of 37 Containment Venting Attachment 5 Section A Containment Venting Data using 5

3-FIC-84-20

/J/\ [1] In column (1), -

RECORD the time the venting begins.

[2] In column (4), -

RECORD the vent flow rate indicated on PATH A VENT FLOW CONT, 3-FIC-84-20.

[3] In column (2), -

RECORD the time the venting ends.

[4] In column (3), -

RECORD the elapsed venting time in minutes by subtracting column (1) from column (2).

[5] In column (5), -

RECORD the Suppression Chamber Venting Correction Factor by multiplying column (3) by column (4).

/ [6] In column (6), Total Cumulative Correction -

RECORD the SUM of the previous event column (6) and the current event column (5).

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 22 of 37 I

Alternate Containment Venting Data is performed when 3-FIC-84-20 indication is not available.

Ycttachment 6- Section A Alternate Containment Venting Data

[1] PRIOR to Venting IA PERFORM the following using instruments on Panel 9-3:

A. In column (1),

RECORD the time the venting begins.

B. In column (2), block ,81 P

RECORD the DRYWELL PRESSURE, 3-Pl-64-135 indication.

C. In column (3), block ,82 P

RECORD the DRYWELL PRESSURE, 3-Pl-64-136 indication.

D. In column (4), block TBI, RECORD the DRYWELL TEMPERATURE, 3-Tl-64-52AB.

E. In column (5), block PB3, RECORD the DW/SUPPR CHBR DIFF PRESS, 3-DPI-64-137 indication F. In column (6), block PB4, RECORD the DW/SUPPR CHBR DIFF PRESS, 3-DPI-64-138, indication G. In column (7), block ,

52 T

RECORD the SUPP CHBR TEMP, 3-TE-64-52B on SUPPRESSION CHAMBER TEMPERATURE/PRESSURE, 3-XR-64-52 (point 1)

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 23 of 37 j

1 Attachment 6 Section A Alternate Containment Venting Data (continued)

JA [2J AFTER the Venting Event is completed, A. In column (2), block PAl, RECORD the DRYWELL PRESSURE, 3-Pl-64-1 35 indication.

B. In column (3), block P, RECORD the DRYWELL PRESSURE, 3-P 1-64-136 indication.

C. In column (4), block TAI, RECORD the DRYWELL TEMPERATURE 3-Tl-64-52AB.

D. In column (5), block P, RECORD the DW/SUPPR CHBR DIFF PRESS, 3-DPI-64-137 indication E. In column (6), block PA4, RECORD the DW/SUPPR CHBR DIFF PRESS, 3-DPI-64-1 38, indication F. In column (7), block T, SUPP CHBR TEMP, 3-TE-64-52B on SUPPRESSION CHAMBER TEMPERATURE/PRESSURE, 3-XR-64-52 (point 1)

G. In column (8), RECORD the SUPPR POOL WATER LEVEL, 3-Ll-64-54A. (Use 3-LI-64-66 if 3-Ll-64-54A is INOP.)

H. In column (9), CALCULATE the DRYWELL VENTING CORRECTION using the Drywell Venting Correction Formula in Section C.

I. In column (10), CALCULATE the SUPPRESSION CHAMBER VENTING CORRECTION using the Suppression Chamber Venting Correction Formula in Section C.

J. In column (11), RECORD the sum the DRYWELL VENTING CORRECTION Column (9) and SUPPRESSION CHAMBER VENTING CORRECTION Column (10).

Attachment 6 Section B Alternate Containment Venting Correction pjf. [1] At the completion of the 24-hour period

In column (12) RECORD the Total Venting Correction, Attachment 6, Section B by ADDING all the TOTAL VENTING CORRECTION from Section A, Column (11).

BFN Primary Containment Nitrogen 3-Sl-4.7A2.A Unit 3 Consumption and Leakage Rev. 0024 Page 24 of 37 Average Nitrogen Consumption And Leakage 7.8.1 Attachment 7 Section A Net Nitrogen Leakage

[1] Total Drywell Control Leakage, RECORD the Total Drywell Control Air Leakage from Attachment 2 in the Gas Addition to the Drywell table.

[2] Cumulative Nitrogen Makeup, RECORD the total cumulative nitrogen makeup from Attachment 4 Section A in the Gas Addition to the Drywell table.

[3] CALCULATE the Total Gas Addition as follows:

ADD all the Gas addition types together from the Gas Addition Table and RECORD the sum as the Total Gas Addition in the Gas Addition to the Drywell table.

[4] Total Drywell and Suppression Chamber Temperature Correction, RECORD the TOTAL VENTING CORRECTION from Attachment 3, Section A in the Correction Factor table.

[5] Total Suppression Chamber Level Correction, RECORD the total Suppression Chamber level correction from Attachment 1, Section A in the Correction Factor table.

[6] Total Venting Correction using 3-FIC 84-20, RECORD the total Drywell Venting Correction from Attachment 5, Section A in the Correction Factor table

[7] Total Alternate Venting Correction, RECORD the total Drywell Venting Correction from Attachment 6, Section B in the Correction Factor table.

[8] CALCULATE the Total Correction Factor as follows:

ADD all the Correction Factor Types together from the Correction Factor Table and RECORD the sum as the Total Correction Factor in the Correction Factor table.

[9] CALCULATE the Net Nitrogen Leakage as follows.

Total Gas Addition for the Net Nitrogen Leakage and SUBTRACT the Air Temperature calculation and SUBTRACT the Total Correction Factor.

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 25 of 37 7.8.2 Attachment 7- Section B Average Nitrogen Leakage NOTE Leakage rates, for comparison purposes, should always be converted to standard flow rate conditions (flow at 70°F, one standard atmosphere). Since nitrogen gas is supplied by evaporating liquid nitrogen and heating it to approximately 70°F then reducing the pressure to 2.0 psig the conversion is:

14.7psia + 2.Opsig 460°R + 70°F

< = 1136 14.7psia 460°R + 70°F Where: 14.7 psia = I standard atmosphere 2.0 psig = nitrogen supply pressure 460°R = Fahrenheit to Rankine conversion factor 70°F = degrees Fahrenheit of nitrogen, actual and standard For calculation purposes, a day consist of 24-hours. During the days when the time changes to Daylight Savings Time (DST) 23-hours will be used. When returning to Central Standard Time (CST) 25-hours will be used.

To average the net nitrogen usage (in ft 3 for a day, a 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period is normally used and the result are expressed in standard cubic feet per hour. The net nitrogen leakage is multiplied by a conversion factor 1.136, then divided by the number of hours in the day.

The result gives the average nitrogen leakage in standard cubic feet per hour for that day.

When Daylight Savings Time and Central Standard Time changes take place, the appropriate number of hours will be used instead of 24 (hours).

[11 MULTIPLY the net nitrogen leakage from Attachment 6, Section A, (Nitrogen Leakage table), by (1.136/Hours during the day).

[2] RECORD the result on the Average Nitrogen Leakage line.

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 26 of 37 Date:

7.9 Completion And Notifications

[1] On the Surveillance Task Sheet (STS),

[1.1] RECORD the Completion Date & Time.

[1.2] REVIEW and COMPLETE the Surveillance Task Sheet (STS) through the Test Director/Lead Performer & Date fields.

[2] NOTIFY the Unit Supervisor that this Surveillance Instruction is complete.

8.0 ILLLJSTRATIONSIATTACHMENTS Attachment 1: Suppression Chamber Water Level Correction Attachment 2: Drywell Control Air Leakage Correction Attachment 3: Containment Air Temperature Correction Attachment 4: Nitrogen Makeup Correction Attachment 5: Containment Venting Corrections Attachment 6: Alternate Venting Correction Attachment 7: Average Nitrogen Consumption and Leakage

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 27 of 37 Attachment I (Page 1 ofl)

Suppression Chamber Level Correction Date: 77:v jJ92 SUPPRESSION CHAMBER LEVEL CORRECTION DATA N S If both Instruments are Operable, then calculate the average of BOTH Operable Instruments by Dividing the sum of their SUPPRESSION CHAMBER LEVEL CORRECTION (column 5) by 2 (two) and record as the TOTAL SUPPRESSION CHAMBER LEVEL CORRECTION.

5lf one of the instruments is INOP, then use only the Operable Instrumentation c Correction Factor for the TOTAL SUPPRESSION CHAMBER LEVEL CORRECTION.

1Suppression Chamber Level Data (Section 7.3.1)

(1) (2) (3) (4) (5)

Initial Ending Suppr Chbr Suppr Chbr Suppr Chbr Change in Conversion Level Level (IN.) LEVEL (IN.) Suppr Chbr Factor Correction UO Instrument (0000 Hours) (2400 Hours> Level (IN.) /IN.

909.8 FT 3 )

3 (FT INIT 3-LI-64-54A 3. n - 2.0 1.0 x 909.8 = Qd1 .

3-LI-64-66 -3.7 - 3.. Z = 0. x 909.8 = .EjjLl, B. Total Suppression Chamber Level Correction Calculation (Section 7.3.2)

Column 5(ft

)

3 + Column 5(ft

)

3 for 3-LI-64-54A for 3-LI-64-66

= Average Suppression Chamber Level 2

Yd?.2 (ft _qq,g (if

)

3 )

3 3LI6454A3--L16466 _42ft) 2 UO

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 28 of 37 Attachment 2 (Page 1 ofl)

Drywell Control Air Leakage Correction Date:

,DrywelI Control Air Leakage (Section 7.4)

Drywell Control Air Line A FLOW DWCA FLOW ELEMENT HEADER A, 3-FIQ-032-0092 (Rx Bldg El 565 16 S Line)

(1) (2) (3)

ENDING INITIAL Difference (2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months ) (0000 hours0 days 0 hours 0 weeks 0 months ) pIp5I.7

)

3 (FT )

3 (FT Drywell Control Air Line B Flow DWCA FLOW ELEMENT HEADER B,3-FIQ-032-0075 (Rx Bldg El 565 R20 Q Line).

(1) (2) (3)

ENDING INITiAL Difference (2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months ) (0000 hours0 days 0 hours 0 weeks 0 months ) 3g,-

g 7 4 - 2Z =

)

3 (FT (FT) )

3 (FT Drywell Control Air Leakage 3-FIQ-032-0092 3-FIQ-032-0075 Difference Difference (Column 3) (Column 3) Total 43/too + =

)

3 (FT )

3 (FT uo

( BEN Unit 3 Primary Containment Nitrogen Consumption and Leakage 3-SI-4.7.A.2.A Rev. 0024 L Page 29 of 37 Attachment 3 (Page 1 of 2)

Containment Air Temperature Correction Date: I o(W/

Drywell Temperature changed less than 2 °F, enter zero (0) in Column 8.

6Suppression Chamber Air Temperature changed less than 2 °F, enter zero (0) in Column 9

,fDrywelI and Suppression Chamber Data DRYWELL Differential Suppression Chamber Pressure Temp Pressure Air Temp Level (1) (2) (3) (4) (5) (6) (7) 3-Pl-64-1 35 3Pl-64-1 36 3-Tl-64-52AB 3-PDI-64-1 37 3-PDI-64-1 38 3-XR-64-52 3-Ll-64-54A (psig) (psig) (°F) (psid) (psid) Point I (°F) or 66 0000 hours0 days 0 hours 0 weeks 0 months N/A P

8 1 02 ISo TBI 1Z5 3 I LiZ T 8 2 2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months / ?o / I, 0 PAl /, ]7 TAI / 3 PA 4 PA ZZ T LA (8) (9) (10)

SUPRESSION DRYWELL VENTING CHMBR VENTING Total VENTING UO CORRECTION CORRECTION CORRECTION Initials rr3 ri ÷ 7 3 FT = 3 FT

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 30 of 37 Attachment 3 (Page 2 of 2)

,IDrYweII Temperature Correction Equation (Section 7.7.3)

+

7 + 460 )

J I\ I

- , +

- x 159000 Drywell Temperature Correction

[14.7÷( A)]x(T ÷460) 2 where: 81 P = Orywell pressure before venting taken from DRYWELL PRESSURE indicator 3-Pl-64-135 2

PB = Drywell pressure before venting taken from DRYWELL PRESSURE indicator 3-Pl-64-136 PAl = Drywell pressure after venting taken from DRYWELL PRESSURE indicator 3.Pl.64..135

= Drywell pressure after venting taken from DRYWELL PRESSURE indicator 3-Pl-64-1 36

+460 8

T 1 = Drywell temperature before venting taken from DRYWELL TEMPERATURE indicator 3-TI-64-52AB and corrected to absolute temperature (Rankine)

TAl460 = DryweA temperature after venting taken from DRYWELL TEMPERATURE indicator 3-TI-64-52AB and corrected to absolute temperature (Rankine)

Suppression Chamber Temperature Correction Equation

[ 47 ÷P82)(PB3+PD4)]X(T+

+(PBI 1 )

460 2 2 X[12620O[(LA+I)X909.8=

Suppression Chamber f\.)j\ 1

)

2

+PA ; PA4)](T +460) 3 (PA Temperature Correction

[147÷(1 where: Psi = Drywell pressure before venting taken from DRYWELL PRESSURE indicator 3-Pl-64-1 35 82 P = Drywell pressure before venting taken from DRYWELL PRESSURE indicator 3-Pl-64-1 36 83 P = OrywelllSuppression Chamber differential pressure before venting taken from DWISUPPR CHBR DIFF PRESS indicator 3-PDI-64-137 P = Drywell/Suppression Chamber differential pressure before venting taken from DWISUPPR CHBR 01FF PRESS indicator 3-PDI-64-138 82 T + 460 = Suppression Chamber temperature before venting taken from SUPPRESSION CHAMBER TEMPERATUREIPRESSURE recorder, (3-XR.64-52 Point 1) and corrected to absolute temperature (Rankine)

T + 460 = Suppression Chamber temperature after venting taken from SUPPRESSION CHAMBER TEMPERATURE/PRESSURE recorder. 3-XR-64-52 (Point 1) and corrected to absolute temperature (Rankine)

PAl = Drywell pressure after venting taken from DRYWELL PRESSURE indicator 3-Pl-64-135 P = Drywell pressure after venting taken from DRYWELL PRESSURE indicator 3-Pl-64-136 P = Drywell!Suppression Chamber differential pressure after venting taken from DW1SUPPR CHBR 01FF PRESS indicator 3-PDI-64-137 PA4 = Drywell/Suppression Chamber differential pressure after venting taken from DWISUPPR CHBR DIFF PRESS indicator 3-PDI-64-138 LA = Suppression Chamber water level taken from SUPPR POOL WATER LEVEL indicator 3-LI-64-54A or 66.

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 31 of 37 Attachment 4 (Page 1 ofl)

Nitrogen Makeup Correction Date:

Nitrogen Makeup Data (Section 7.6.1)

MAKEUP N ADDED 2 N MAKEUP (4) 2 DURATION N M

2 AKEP (2) X (3) + PREVIOUS (5)

TIME (MINUTES) FLOW (CFM) (FT 3) (FT3)

UO (1) (2) (3) (4) (5) Initials EVENT

1. /\jz.1cii L / x = .4_()

2. (1O x = f7 1*17

3. x = 2/

4. (L I (/c x = /1 o

5. ,J -t 7 x =

,g4

6. .J -k t

2 L7D x =

7.fj 1M LcQ x =

J 8 16k- x

=

3i2 Remarks: /\JoIE

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024

Page 32 of 37 Attachment 5 (Page 1 of 1)

Containment Venting Correction Date: 1 Thf] y A. Venting Data using 3-FtC 84-20, NOTE Enter data for each venting event: (ie. flow started and stopped through vent valves)

EVENT Calculations (1) (2) (3) (4) (5) (6)

ELAPSED Event Total VENT FLOW RATE Total Cumulative START END TIME 3-FIC-84-20 (SCF) Correction TIME TIME (MIN) (SCFM) (Note 1) (Note 2) .

1al 1

2 3

4 5

6 7

7

/

7 8

9 10 11

/

12

/

13

-- /

--/

/

17 Note I Column (3) x Column (4)

Note 2 Previous Event Column (6) + Current Event Column (5)

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 33 of 37 Attachment 6 (Page 1 of 3)

Alternate Venting Correction Date: 7)fl4Y IAIternate Containment Venting Data is performed when 3-FIC-84-20 indication is not available.

this table the BEFORE is prior to establishing flow through the vent valves.

or after the DP Air Compressor 32he AFTER is when venting is completed, regardless of the number of times for the event. It can also be taken either before pumps up the drywell, but do not take data while the DP is running.

2se 3-Ll64-54A unless INOP then use 3-Ll-64-66.

A. Alternate Venting Data (Section 7.7.2)

DRYWELL Differential Suppression Chamber Temp Pressure I Pressure (2) (3) (4) (5) (7) (8)

(1) 3-Pl-64-1 35 3-Pl 136 3-Tl-64-52AB jjQ.L4t37 3-PDI 138 3-XR-64-52 3-Ll-64-54A (psig) (psig) (°F)_ (psid) (psid) Point 1 (°F) or 66 EVENT TIME (BEFORE) PBl P 8 3 P 8 4 2 TB N/A 1 P PM T (AFTER)

(BEFORE)

PAI D81

/ 1 T

T 8 1 P Ps., T 8 2 LA N/A 2 TAI 3 PA P 8 4 T 8 4 LA (AFTER)

(BEFO,- P 8 1 P 8 4 T 0 1 P 8 3 P 8 4 T 8 2 N/A 1

P, 2 P, 1 T, 3 PA P 8 4 2 T, LA PcThR) 81 P PRZ T 8 1 P 8 3 P 8 4 T 8 2 N/A (BEFORE)

P 8 1 P, TAI 3 P, P 8 4 LA (AFTER)

P 8 1 P 8 2 T 8 1 P 8 4 T 8 2 N/A (BEFORE)

PAZ 7 T, PAZ P 8 4 T 8 4 LA (AFTER) PAI

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 34 of 37 Attachment 6 (Page 2 of 3)

Alternate Venting Correction Date:

(9) (10) (11)

DRYWELL VENTING SUPRESSION CHMBR TOTAL VENTING uO CORRECTION VENTING CORRECTION CORRECTION 1 + =

+ -

2

+

3

+

4 5 +

B. Total Alternate Venting Sum all of the T Corrections from Section A, Column 11 (12)

TOTAL VENTING UO CORRECTION Initial 3

FT

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 35 of 37 Attachment 6 (Page 3 of 3)

Alternate Venting Correction Alternate Venting Correction Formulas (Section 7.7.2)

Drywell Correction Equation

[1 0

+

7 14

(( (P

)jX(TAl +460 )11lix

/\..X\. 159000 DryweH Temperature Correction

{

=

((14.7

+ ( P, (Ta, + 460 )jj where: 81 P = Drywell pressure before venting taken from DRYWELL PRESSURE indicator 3-Pl-64-135 92 P = Drywell pressure before venting taken from DRYWELL PRESSURE indicator 3-Pl-64-1 36 PAl = Drywefl pressure after venting taken from DRYWELL PRESSURE indicator 3-PI-64-1 35 P = Drywell pressure after venting taken from DRYWELL PRESSURE indicator 3-PI-64-1 36

+460 6

T 1 = Drywell temperature before venting taken from DRYWELL TEMPERATURE indicator 3-TI-64-52AB and corrected to absolute temperature (Rankine)

+460 4

T 1 = Drywell temperature after venting taken from DRYWELL TEMPERATURE indicator 3-Tl-64-52AB and corrected to absolute temperature (Rankine) uppression Chamber Correction Equation r 81

÷ 7

14 FF

+P: (P (Pfl3+PB4)1x(T+

2

)ll 460 2

jjx[I262oo_[(LA÷l)x9o9.8=

Suppression Chamber N Temperature Correction

[ ((14.7+( AIA2 2

46 l

4 (T+

(PA3+PA o) 2 where: P 8 1 = Drywell pressure before venting taken from DRYWELL PRESSURE indicator 3..PI-64-135 92 P = Drywell pressure before venting taken from DRYWELL PRESSURE indicator 3-Pl-64-136 P = Drywell!Suppression Chamber differential pressure before venting taken from DWISUPPR CHBR DIFF PRESS indicator 3-PDI-64-137

= DrywelllSuppression Chamber differential pressure before venting taken from DWISUPPR CHBR DIFF PRESS indicator 3-PDI-64-138 TB2 + 460 = Suppression Chamber temperature before venting taken from SUPPRESSION CHAMBER TEMPERATUREIPRESSURE recorder, (3-XR-64-52 Point 1) and corrected to absolute temperature (Rankine)

T + 460 = Suppression Chamber temperature after venting taken from SUPPRESSION CHAMBER TEMPERATUREIPRESSURE recorder, 3-XR-64-52 (Point 1) and corrected to absolute temperature (Rankine)

PAl = Drywell pressure after venting taken from DRYWELL PRESSURE indicator 3-PI-64-135 P = Drywell pressure after venting taken from DRYWELL PRESSURE indicator 3-Pl-64-136 P = Drywell!Suppression Chamber differential pressure after venting taken from DWISUPPR CHBR DIFF PRESS indicator 3-PDI-64-137 PM = DrywelllSuppression Chamber differential pressure after venting taken from DW/SUPPR CHBR 01FF PRESS indicator 3-PDI-64-138 LA = Suppression Chamber water level taken from SUPPR POOL WATER LEVEL indicator 3-Ll-64-54A or 66.

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 36 of 37 Attachment 7 (Page 1 of 2)

Average Nitrogen Consumption and Leakage Date:

Net Nitrogen Leakage (Section 7.8)

1. SUM all Gas additions to obtain the Total Addition:

Gas Addition to the Drywell Total Drywell Control Air Leakage Attachment 2, Section A Cumulative_Nitrogen_Makeup 3 Attachment_4,_Section_A

+_________

_ ft Total Gas Addition = 3 ft

2. Air Temperature Correction

. Air Temperature Total DW and SC Temperature Correction 3 Attachment 3, Section A ft

3. SUM all the Correction Factors to obtain a Total Correction Factor:

Correction Factor Total Supp Chamber Level Correction Attachment 1, Section B Total Venting Correction using 3-FIC 84-20 Attachment 5, Section A Total Alternate Venting Correction + 3 Attachment 6, Section B ft Total Correction Factor =

4. CALCULATE Net Nitrogen leakage:

Total Gas Addition Total DW and SC Tempe Correction Total Correction Factor Nitrogen Leakage Total Gas Addition (Step I above)

Total DW and SC Temperature Correction - 2 above)

Total Correction Factor - ft

(

3 Step 3 above)

Net Nitrogen Leakage = 3 ft

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 37 of 37 Attachment 7 (Page 2 of 2)

Average Nitrogen Consumption and Leakage Date: 7a)LI (

NOTES

1) For calculation purposes, a day consist of 24-hours. During the days when the time changes to Daylight Savings Time (DST) 23-hours will be used. When returning to Central Standard Time (CST) 25-hours will be used.

2) The average nitrogen leakage (adjusted) must be <542 SCFH (Step 6.OA.1). Notify the Unit Supervisor (US) if the nitrogen leakage exceeds 542 SCFH (Refer to 3-AOl-64-7 and Tech Specs 3.6.1.1.).

B. Average Nitrogen Leakage (Section 7.8.2)

CALCULATE the Average Nitrogen Leakage

Net nitrogen leakagexl.136 Avg. Nitrogen Leakage = =

Hours during the day Avg. Nitrogen Leakage = ( ft)x1.136 Hours)

Avg. Nitrogen Leakage SCFH (Ac)

Uo IV

ANAL Admiri SRO A2 PAGE 1 OF 8 OPERATOR:

RO SRO DATE:

JPM NUMBER: SRO A2 TASK NUMBER: Equipment Control TASK TITLE: 3-SI-4.7.A.2.A Primary Containment Nitrogen Consumption and Leakage K/A NUMBER: 2.2.12 K/A RATING: RO 3.7 SRO 4.1 PRA:

TASK STANDARD: Perform section 7.8 of 3-SI-4.7.A.2.A and determine Average Nitrogen Leakage does not meet Acceptance Criteria. Determine proper Technical Specification entry requirements.

LOCATION OF PERFORMANCE: Classroom REFERENCES/PROCEDURES NEEDED: 3 -SI-4.7.A.2.A VALIDATION TIME: 20 minutes MAX. TIME ALLOWED:

PERFORMANCE TIME:

COMMENTS:______________________________

Additional comment sheets attached? YES NO RESULTS: SATISFACTORY___ UNSATISFACTORY SIGNATURE: DATE:

EXAMINER

INITIAL CONDITIONS: You are the Unit Supervisor (US). The time is 2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months . The plant is in Mode 1. 3-SI-4.7.A.2.A, Primary Containment Consumption and Leakage, and has been completed thru section 7.7.

INITIATING CUE: The Shift Manager (SM) directs you to complete 3-SI-4.7.A.2.A, Primary Containment Consumption and Leakage, and determine any required actions.

Admin RO Aib PAGE 3 OF 8 Class Room INITIAL CONDITIONS: You are the Unit Supervisor (US). The time is 2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months . The plant is in Mode 1. 3-SI-4.7.A.2.A, Primary Containment Consumption and Leakage, and has been completed thru section 7.7.

INITIATING CUE: The Shift Manager (SM) directs you to complete 3-SI-4.7.A.2.A, Primary Containment Consumption and Leakage, and determine any required actions.

Adinin RO Aib PAGE 4 OF 8 START TIME____

Performance Step 1: Critical Not Critical X 7.8 Average Nitrogen Consumption and Leakage 7.8.1 Attachment 7 Section A Net Nitrogen Leakage

[1] Total Drywell Control Leakage, RECORD the Total Drywell Control Air Leakage from Attachment 2 in the Gas Addition to the Drywell table.

Standard:

3 for Total Drywell Control Air Leakage on Refers to Attachment 2 and records 1017.40 ft Attachment 7 SAT_ UNSAT N/A COMMENTS:________________________________

Performance Step 2: Critical Not Critical X

[2] Cumulative Nitrogen Makeup, RECORD the total cumulative nitrogen makeup from Attachment 4 Section A in the Gas Addition to the Drywell table.

Standard:

Refers to Attachment 4 and records 9912 & for cumulative nitrogen makeup on attachment 7 SAT_ UNSAT N/A COMMENTS:______________________

Admin RO Aib PAGE 5 OF 8 Performance Step 3: Critical X Not Critical

[3] CALCULATE the Total Gas Addition as follows:

ADD all the Gas addition types together from the Gas Addition Table and RECORD the sum as the Total Gas Addition in the Gas Addition to the Drywell table.

Standard:

Adds the Total Drywell Control Air Leakage and the Cumulative Nitrogen Makeup and determines the Total Gas Addition is 10929.40 ft 3

SAT UNSAT_ N/A COMMENTS:_________________________________

Performance Step 4: Critical Not Critical

[4] Total Drywell and Suppression Chamber Temperature Correction, RECORD the TOTAL VENTING CORRECTION from Attachment 3, Section A in the Correction Factor table.

Standard:

Refers to Attachment 3 and records 0 & for Total DW and SC Temperature Correction on Attachment 7 SAT UNSAT N/A COMMENTS:

Performance Step 5: Critical Not Critical X

[5] Total Suppression Chamber Level Correction, RECORD the total Suppression Chamber level correction from Attachment 1, Section A in the Correction Factor table.

Standard:

Refers to Attachment 1 and records (-)682.35 & for Total DW and SC Temperature Correction on Attachment 7 SAT_ UNSAT N/A_COMMENTS:

Admin RD Aib PAGE 6 OF 8 Performance Step 6: Critical Not Critical X

[6] Total Venting Correction using 3-FIC 84-20, RECORD the total Drywell Venting Correction from Attachment 5, Section A in the Correction Factor table.

Standard:

3 for Total Venting Correction using 3-FIC 84-20 on Refers to Attachment 5 and records 0 ft Attachment 7 due to no venting performed during previous 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SAT_ UNSAT N/A COMMENTS:________________________________

Performance Step 7: Critical Not Critical X

[7] Total Alternate Venting Correction, RECORD the total Drywell Venting Correction from Attachment 6, Section B in the Correction Factor table.

Standard:

Refers to Attachment 6 and records 0 & for Total Alternate Venting Correction on Attachment 7 due to no venting performed during previous 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SAT_ UNSAT N/A COMMENTS:________________________________

Performance Step 8: Critical Not Critical

[81 CALCULATE the Total Correction Factor as follows:

ADD all the Correction Factor Types together from the Correction Factor Table and RECORD the sum as the Total Correction Factor in the Correction Factor table.

Standard:

Adds the Total Suppression Chamber Level Correction, the Total Venting Correction using 3-FIC 84-20, and the Total Alternate Venting Correction together and determines the Total Correction Factor is (-)682.35 &

SAT_ UNSAT N/A COMMENTS:________________________________

Admin RO Aib PAGE 7 OF 8 Performance Step 9: Critical Not Critical

[9] CALCULATE the Net Nitrogen Leakage as follows:

Total Gas Addition for the Net Nitrogen Leakage and SUBTRACT the Air Temperature calculation and SUBTRACT the Total Correction Factor.

Standard:

Subtracts the Total DW and SC Temperature Correction and the Total Correction Factor from the Total Gas Addition and determines a Net Nitrogen Leakage of 11611 +/-1.0 ft 3 10929.40 ft3 0 ft 3 (-)682.35 ft 3 = 11611 +/- 1.0 ft 3

SAT_ UNSAT N/A COMMENTS:_________________________________

Performance Step 10: Critical Not Critical 7.8.2 Attachment 7 Section B Average Nitrogen Leakage Cue: There is an identified Procedure Error, Section 7.8.2 11] should read: MULTIPLY the net nitrogen leakage from Attachment 7, Section A, (Nitrogen Leakage table), by (1.136/hours during the day).

[1] MULTIPLY the net nitrogen leakage from Attachment 6 (should read Attachment 7), Section A, (Nitrogen Leakage table), by (1.136/Hours during the day).

[2] RECORD the result on the Average Nitrogen Leakage line.

Standard:

Multiplies Net Nitrogen Leakage of 11611 +/-1.0 ft 3 (obtained from Attachment 7, Section A) by 1.136 and divides by 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to determine an Average Nitrogen Leakage of 549.62 +/- 2.0 SCFH.

Determines that the Average Nitrogen Leakage is greater than 542 SCFH (AC) and does not initial for the Acceptance Criteria. Checks No on the Surveillance Task Sheet (STS) for Were all Tech Spec/Tech Req/ISFSIJCoC/ODCM]Fire Prot reqt AMSAC* acceptance criteria satisfied.

SAT_ UNSAT_ N/A COMMENTS:

Admin RO Aib PAGE 8 OF 8 Performance Step 11: Critical X Not Critical 3-AOI-64-7, N 2 Usage High 4.2 Subsequent Actions (Continued)

[8] IF 24-Hour average N2 makeup to the primary containment is> 542 scth, THEN

[8.1] DECLARE Primary Containment 1NOP immediately.

[8.2] RESTORE Primary Containment to Operable within ONE HOUR. REFER TO LCO 3.6.1.1.

[9] IF it is discovered that Primary Containment Integrity does NOT exist during the evaluation, THEN RESTORE Primary Containment to Operable within ONE HOUR, OR BEGIN actions to place the unit in Mode 3 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and Mode 4 in 36 Hours.

REFER TO LCO 3.6.1.1.

rimery coiteirment 3,6,1.1 3.6 (3liTI F.! lvi B JT VTBFv1 3.6.1 .1 rimery ,riteirimerit Lc 36.1i Rrimery o teirmert shlI be L_I..BIL..rTy: 1i1B 1 2, eril 3.

I N ccMI rTIN 5 Li I BID .A.CrIC) N CC)l\,1 FLBTIC) l4 1 I Fyi B Ps.. Frrriery ooriteirmerit A.. I Feetc,re rirnery 1 hzi..ir iroIerbIe - OOr)tai nrnent to EFt.A.B LB stetLie.

8. eijired otior, erid 5.1 Be in F.lC)LDB 3. 12 hoL.irs essocieted ompletiori Time ricit met. AJ.J 5.2 Se in Fv1DB 4. 36 hoLirs Standard:

Declares Primary Containment Inoperable Immediately and determines Primary Containment must be restored within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OR be in Mode 3 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and Mode 4 in 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SAT UNSAT N/A COMMENTS:________________________________

END OF TASK STOP TIME

S 4 A **

1 Surveillance Task Sheet (SIS)

WO: 111807079 PM#: P3402 Procedure: 3-Sl-4.7.A.2.A

Title:

3-Sl-4.7.A.2.A PRIMARY CONTAINMENT NITROGEN CONSUMPTION AND LEAKAGE ,7ithorizatlon to ØiT(SRO 1 Dat & Time Data Sheets Attached:

Pert Grp: OPS Unit: 3 LooplDiv:

7i Start

/i,ooc e & Time D,re /-r1i Compietlo,( Date & Time Test Reason: Conditional Due Date:

Frequency: 1 Days Tech Spec: ASME XI:

Applicable Modes: Pert Modes: Mode I Clearance Required: EQ: LCO entered:

Dry Cask Storage: N Performed By:

Was this a Complete or Partial Performance?

Print Name /inature. Initial Section (Explain Partial In REMARKS below) Complete>( Partial

\

£/k-/?)

/ ;4/ Were all Tech SpeclTech ReqI1SFSIIC0CIODCMIFIre Prot reql AMSAC acceptance criteria satisfied? Yes [1 No N!A r I . Cr iicc 4

Were all other acceptance 4ep Criteria satisfied? Yes(] No(] NIA If all Tech SpeclTech ReqIISFSIIC0CIODCMIFIre Prot reqIAMSAC*

Criteria were not satisfied, was a LCO1ODCM actiop required?

(Explain In REMARKS below) Yes pi.1 No t 1 NIA Ei PWR only.

Subsequent RevIews:

Group: Signature Date Teat trector Leacerformer Date Acceptance Criteria Review: SRO Date & Time PERMANENT COMMENTS:

independent Reviewer Date & Time REMARKS: /it Nit 4 cr;k(1c.. v.ol

ci( dve -k 4vtt.

1

-\t M\ rf 44 &IálI.e1 9

t

,\/,,oc& 1Avr.1c cpecPLco . c I y3iu4 i c,id rdfrorC1 (W 9( kicc /,.ioP ;,eCJ;ScLL..

WA RESTRICTED INFORMATION Today, 2012

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 36 of 37 Attachment 7 (Page 1 of 2)

Average Nitrogen Consumption and Leakage Date:

ØNet Nitrogen Leakage (Section 7.8) all Gas additions to obtain the Total Addition:

Gas Addition to the Drywell Total Drywell Control Air Leakage 1Q/7 Lip 3 Attachment 2, Section A ft Cumulative Nitrogen Makeup + ( 3 Attachment 4, Section A ft Total Gas Addition = Jf2k 4/o ft 3

IZAir Temperature Correction Air Temperature Total DW and SC Temperature Correction 3 Attachment 3, Section A ft

,1SUM all the Correction Factors to obtain a Total Correction Factor:

Correction Factor Total Supp Chamber Level Correction , 4 3 Attachment 1, Section B ft Total Venting Correction using 3-FIC 84-20 175 3 Attachment 5, Section A ft Total Alternate Venting Correction + (Z 3 Attachment 6, Section B ft Total Corr9ction Factor = LC3 ft 3

,ALCULATE Net Nitrogen leakage:

Total Gas Addition Total DW and SC Tempe Correction

- Total Correction Factor Nitrogen Leakage Total Gas Addition (Step 1 above)

Total DW and SC Temperature Correction - Ø ft

(

3 Step 2 above)

Total Correction Factor - -i.36 ft (Step 3 above) 3 Net Nitrogen Leakage = I I(1 I 7ft

/

1I(L

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 37 of 37 Attachment 7 (Page 2 of 2)

Average Nitrogen Consumption and Leakage Date: 7&)zJ For calculation purposes, a day co-hours. During the days when the time changes to Daylight Savings Time (DST) 23-hours will be used. When returning to C ntral Standard Time (CST) 25-hours will be used.

2 The average nitrogen leakage (adjusted) must be <542 SCFH (Step 6.OA.1). Notify J the Unit Supervisor (US) if the nitrogen leakage exceeds 542 SCFH (Refer to 3-AOl-64-7 and Tech Specs 3.6.1.1.).

IAverage Nitrogen Leakage (Section 7.8.2)

CALCULATE the Average Nitrogen Leakage Net nitrogen leakagexl.136 Avg. Nitrogen Leakage = =

Hours during the day I)

Avg. Nitrogen Leakage

(, ftjxl.136

=

Avg. Nitrogen Leakage SCFH sc(

Uo lv

SurveHiance Task Sheet (STS)

W0 111807079 PMSt P3402 Procedure: 3-Sl-4.7.A.2.A The 3.Sl.47.A.2.A-PR1MARY CONTAINMENT NITROGEN CONSUMPTION AND 1.EAKAGE ftoilzctlonto BtrI:ERO/

7 Daté Time Data Sheets Attached:

PeslGrp OPS UnIt 3 LooplDlv: i4Af Start Date Completion Date & Time Test Reesom conditional Dac Date:

Fuency I Days Tech Spec: ASME XI:

Acc Modes; Pert Modes; Model Clearance Required: EQ: LO entered:

Dry Cask S orae: N Performed By Was this a Complete or Partial Performance?

(Explain Partial In REMARKS below) Complete 3 PartIal LI AMSAC acceptance criteria satisfied? Yes (3 No (3 WA (I Were all other acceptance CrftnrlasatIsfled? Yes(1 No(I NIAII Criteria were not satisfied, was a LCOIODCM action required?

(Explain In REMARKS below) Yes 3 No (I WA (3 w FWR only.

Subsequent Reviews:

Group:

Test Director Lead Performer Date Acceptance Criteria RevIow SRO Date & Time PERMANENT COMMENTS:

Independent Reviewer Date & Time REMARKS:

WA RESTRICTED INFORMATION Today, 2012

I Browns Ferry Nuclear Plant Unit 3 Surveillance Instruction 3-Sl-4.7.A.2.A Primary Containment Nitrogen Consumption and Leakage Revision 0024 Quality Related Level of Use: Continuous Use Level of Use or Other Information: Key Number P3402 Effective Date: 02-29-2012 Responsible Organization: OPS, Operations Prepared By: J D Savage Approved By: Jeffery D. Morrison

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 2 of 37 Current Revision Description Type of Change: Enhancements. Tracking Number: 028 PCRs: 11000391 PERs none Documentation None Minor changes to correct typos and align step with attachments. This PCR was written for UI but applies to U3 also.

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 3 of 37 Table of Contents

1.0 INTRODUCTION

5 1.1 Purpose 5 1.2 Scope 5 1.3 Frequency 5

2.0 REFERENCES

6 2.1 Technical Specifications 6 2.2 Technical Requirements Manual TRM - 6 2.3 Final Safety Analysis Report 6 2.4 Plant Instructions 6 2.5 Plant Drawings 7 2.6 Plant Generated Calculations 7 2.7 Miscellaneous 7 3.0 PRECAUTIONS AND LIMITATIONS 8 3.1 General Precautions 8 3.2 Operability and LCOs 8 3.3 Equipment 8 3.4 Initiation/Isolation/Trips 8 3.5 Interlocks 8 3.6 Performance Testing 9 4.0 PREREQUISITES 11 5.0 SPECIAL TOOLS AND EQUIPMENT RECOMMENDED 11 6.0 ACCEPTANCE CRITERIA 11 7.0 PROCEDURE STEPS 12 7.1 Initial Requirements And Notifications 12 7.2 Data Collection As Close To Midnight (0000 Hour) As Possible 13 7.3 Suppression Chamber Level 15 7.3.1 Attachment I Section A- Suppression Chamber Level Corrections Data 15 7.3.2 Attachment I Section B Total Suppression Chamber Level Correction 15 7.4 Calculating the Drywell Control Air leakage 16

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 4 of 37 Table of Contents (continued) 7.4.1 Attachment 2 Calculate the Drywell Control Air Line A leakage 16 7.4.2 Attachment 2 Calculate the Drywell Control Air Line B leakage 16 7.4.3 Calculate The Total Drywell Control Air Leakage 16 7.5 Air Temperature Correction 17 7.5.1 Attachment 3 Section A Drywell and Suppression Chamber Data 17 7.6 Nitrogen Makeup 18 7.6.1 Attachment 4 Section A Nitrogen Makeup Data

- - 18 7.7 Containment Venting 21 7.7.1 Attachment 5 Section A Containment Venting Data using 3-FIC-84-20 21 7.7.2 Attachment 6 Section A Alternate Containment Venting Data 22 7.7.3 Attachment 6 Section B Alternate Containment Venting Correction 23 7.8 Average Nitrogen Consumption And Leakage 24 7.8.1 Attachment 7 Section A Net Nitrogen Leakage

- - 24 7.8.2 Attachment 7 Section B Average Nitrogen Leakage

- - 25 7.9 Completion And Notifications 26 8.0 ILLUSTRATIONSIATTACHMENTS 26 : Suppression Chamber Level Correction 27 : Drywell Control Air Leakage Correction 28 : Containment Air Temperature Correction 29 Attachment 4: Nitrogen Makeup Correction 31 Attachment 5: Containment Venting Correction 32 Attachment 6: Alternate Venting Correction 33 Attachment 7: Average Nitrogen Consumption and Leakage 36

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 5 of 37

1.0 INTRODUCTION

1.1 Purpose This Surveillance Instruction provides the necessary steps to monitor the primary containment nitrogen consumption rate (i.e., primary containment system leakage) in compliance with the requirements in Technical Specification 3.6.1.1 and TRM 3.6.2, and 3.6.5.

1.2 Scope Primary containment nitrogen consumption is monitored to determine the average daily nitrogen consumption. Corrections are made for Suppression Chamber level changes and Drywell/Suppression Chamber venting that may occur. The average nitrogen leakage is calculated using data gathered during the day of this test.

For calculation purposes, a day consist of 24-hours. During the days when the time changes to Daylight Savings Time (DST) 23-hours will be used. When returning to Central Standard Time (CST) 25-hours will be used.

1.3 Frequency This Surveillance Instruction shall be performed each day (24-hour duration except the days converting to Daylight Saving Time and returning to Central Standard Time) and reviewed each shift while the reactor is in the RUN mode (Mode 1) and primary containment is inerted.

This procedure is initially started when the conditions are met during Reactor Startup and remains in process until the following Midnight (2400 Hours).

This procedure should be initiated at Midnight (0000 Hours) and remain in process for a 24 Hour period (until the following Midnight (2400 Hours)) or when conditions are no longer met during Reactor Shutdown per Tech Specs..

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 6 of 37

2.0 REFERENCES

2.1 Technical Specifications Section 3.6.1.1, Primary Containment 2.2 Technical Requirements Manual TRM -

Section 3.6.2, Oxygen Concentration Monitors Section 3.6.5, Nitrogen Makeup to Containment 2.3 Final Safety Analysis Report Section 5.2.2.8, Primary Containment-Safety Design Basis Section 5.2.3.8, Containment Inerting System Section 5.2.4.5, Primary Containment Leakage Analysis Section 5.2.5.1, Primary Containment Integrity and Leak-Tightness Table 5.2-1, Principal Design Parameters and Characteristics of Primary Containment 2.4 Plant Instructions 3-AOI-64-7, Primary Containment N 2 Usage High O-Ol-57C, 208/120V AC Electrical System Operating Instructions 3-01-64, Primary Containment System Operating Instructions 3-01-84, Containment Atmosphere Dilution System NPG-SPP-06.9.1, Conduct of Testing NPG-SPP-06.9.2, Surveillance Test Program

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 7 of 37 2.5 Plant Drawings I -47E61 0-76-I, Mechanical Control Diagram Containment Inerting System 3-47E61 0-64-1, 2, 3, Mechanical Control Diagram Primary Containment System 3-47E610-76-1, Mechanical Control Diagram Containment Inerting System I -47E860-1, Flow Diagram Containment Inerting System 3-47E860-1, Flow Diagram Containment lnerting System 2.6 Plant Generated Calculations PGC-003-064-0, Change in Torus Free Volume Per 1 of Water Level 2.7 Miscellaneous BFPER970886, Calculating Leakage when CAD is cross-tied to Drywell Control Air

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 8 of 37 3.0 PRECAUTIONS AND LIMITATIONS 3.1 General Precautions A. This procedure should be initiated at Midnight (0000 Hours) and remain in process for a 24 Hour period (until the following Midnight (2400 Hours)).

B. If it is necessary to begin a new revision to the procedure before the time period is completed, then the appropriate data must be transferred to the new document and the two procedures maintained together.

C. For an INDEPENDENT REVIEWER signature, the STA or SRO cannot perform any actions or signoffs in the body of the procedure. This will ensure an adequate review of the procedure.

3.2 Operability and LCOs A. If Nitrogen leakage exceeds 542 SCFH, 3-AOl-64-7 and TECH SPECS must be referred to for further action.

1. 2 makeup to the primary containment is > 542 scTh, If 24-Hour average N then Primary Containment must be declared INOP immediately.

(Refer to LCO 3.6.1.1.)

B. If the nitrogen consumption demonstrates a trend that will be greater than 542 SCFH for the 24-hour period, notify the Unit Supervisor (US) immediately.

3.3 Equipment A. When a Drywell Control Air Totalizer is mop, the DWCA System Engineer will use the AUD Rounds to determine the average flow to be used for N2 Drywell Control Air Flow.

B. When a Drywell Control Air Totalizer is INOP and a break or a leak occurs in the drywell from an air line, then the number of times the drywell is vented will rise based upon the severity of the leak or break. System Engineering should monitor and address any raise in Venting Requirements to determine if it is caused by a Drywell Control Air Line leak or due to atmospheric conditions.

3.4 lnitiationllsolationlTrips None 3.5 Interlocks None

BFN Primary Containment Nitrogen 3-St-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 9 of 37 3.6 Performance Testing A. Since changes in Suppression Chamber level change the Suppression Chamber free volume, the Torus atmospheric pressure will change, although nitrogen may not have been lost or added.

1. The Suppression Chamber level may change for any number of events such as venting the drywell/suppression chamber, pumping down the Suppression Chamber, MSRVs Leakage or testing Core Spray, RHR, HPCI, or RCIC Systems.

2. The correction for level changes is based on the assumption that the Suppression Chamber level change is relatively small (1to -7.25 indicated level) allowing the effect of Suppression Chamber curvature to be neglected. Therefore, the 909.8 cubic feet change in volume per one inch change in Suppression Chamber level is assumed constant.

B. Changes in either the Drywell or Suppression Chamber Air Temperature would cause a change in Containment Pressure under idea conditions. Due to the continuous Drywell Control Air addition and possible venting during the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period the changes in containment pressures may not be as expected.

Therefore when a change of more than 2 °F in either area occurs a Temperature Correction will be performed for that areas Air Temperature, otherwise zero 0 will be used for the correction factor.

C. For Sections 7.5and 7.7.2 if one pressure indicator and/or differential indicator is inoperable, (NA the appropriate column on the Attachment, note the mop indicator on Attachment 3 and 6, and delete dividing by 2 for that particular term in the equation.)

D. Attachment 3, Section B should be used to calculate the venting correction factor when any of the following instwmentation is unavailable.

1. Both DRYWELL PRESSURE, 3-Pl-64-1 35 and 3-Pl-64-1 36

2. DRYWELL TEMPERATURE, 3-Tl-64-52AB E. Attachment 4, Section B should be used to calculate the venting correction factor when any of the following instrumentation is unavailable.

1. Both DRYWELL PRESSURE, 3-Pl-64-135 and 3-Pl-64-136

2. Both DW/SUPPR CHBR DIFF PRESS, 3-PDI-64-137 and 3-PDI-64-138

3. DRYWELL TEMPERATURE, 3-Tl-64-52AB

4. SUPPR POOL WATER LEVEL, 3-Ll-64-54A and 3-Ll-64-66

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024

. PagelOof37 3.6 Performance Testing (continued)

F. Drywell/Suppression Chamber venting may be required to maintain Drywell pressure within limits during changes in barometric pressure, maintenance on Drywell Delta P Air Compressors, or other similar events. When using the Alternate Venting Correction equation in Attachment 6, the following assumptions are used.

1. The Drywell free volume is 159,000 cubic feet.

2. The Suppression Chamber free volume is 126,200 cubic feet at -1 inches (3-Ll-64-54A or 66, Suppr Pool Water Level), and an additional 909.8 cubic feet of free volume for each inch that water level is lowered.

3. The actual venting process is a rapid event so barometric pressure changes can be neglected.

4. The average Drywell temperature change is represented by DRYWELL TEMPERATURE indicator 3-Tl-64-52AB, and DRYWELL TEMPERATURE/PRESSURE recorder 3-XR-64-50.

5. Drywell and Suppression Chamber nitrogen pressures are low enough to use the ideal gas law as a model, i.e.

l[PBTA1Xv L A BJ Where: =

0 V Venting Correction

=

5 P Drywell or Suppression Chamber pressure before venting P Drywell or Suppression Chamber pressure after venting TB= Drywell or Suppression Chamber temperature before venting TA= Drywell or Suppression Chamber temperature after venting V= Total free volume of Drywell or Suppression Chamber

6. The Suppression Chamber water and atmospheric temperatures are in equilibrium.

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 11 of 37 Date:

PREREQUISITES VERIFY this instruction to be the most current revision.

OBTAIN a Surveillance Task Sheet (STS) for this procedure and Work Activity. (Key Number P3402)

VERIFY Cabinet 2, Panel 9-9 is energized in accordance with 0-Ol-57C, 208/1 20V AC Electrical System Operating Instruction.

SPECIAL TOOLS AND EQUIPMENT RECOMMENDED

,Calculator ACCEPTANCE CRITERIA

,Responses which fail to meet the following acceptance criteria constitute unsatisfactory surveillance instruction results and require the immediate notification of the Unit Supervisor at the time of failure:

0 Nitrogen makeup to the primary containment, averaged over 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (corrected for Suppression Chamber level changes and Drywell/Suppression Chamber venting) is less than 542 standard cubic feet per hour (SCFH).

Steps which determine the above criteria are designated by (AC) next to the

/ initials blank.

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 12 of 37 Date:

This procedure should be initiatedht which is represented as (0000 Hours) and remain in process for a 24 Hour period (until the following Midnight which is represented as (2400 Hours)). These times are used to represent the difference from the start and the completion of this SR and may not match the proper military times that is used by the electronic narrative logs.

If it is necessary to stop this procedure and recommence with a new revision before the time period is completed, the appropriate data must be transferred to the new document and the two procedures maintained together..

PROCEDURE STEPS Initial Requirements And Notifications VERIFY the Precautions and Limitations in Section 3.0 have been reviewed.

VERIFY the Prerequisites in Section 4.0 are satisfied.

On the Surveillance Task Sheet (STS)

OBTAIN Authorization Signature and Date/Time from the Unit Supervisor/SRO to perform this surveillance.

On the Surveillance Task Sheet (STS)

RECORD the Start Date & Time.

RECORD the date on each data sheet Attachments I i through 7.

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 13 of 37 Date:

This procedure should be initiated by the midnight shift Unit Supervisor or by the Unit Supervisor of any shift meeting the requirements of Section 1.3.

For the first run of the 24-hour period, the previous cumulative total is zero since totals are not carried over from the previous 24-hour test.

7 Data Collection As Close To Midnight (0000 Hour) As Possible RECORD on Attachment I Part A, the initial Suppression Pool

,X_. Level (0000 Hour), in column (I) for each of the following instruments (if available) on Panel 9-3.

SUPPR POOL WATER LEVEL, 3-LI-64-54A

SUPPR POOL WATER LEVEL, 3-Ll-64-66 Attachment 2 in the INITIAL column, the (RECORD on Drywell Control Air Loop A flow from the N2 Containment Inerting system, from one of the following:

DWCA FLOW ELEMENT HEADER A, 3-FIQ-032-0092 (Rx Bldg El 565 R16 S Line).

OR

Average flow as determined by the DWCA System Engineer if 3-FIQ-032-0092 is INOP.

(Reference Step 3.3A)

RECORD on Attachment 2 in the INITIAL column, the X._- Drywell Control Air Loop B flow from the N2 Containment Inerting system, from one of the following:

DWCA FLOW ELEMENT HEADER B, 3-FIQ-032-0075 (Rx Bldg El 565 R20 Q Line).

OR

Average flow as determined by the DWCA System Engineer if 3-FIQ-032-0075 is INOP.

(Reference Step 3.3A)

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 14 of 37 Data Collection As Close To Midnight (0000 Hour) As Pos:ible (continued)

RECORD on Attachment 3 in the 0000 Hours the following data.

Drywell Pressure 3-P 1-64-135

Drywell Pressure 3-Pl-64-136

Drywell Temperature 3-TI-64-52AB

Drywell Differential Pressure 3-DPI-64-1 37

Drywell Differential Pressure 3-DPI-64-1 38

SUPP CHBR TEMP, 3-TE-64-52B on SUPPRESSION CHAMBER TEMPERATURE/PRESSURE, 3-XR-64-52 (point 1)

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 15 of 37 The correction for level changes is based on the assumption that the Suppression Chamber level change is relatively small (-1 to -7.25 indicated level) allowing the effect of Suppression Chamber curvature to be neglected. Therefore, the 909.8 cubic feet change in volume per one inch change in Suppression Chamber level is assumed constant.

Suppression Chamber Level Attachment I - Section A- Suppression Chamber Level Corrections Data At the beginning of the surveillance (0000 hours0 days 0 hours 0 weeks 0 months ), RECORD the Suppr Pool

/ Water Level from indicators 3-Ll-64-54A and 3-Ll-64-66 on Panel 9-3, in column (1) for each available instrument.

At the end of the surveillance (2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months ), RECORD the Suppression A Chamber level from indicators 3-Ll-64-54A and 3-Ll-64-66 on Panel 9-3, in column (2), for each available instrument.

IF both instruments are available, 3-Ll-64-54A and 3-Ll-64-66, THEN SUBTRACT column (2) from column (1) to determine the amount of change in Suppression Chamber level and RECORD in column (3) (negative numbers are possible).

For each instrument 3-Ll-64-54A and 3-Ll-64-66, CALCULATE the change in

)C_

Suppression Chamber free volume as standard cubic feet (SCF) by

/in.) and RECORD in multiplying column (3) by column (4) (909.8 ft 3

column (5).

.2 Attachment I - Section B - Total Suppression Chamber Level Correction

IF both (64-54A & 64-66) instrument are available, THEN ADD column (5) for each instrument and DIVIDE by two (for calculating the average) and RECORD results as the Total Suppression Chamber Level Correction blank.

IF an instrument is unavailable, THEN USE only the operable instrument and ENTER the column (5) value for the operable instrument as Total Suppression Chamber Level Correction blank.

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 16 of 37 Calculating the Drywell Control Air leakage Attachment 2 - Calculate the Drywell Control Air Line A leakage At the beginning of the surveillance (0000 hours0 days 0 hours 0 weeks 0 months ), RECORD the DWCA FLOW ELEMENT HEADER A, 3-FIQ-032-0092 in the column (2) INITIAL (0000 hours0 days 0 hours 0 weeks 0 months ).

At the end of the surveillance (2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months ), RECORD the DWCA FLOW ELEMENT HEADER A, 3-FIQ-032-0092 in the Column (1) ENDING (2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months )

CALCULATE the daily difference for Drywell Control Air Loop A, 3-FIQ-032-0092.

Column (1) Column (2)

- = Difference (Column 3)

J5Attachment 2 - Calculate the Drywell Control Air Line B leakage At the beginning of the surveillance (0000 hours0 days 0 hours 0 weeks 0 months ), RECORD the DWCA FLOW ELEMENT HEADER B, 3-FIQ-032-0075 in the column (2) INITIAL (0000 hours0 days 0 hours 0 weeks 0 months ).

At the end of the surveillance (2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months ), RECORD the DWCA FLOW

) ELEMENT HEADER B, 3-FIQ-032-0075 in the Column (1) UENDING (2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months )

,(CALCULATE the daily difference for Drywell Control Air Loop A, 3-FIQ-032-0075.

Column (1) Column (2)

- = Difference (Column 3)

C 1 aIculate The Total Drywell Control Air Leakage

. SUM the Drywell Control Air Loop A, 3-FIQ-032-0092 Difference and Drywell Control Air Loop B, 3-FIQ-032-0075 Difference.

3-FIQ-032-0092 (Difference) + 3-FIQ-032-0075 (Difference) = Total

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 17 of 37 Date: DcYL.f 1

/

Air Temperature Correction 3- Section A - Drywell and Suppression Chamber Data JAftachment

,/JAt the beginning of the surveillance (0000 hours0 days 0 hours 0 weeks 0 months ), RECORD on

) Attachment 3 in the 0000 Hours the following data.

DRYWELL PRESSURE 3-Pl-64-1 35

DRYWELL PRESSURE 3-Pl-64-136

DRYWELL TEMPERATURE 3-Tl-64-52AB

DWISUPPR CHBR DIFF PRESS 3-DPI-64-137

DW/SUPPR CHBR DIFF PRESS 3-DPI-64-138

SUPP CHBR TEMP, 3-TE-64-52B on SUPPRESSION CHAMBER TEMPERATURE/PRESSURE, 3-XR-64-52 (point 1)

At the end of the surveillance (2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months ), RECORD on 7 Attachment 3 in the 2400 Hours the following data.

DRYWELL PRESSURE 3-Pl-64-135

DRYWELL PRESSURE 3-Pl-64-136

DRYWELL TEMPERATURE 3-Tl-64-52AB

DW/SUPPR CHBR DIFF PRESS 3-DPI-64-137

DW/SUPPR CHBR 01FF PRESS 3-DPI-64-138

SUPP CHBR TEMP, 3-TE-64-52B on SUPPRESSION CHAMBER TEMPERATURE/PRESSURE, 3-XR-64-52 (point 1)

Suppression Pool Level 3-Ll-64-54A or 3-Ll-64-66 IF the Drywell Temperature has changed by 2°F or more, THEN PERFORM the calculation using Section B for Drywell and enter the result in column (8) of Section A. (Otherwise enter 0 (Zero) for the calculation.)

(1P(

X THEN IF the Suppression Chamber Air Temperature has changed by 2°F or more, PERFORM the calculation using Section C for Suppression Chamber and enter the result in column (9) of Section A. (Otherwise enter 0 (Zero) for the calculation.)

Calculate the Total Correction Factor as follows SUM the Drywell (Column 8) and Suppression Chamber (Column 9) and entering the results in Column (10).

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 18 of 37 y

Stopwatch may be used to perform Section 7.6.1.

Nitrogen flow should be less than 60 SCFM in accordance with 3-01-64, Primary

/ Containment when performing Section 7.6.1.

Nitrogen Makeup Attachment 4- Section A Nitrogen Makeup Data IF Makeup is from the Nitrogen Storage Tank, THEN.

PERFORM the following during Nitrogen additions:

In EVENT Column, RECORD N2 Tank.

JI

- In column (1), RECORD the time each nitrogen addition begins.

In column (2), RECORD the nitrogen makeup duration, in minutes, from the chart of DW/SUPPR CHBR N2 MAKEUP FLOW/PRESS recorder, 3-XR-076-0014 on Panel 9-3 or from stopwatch.

In column (3), RECORD the nitrogen makeup flow in cubic feet per

-K.- minute as indicated by the Red Pen on DW/SUPPR CHBR N2 MAKEUP FLOW/PRESS, 3-XR-076-0014 on Panel 9-3.

CALCULATE the amount of nitrogen, in cubic feet (ft ), added during 3

the run by multiplying column (2) by column (3) and RECORD in column (4).

CALCULATE the total cumulative nitrogen use in cubic feet for the 24-hour period of this test by adding the latest entry in column (4) to the previous cumulative total in column (5) and RECORD the new cumulative total in column (5).

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 19 of37 Attachment 4- Section A Nitrogen Makeup Data (continued)

[OCICI IF CAD is cross-tied to DryweN Control Air, THEN PERFORM the following: (REFER TO 3-01-84) [BFPER950935]

[2.1] In EVENT Column, RECORD CAD/DCA.

J [2.2] In Column (1), RECORD the time CAD was cross-tied to Drywell Control Air on the CAD/DCA line provide.

[2.3] In Column (2), RECORD the duration in minutes that CAD was cross-tied to Drywell control air.

[2.4] OBTAIN calculated Total Leakage(CFM) from Site Engineering.

[2.51 In Column (3), RECORD the calculated Total Leakage(CFM) obtained from Site Engineering.

[2.6] CALCULATE the amount of nitrogen added during the period by multiplying columns (2) and (3) and RECORD in column (4).

[2.7] CALCULATE the total cumulative nitrogen use in cubic feet for the 24-hour period of this test by adding the latest entry in column (4) to the previous cumulative total in column (5) and RECORD the new cumulative total in column (5).

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 20 of 37 Attachment 4 Section A Nitrogen Makeup Data (continued)

Measure the CAD addition using a stop watch.

P1Use a separate Event Column for each CAD TRAIN if both trains are being used at the same time.

IF CAD is aligned to Containment other than Section 7.6.1[2], THEN PERFORM the following for any CAD additions.

[3.1] In EVENT Column, RECORD CAD/CONT

[3.2] In column (1), RECORD the time each CAD addition begins.

[3.3] In column (2), RECORD the CAD addition duration, in minutes from the stopwatch.

[3.4] In column (3), RECORD the CAD makeup flow in cubic feet per minute for each CAD train being used:

CAD A N2 SYSTEM FLOW

O-Fl-84-7/3, CAD A N2 SYSTEM FLOW, on 3-PNL-9-54.

OR

O-FI-84-7, CAD LINE A N2 FLOW, on (Unit 1) PNL-9-54 CAD B N2 SYSTEM FLOW

O-Fl-84-1 8/3, CAD B N2 SYSTEM FLOW, on 3-PNL-9-55.

OR

O-Fl-84-18, CAD B N2 SYSTEM FLOW, on (Unit 1) PNL-9-55.

[3.5] CALCULATE the amount of nitrogen, in cubic feet (ft ), added during 3

the run by multiplying column (2) by column (3) and RECORD in column (4).

[3.6] CALCULATE the total cumulative nitrogen use in cubic feet for the 24-hour period of this test by adding the latest entry in column (4) to the previous cumulative total in column (5) and RECORD the new cumulative total in column (5).

BFN Primary Containment Nitrogen 3-S1-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 21 of 37 Containment Venting Attachment 5 Section A Containment Venting Data using 5

3-FIC-84-20

/J/.\ [1] In column (1), -

RECORD the time the venting begins.

[2] In column (4), -

RECORD the vent flow rate indicated on PATH A VENT FLOW CONT, 3-FIC-84-20.

[3] In column (2), -

RECORD the time the venting ends.

[4] In column (3), -

RECORD the elapsed venting time in minutes by subtracting column (1) from column (2).

[5] In column (5), -

RECORD the Suppression Chamber Venting Correction Factor by multiplying column (3) by column (4).

[6] In column (6), Total Cumulative Correction -

RECORD the SUM of the previous event column (6) and the current event column (5).

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 22 of 37 Alternate Containment Venting Data is performed when 3-FIC-84-20 indication is not available.

,Yttachment 6 Section A Alternate Containment Venting Data

[1] PRIOR to Venting IA PERFORM the following using instruments on Panel 9-3:

A. In column (1),

RECORD the time the venting begins.

B. In column (2), block PB1, RECORD the DRYWELL PRESSURE, 3-PI-64-135 indication.

C. In column (3), block PB2, RECORD the DRYWELL PRESSURE, 3-PI-64-136 indication.

D. In column (4), block TBI, RECORD the DRYWELL TEMPERATURE, 3-TI-64-52AB.

E. In column (5), block ,

83 P

RECORD the DWISUPPR CHBR DIFF PRESS, 3-DPI-64-137 indication F. In column (6), block PB4, RECORD the DW/SUPPR CHBR DIFF PRESS, 3-DPI-64-138, indication G. In column (7), block TB2, RECORD the SUPP CHBR TEMP, 3-TE-64-52B on SUPPRESSION CHAMBER TEMPERATURE/PRESSURE, 3-XR-64-52 (point 1)

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 23 of 37 j

A 1 ttachment 6 Section A Alternate Containment Venting Data (continued)

[2] AFTER the Venting Event is completed, A. In column (2), block PM, RECORD the DRYWELL PRESSURE, 3-Pl-64-1 35 indication.

B. In column (3), block - RECORD the DRYWELL PRESSURE, 3-P 1-64-136 indication.

C. In column (4), block TA1, RECORD the DRYWELL TEMPERATURE 3-Tl-64-52AB.

D. In column (5), block PA3, RECORD the DW/SUPPR CHBR DIFF PRESS, 3-DPI-64-137 indication E. In column (6), block PA4, RECORD the DW/SUPPR CHBR DIFF PRESS, 3-DPI-64-138, indication F. In column (7), block Tp., SUPP CHBR TEMP, 3-TE-64-52B on SUPPRESSION CHAMBER TEMPERATURE/PRESSURE, 3-XR-64-52 (point 1)

C. In column (8), RECORD the SUPPR POOL WATER LEVEL, 3-LI-64-54A. (Use 3-Ll-64-66 if 3-LI-64-54A is INOP.)

H. In column (9), CALCULATE the DRYWELL VENTING CORRECTION using the Drywell Venting Correction Formula in Section C.

I. In column (10), CALCULATE the SUPPRESSION CHAMBER VENTING CORRECTION using the Suppression Chamber Venting Correction Formula in Section C.

J. In column (11), RECORD the sum the DRYWELL VENTING CORRECTION Column (9) and SUPPRESSION CHAMBER VENTING CORRECTION Column (10).

Attachment 6 Section B Alternate Containment Venting Correction jJ [1] At the completion of the 24-hour period

In column (12) RECORD the Total Venting Correction, Attachment 6, Section B by ADDING all the TOTAL VENTING CORRECTION from Section A, Column (11).

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 24 of 37 Average Nitrogen Consumption And Leakage 7.8.1 Attachment 7 Section A Net Nitrogen Leakage

[1] Total Drywell Control Leakage, RECORD the Total Drywell Control Air Leakage from Attachment 2 in the Gas Addition to the Drywell table.

[2] Cumulative Nitrogen Makeup, RECORD the total cumulative nitrogen makeup from Attachment 4 Section A in the Gas Addition to the Drywell table.

[3] CALCULATE the Total Gas Addition as follows:

ADD all the Gas addition types together from the Gas Addition Table and RECORD the sum as the Total Gas Addition in the Gas Addition to the Drywell table.

[4] Total Drywell and Suppression Chamber Temperature Correction, RECORD the TOTAL VENTING CORRECTION from Attachment 3, Section A in the Correction Factor table.

[5] Total Suppression Chamber Level Correction, RECORD the total Suppression Chamber level correction from Attachment 1, Section A in the Correction Factor table.

[6] Total Venting Correction using 3-FIC 84-20, RECORD the total Drywell Venting Correction from Attachment 5, Section A in the Correction Factor table

[7] Total Alternate Venting Correction, RECORD the total Drywell Venting Correction from Attachment 6, Section B in the Correction Factor table.

[8] CALCULATE the Total Correction Factor as follows:

ADD all the Correction Factor Types together from the Correction Factor Table and RECORD the sum as the Total Correction Factor in the Correction Factor table.

19] CALCULATE the Net Nitrogen Leakage as follows.

Total Gas Addition for the Net Nitrogen Leakage and SUBTRACT the Air Temperature calculation and SUBTRACT the Total Correction Factor.

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 25 of 37 7.8.2 Attachment 7 Section B Average Nitrogen Leakage NOTE Leakage rates, for comparison purposes, should always be converted to standard flow rate conditions (flow at 70°F, one standard atmosphere). Since nitrogen gas is supplied by evaporating liquid nitrogen and heating it to approximately 70°F then reducing the pressure to 2.0 psig the conversion is:

14.7psia + 2.Opsig 460°R + 70°F

< = 1136 14.7psia 460°R+70°F Where: 14.7 psia = I standard atmosphere 2.0 psig = nitrogen supply pressure 460°R = Fahrenheit to Rankine conversion factor 70°F = degrees Fahrenheit of nitrogen, actual and standard For calculation purposes, a day consist of 24-hours. During the days when the time changes to Daylight Savings Time (DST) 23-hours will be used. When returning to Central Standard Time (CST) 25-hours will be used.

To average the net nitrogen usage (in ft ) for a day, a 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period is normally used and 3

the result are expressed in standard cubic feet per hour. The net nitrogen leakage is multiplied by a conversion factor 1.136, then divided by the number of hours in the day.

The result gives the average nitrogen leakage in standard cubic feet per hour for that day.

When Daylight Savings Time and Central Standard Time changes take place, the appropriate number of hours will be used instead of 24 (hours).

[11 MULTIPLY the net nitrogen leakage from Attachment 6, Section A, (Nitrogen Leakage table), by (1.136/Hours during the day).

[2] RECORD the result on the Average Nitrogen Leakage line.

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 26 of 37 Date: 7O4(

7.9 Completion And Notifications

[1] On the Surveillance Task Sheet (STS),

[1.1) RECORD the Completion Date & Time.

[1.2) REVIEW and COMPLETE the Surveillance Task Sheet (STS) through the Test Director/Lead Performer & Date fields.

[2] NOTIFY the Unit Supervisor that this Surveillance Instruction is complete.

8.0 ILLUSTRATIONSIATTACHMENTS Attachment 1: Suppression Chamber Water Level Correction Attachment 2: Drywell Control Air Leakage Correction Attachment 3: Containment Air Temperature Correction Attachment 4: Nitrogen Makeup Correction Attachment 5: Containment Venting Corrections Attachment 6: Alternate Venting Correction Attachment 7: Average Nitrogen Consumption and Leakage

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 27 of 37 Attachment I (Page 1 off)

Suppression Chamber Level Correction Date: 77nw SUPPRESSION CHAMBER LEVEL CORRECTION DATA If both Instruments are Operable, then calculate the average of BOTH Operable Instruments by Dividing the sum of their SUPPRESSION CHAMBER LEVEL CORRECTION (column 5) by 2 (two) and record as the TOTAL SUPPRESSION CHAMBER LEVEL CORRECTION.

one of the instruments is INOP, then use only the Operable Instrumentation Correction Factor for the TOTAL SUPPRESSION CHAMBER LEVEL CORRECTION.

,(Suppression Chamber Level Data (Section 7.3.1)

(1) (2) (3) (4) (5) initial Ending Suppr Chbr Suppr Chbr Suppr Chbr Change in Conversion Level Level (IN.) LEVEL (IN.) Suppr Chbr Factor Correction UO Instrument (0000 Hours) (2400 Hours) Level (IN.) /IN.

909.8 FT 3 )

3 (FT INIT 3-Ll-64-54A - 2.o = 1. ) x 909.8 = qt .

3-Ll-64-66 O. x909.8=

B. Total Suppression Chamber Level Correction Calculation (Section 7.3.2)

Column 5(ft) 3 + Column 5(ft

)

3 for 3-LI-64-54A for 3-LI-64-66

= Average Suppression Chamber Level 2

-k2 )

3 (ft

_4q,g(ft3) 3LI6454A3--L16466 _4a2ft) 2 uO

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 28 of 37 Attachment 2 (Page 1 of 1)

Drywell Control Air Leakage Correction Date: -Tf)1W

,Drywell Control Air Leakage (Section 7.4)

Drywell Control Air Line A FLOW DWCA FLOW ELEMENT HEADER A, 3-FIQ-032-0092 (Rx Bldg El 565 16 S Line)

(1) (2) (3)

ENDING INITIAL Difference (2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months ) (0000 hours0 days 0 hours 0 weeks 0 months ) cLIpI.7 - LIc,3g.7 43Ioo

)

3 (FT )

3 (FT Drywell Control Air Line B Flow DWCA FLOW ELEMENT HEADER B,3-FIQ-032-0075 (Rx Bldg El 565 R20 Q Line).

(1) (2) (3)

ENDING INITIAL Difference (2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months ) (0000 hours0 days 0 hours 0 weeks 0 months ) 1 L

3 3?

-7g4 J - =

)

3 (FT (FT) )

3 (FT Drywell Control Air Leakage 3-FIQ-032-0092 3-FIQ-032-0075 Difference Difference (Column 3) (Column 3) Total

+ =

)

3 (FT )

3 (FT uo

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 29 of 37 Attachment 3 (Page 1 of 2)

Containment Air Temperature Correction Date: Itfl,\Lf DelJ Temperature changed less than 2 °F, enter zero (0) in Column 8.

Suppression Chamber Air Temperature changed less than 2 °F, enter zero (0) in Column 9

,5DrywelI and Suppression Chamber Data DRYWELL Differential Suppression Chamber Pressure Temp Pressure Air Temp Level (1) (2) (3) (4) (5) (6) (7) 3-PI-64-1 35 3-Pl-64-1 36 3-Tl-64-52AB 3-PDI-64-1 37 3-PDI-64-1 38 3-XR-64-52 3-Ll-64--54A (psig) (psig) (°F) (psid) (psid) Point 1 (°F) or 66 0000 hours0 days 0 hours 0 weeks 0 months ISa TBI 83 L T 8 2 2400 hours0.0278 days 0.667 hours 0.00397 weeks 9.132e-4 months / / / Z 0 PAI / 37 1 T /

p T LA (8) (9) (10)

SUPRESSION DRYWELL VENTING CHMBR VENTING Total VENTING UO CORRECTION CORRECTION CORRECTION Initials 3

FT r3 ri +

9, 3 FT =

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 30 of 37 Attachment 3 (Page 2 of 2)

,1DrYweII Temperature Correction Equation (Section 7.7.3)

[14.7+()jx(TA:+46o )

g&) A r , Al +

x 159000 = Drywell Temperature Correction

[14.7+(

2 A2)jx(T+4643 )

where: PBI = Dryweti pressure before venting taken from DRYWELL PRESSURE indicator 3-PI-64-135 PB2 = Drywell pressure before venting taken from DRYWELL PRESSURE indicator 3-PI-64-136 PAl = Drywell pressure after venting taken from DRYWELL PRESSURE indicator 3-P 1-64-135 Dryweu pressure after venting taken from DRYWELL PRESSURE indicator 3-PI-64-1 36 5

T 1

+460 = Drywell temperature before venting taken from DRYWELL TEMPERATURE indicator 3-TI-64-52AB and corrected to absolute temperature (Rankine)

TA1+460 = Drywell temperature after venting taken from DRYWELL TEMPERATURE indicator 3-TI-64-52AB and corrected to absolute temperature (Rankine)

_Suppression Chamber Temperature Correction Equation Suppression Chamber Temperature Correction where: PB1 = DryweU pressure before venting taken from DRYWELL PRESSURE indicator 3-PI-64-1 35 PB2 = Drywell pressure before venting taken from DRYWELL PRESSURE indicator 3-Pl-64.136 3

PB = DrywelllSuppression Chamber differential pressure before venting taken from DWISUPPR CHBR DIFF PRESS indicator 3-PDI.64-137

= Drywell/Suppression Chamber differential pressure before venting taken from DWISUPPR CHBR DIFF PRESS indicator 3-PDI-64-138 T + 460 Suppression Chamber temperature before venting taken from SUPPRESSION CHAMBER TEMPERATURE/PRESSURE recorder, (3-XR-64-52 Point 1) and corrected to absolute temperature (Rankine)

+ 460 = Suppression Chamber temperature after venting taken from SUPPRESSION CHAMBER TEMPERATUREIPRESSURE recorder, 3-XR-64-52 (Point 1) and corrected to absolute temperature (Rankine)

PAl = Drywell pressure after venting taken from DRYWELL PRESSURE indicator 3-PI-64-135

= Drywall pressure after venting taken from DRYWELL PRESSURE indicator 3-Pl-64-136 P = Drywell!Suppression Chamber differential pressure after venting taken from DW/SUPPR CHBR DIFF PRESS indicator 3-PDI-64-137 PM = Drywell/Suppression Chamber differential pressure after venting taken from DW/SUPPR CHBR DIFF PRESS indicator 3-PDI-64-138 tf LA = Suppression Chamber water level taken from SUPPR POOL WATER LEVEL indicator 3-Ll-64-54A or 66.

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 31 of 37 Attachment 4 (Page 1 of 1)

Nitrogen Makeup Correction Date: -mnf Nitrogen Makeup Data (Section 7.6.1)

MAKEUP N ADDED 2 N MAKEUP (4) 2 DURATION N M

2 AKEP (2) X (3) + PREVIOUS (5)

TIME (MINUTES) FLOW (CFM) (FT 3) (FT3)

UO (1) (2) (3) (4) (5) Initials EVENT

1. Ic x =

x

2. f9 Olo =

AJ21 ifrS / x =

4. 1(1./p x =

142-71 1

5

- J,- flz-o = /-/16 21

6. -ik 17L7 x = /96Z 7

7.fj i4 x =_[66 8th.--

x = 17/j Remarks: /JoM

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 32 of 37 Attachment 5 (Page 1 of 1)

Containment Venting Correction Date: rThni A. Venting Data using 3-FIC 84-20, NOTE Enter data for each venting event: (ie. flow started and stopped through vent valves)

EVENT Calculations (1) (2) (3) (4) (5) (6)

ELAPSED Event Total VENT FLOW RATE Total Cumulative START END TIME 3-FIC-84-20 (SCF) Correction TIME (MIN) (SCFM) (Note 1) (Note 2) nitials TIME 3

6

//

/_______

Note 1 Column (3) x Column (4)

Note 2 Previous Event Column (6) + Current Event Column (5)

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 33 of 37 Attachment 6 (Page 1 of 3)

Alternate Venting Correction Date: 7r)y Alternate Containment Venting Data is performed when 3-FIC-84-20 indication is not available.

this table the BEFORE is prior to establishing flow through the vent valves.

before or after the DP Air Compressor The AFTER is when venting is completed, regardless of the number of times for the event, It can also be taken either

- pumps up the drywell, but do not take data while the DP is running.

3-Ll-64-54A unless INOP then use 3-Ll-64-66.

A. Alternate Venting Data (Section 7.7.2)

DRYWELL Differential Suppression Chamber Pressure Temp Pressure Air_. ._Lee1__

(2) (3) (4) (5) j_. (7) (8)

(1) 3-PI 135 3-Pl 136 3-Tl-64-52AB J4t37 3-PDI-64-1 38 3-XR-64-52 3-LI-64-54A (psig) (psig) (°F) (psid) (psid) Point 1 (°F) or66 EVENT TIME (BEFORE) PBI E32 3 Pu Ps Ti; N/A I 3 PA PM T LA (AFTER)

(BEFORE)

PM P,

[ T 0

T 3 P p T 8 2 N/A 2 TA, PA) PM TM LA (AFTER) i 0

P Pu2 T,, P 0 3 PM T 0 2 r/A PA, PA) TA, PA) PA) TA) LA (BEFORE) Pu, P 0 2 ,

0 T PM P, T 0 7 N/A PA) TA, PA) PA) TA) LA (AFTER) PM (BEFORE) P 8 1 P 0 2 ,

8 T PM 4 Pu 1 T N/A TA, PA) PM TA) LA (AFTER) PA,

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 34 of 37 Attachment 6 (Page 2 of 3)

Alternate Venting Correction Date: Thf)4 (9) (10) (11)

DRYWELL VENTING SUPRESSION CMBR TOTAL VENTING uO CORRECTION VENTING CORRECTION CORRECTION 1 + =

3 ft 2 + =

3 ft 3 +

3 ft 4 +

5 + 3 ft B. Total Alternate Venting Sum renting Corrections from Section A, Column 11 (12)

TOTAL VENTING uo CORRECTION Initial 3

FT

BFN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 35 of 37 Attachment 6 (Page 3 of 3)

Alternate Venting Correction

,Jternate Venting Correction Formulas (Section 7.7.2)

Drywell Correction Equation 1 1

+

7 14

(( (P i-PH,

)jx(TA÷46o )11Ix

,_X\. 159000 Drywell Temperature Correction I

=

where: 81 P = Drywefl pressure before venting taken from DRYWELL PRESSURE indicator 3-Pl-64-135

= Drywell pressure before venting taken from DRYWELL PRESSURE indicator 3-Pl-64-1 36 PAl = Drywell pressure after venting taken from DRYWELL PRESSURE indicator 3-Pl-64-1 35 PA2 = Drywell pressure after venting taken from DRYWELL PRESSURE indicator 3-Pl-64-1 36

+460 9

T 1 = Drywell temperature before venting taken from DRYWELL TEMPERATURE indicator 3-Tl-64-52AB and corrected to absolute temperature (Rankine)

TAI+460 = Drywell temperature after venting taken from DRYWELL TEMPERATURE indicator 3-TI-64-52AB and corrected to absolute temperature (Rankine)

,uppression Chamber Correction Equation r +(PBI 7

4 F[I 4

2

]x(T+o)ll

+PB2)(PDi+PB

)

Suppression Chamber

\

4 f\J (([l4.7

]PAl +PA4))(T 2

+PA

+460)))

Temperature Correction 2

where: 81 P = Drywell pressure before venting taken from DRYWELL PRESSURE indicator 3-PI-64-135 2

PB = Orywell pressure before venting taken from DRYWELL PRESSURE indicator 3-Pl-64-136 83 P = Drywell/Suppression Chamber differential pressure before venting taken from DWISUPPR CHBR DIFF PRESS indicator 3-PDI-64-137 P = DrywelllSuppression Chamber differential pressure before venting taken from OWISUPPR CHBR DIFF PRESS indicator 3-PDI-64-138 2

TB + 460 = Suppression Chamber temperature before venting taken from SUPPRESSION CHAMBER TEMPERATURE/PRESSURE recorder, (3-XR-64-52 Point 1) and corrected to absolute temperature (Rankine)

TM + 460 = Suppression Chamber temperature after venting taken from SUPPRESSION CHAMBER TEMPERATURE/PRESSURE recorder, 3-XR-64-52 (Point 1) and corrected to absolute temperature (Rankine)

PAl = Drywell pressure after venting taken from DRYWELL PRESSURE irrdicator3-Pl-64-135 P = Drywell pressure after venting taken from DRYWELL PRESSURE indicator 3.Pl-64-136 PM = DrywelllSuppression Chamber differential pressure after venting taken from DW/SUPPR CHBR DIFF PRESS indicator 3-PDI.64-137 PM = Drywell/Suppression Chamber differential pressure after venting taken from DWISUPPR CHBR 01FF PRESS indicator 3-PDI-64-138 LA = Suppression Chamber water level taken from SUPPR POOL WATER LEVEL indicator 3-Ll-64-54A or 66.

BEN Primary Containment Nitrogen 3-Sl-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 36 of 37 Attachment 7 (Page 1 of 2)

Average Nitrogen Consumption and Leakage Date:

Net Nitrogen Leakage (Section 7.8)

1. SUM all Gas additions to obtain the Total Addition:

Gas Addition to the Drywall Total Drywell Control Air Leakage Attachment 2, Section A Cumulative Nitrogen Makeup + Attachment 4, Section A Total Gas Addition = 3 ft

2. Air Temperature Correction Air Temperature Total DW and SC Temperature Correction 3 Attachment 3, Section A ft

3. SUM all the Correction Factors to obtain a Total Correction Factor:

- Correction Factor Total Supp Chamber Level Correction Attachment 1, Section B Total Venting Correction using 3-FTC 84-20 Attachment 5, Section A Total Alternate Venting Correction + 3 Attachment 6, Section B ft Total Correction Factor =

4. CALCULATE Net Nitrogen leakage:

Total Gas Addition Total DW and SC Tempe Correction Total Correction Factor Nitrogen Leakage Total Gas Addition (Step I above)

Total DW and SC Temperature Correction - 2 above)

Total Correction Factor - (Step 3 above) 3 ft Net Nitrogen Leakage = 3 ft

BFN Primary Containment Nitrogen 3-SI-4.7.A.2.A Unit 3 Consumption and Leakage Rev. 0024 Page 37 of 37 Attachment 7 (Page 2 of 2)

Average Nitrogen Consumption and Leakage Date: 7EiJ)i2 (

NOTES

1) For calculation purposes, a day consist of 24-hours. During the days when the time changes to Daylight Savings Time (DST) 23-hours will be used. When returning to Central Standard Time (CST) 25-hours will be used.

2) The average nitrogen leakage (adjusted) must be <542 SCFH (Step 6.OA.1). Notify the Unit Supervisor (US) if the nitrogen leakage exceeds 542 SCFH (Refer to 3-AC 1-64-7 and Tech Specs 3.6.1.1.).

B. Average Nitrogen Leakage (Section 7.8.2)

CALCULATE the Average Nitrogen Leakage Net nitrogen leakagexl.136 Avg. Nitrogen Leakage = . =

Hours during the day fi)x1.136 Avg. Nitrogen Leakage=

Hours)

Avg. Nitrogen Leakage SCFH (Ac)

Uo IV

FINAL Admin RO/SRO A3 PAGE 1 OF 14 OPERATOR:

RO___ SRO DATE:

JPM NUMBER: Admin RO/SRO A3 TASK NUMBER: Radiation Control TASK TITLE: Calculate Airborne Effluent Release Rate jaw O-SI-4.8.b.1.a.1 KJANUMBER: 2.3.11 KJARATING:R03.8 SRO4.3 PRA:

TASK STANDARD: Calculate Stack Release Rate and Total Site Release Fraction determine it does not meet Acceptance Criteria, and determine that vent flowrate must be reduced in accordance with 2-EOI Appendix-12.

LOCATION OF PERFORMANCE: Classroom REFERENCES/PROCEDURES NEEDED: O-SI-4.8.B. l.a. 1, 2-EOI-Appendix- 12 VALIDATION TIME: 15 minutes MAX. TIME ALLOWED:

PERFORMANCE TIME:

COMMENTS:

Additional comment sheets attached? YES NO RESULTS: SATISFACTORY___ UNSATISFACTORY SIGNATURE: DATh:

EXAMINER

INITIAL CONDITIONS: You are an extra operator. Unit2 reactor has scrammed. A small leak exists in primary containment. EOI-2 has been followed to PC/P-i. Primary Containment Venting is in progress in accordance with 2-EOI Appendix-12, Primary Containment Venting.

The Control Bay AUO has partially completed Attachment 11 of O-SI-4.8.B.i.a.l, Airborne Effluent Release Rate.

INITIATING CUE: The Shift Manager directs you to complete the remainder of Attachment ii of O-SI-4.8.B.i.a.i, Airborne Effluent Release Rate, starting at [10.31 and stopping at [12];

determine what actions are required, if any, in accordance with 2-EOI Appendix-i2.

NOTE: The Control Bay AUO has gathered all required data; therefore, some subsequent steps after [10.3] may be completed.

Adniin RO/SRO A3 PAGE 3 OF 14 Classroom INITIAL CONDITIONS: You are an extra operator. Unit2 reactor has scrammed. A small leak exists in primary containment. EOI-2 has been followed to PC/P-i. Primary Containment Venting is in progress in accordance with 2-EOI Appendix-12, Primary Containment Venting.

The Control Bay AUO has partially completed Attachment 11 of O-SI-4.8.B.l.a.1, Airborne Effluent Release Rate.

INITIATING CUE: The Shift Manager directs you to complete the remainder of Attachment 11 of O-SI-4.8.B.1.a.l, Airborne Effluent Release Rate, starting at [10.3] and stopping at [12];

determine what actions are required, if any, in accordance with 2-EOI Appendix-12.

NOTE: The Control Bay AUO has gathered all required data; therefore, some subsequent steps after [10.3] may be completed.

Admin RO/SRO A3 PAGE 4 OF 14 START TIME____

Performance Step 1: Critical X Not Critical 7.0 Procedure Steps (continued)

[10.3] MULTIPLY the release rate by the release factor and RECORD the answer under the column labeled Actual Rate on Attachment 4.

Standard:

Multiplies the Release Rate from the RM-90-250, RM-90-249, and the RM-90-251 by the Release Factor to determine the Actual Rate; candidate will perform this action for each Unit as well as the Radwaste Building (0-RM-90-252) and record the data on Attachment 11 pages 3-6. Refer to Answer Sheet for correct values or see below.

Unit 1 Unit 2 Unit 3 Radwaste Reactor Building Reactor Building Reactor Building (l-RM-90-250) (2-RM-90-250) (3-RM-90-250) 4000 x 0.64 = 2560 4300 x 0.73 = 3139 3100 x 0.69 = 2139 Turbine Building Turbine Building Turbine Building O-RM-90-252 (l-RM-90-249) (2-RM-90-249) (3-RM-90-249) 225 x 0.62 = 139-140 500 x 0.75 = 375 840 x 1.00 = 840 1600 x 0.40 = 640 (1-RM-90-25 1) (2-RM-90-25 1) (3-RM-90-25 1) 910 x 0.80 = 728 2200 x 1.00 = 2200 1900 x 0.75 = 1425 SAT UNSAT N/A COMMENTS:

Admin RO/SRO A3 PAGE 5 OF 14 Performance Step 2: Critical X Not Critical

[10.4] For each unit, SUM the actual rates for the RM-90-249, RM-90-250, and RM 251 monitors. RECORD the unit total release rates in the appropriate columns on Attachment 4.

Standard:

Sums the Actual Rates from the RM-90-249, RM-90-250, and RM-90-25 1 monitors for each Unit and records the Total Release Rate for each Unit on Attachment 11 page 6.

Refer to Answer Sheet for correct values or see below.

Unit 1 Unit 2 Unit 3 2560+375+728=3663 3139+840+2200=6179 2139+640+1425=4204 SAT_ UNSAT N/A COMMENTS:_______________________________

Performance Step 3: Critical X Not Critical

[10.5] SUM the three unit total release rates and the 0RM-90-252 actual rate.

RECORD the building ventilation release rate on Attachment 4.

Standard:

Sums each Units Total Release Rate and the Radwaste Building Actual Release Rate (0-RM-90-252) and records the Building Ventilation Release Rate on Attachment 11 page 6. Refer to Answer Sheet for correct value or see below.

Unit 1 Unit 2 Unit 3 Radwaste Total 3663 + 6179 + 4204 + 139-140 14185-14186 SAT_UNSAT_N/A COMMENTS:

Adinin RO/SRO A3 PAGE 6 OF 14 Performance Step 4: Critical X Not Critical NOTE For reporting purposes, the release fraction should only be recorded to three decimal places.

EXAMPLES A release fraction of 0.12345 should be recorded as 0.123.

A release fraction of 0.00012 should be recorded as 0.000.

[10.6] DETERMINE the building ventilation release fraction by dividing the total building ventilation release rate by 1.50 E+05 (or 150,000) jiCi/sec. RECORD the fraction on both Attachment 2 and Attachment 4.

Standard:

Divides the Total Building Ventilation Release Rate by 150,000 jiCi/sec and determines the Building Ventilation Release Fraction; records on Attachment 11 page 6 and page 2. Refer to Answer Sheet for correct value or see below.

14185.5+/-0.5 / 150,000 = 0.095 SAT_ UNSAT N/A COMMENTS:________________________________

Adrnin RO/SRO A3 PAGE 7 OF 14 Performance Step 5: Critical X Not Critical

[10.7] VERIFY the acceptance criteria as given in Step 6.OB. 1 has been met. The building ventilation release fraction must be less than or equal to 0.90. IF the acceptance criteria have failed, THEN IMMEDIATELY CONTACT the Unit Supervisors. (AC)

Standard:

Determines Building Ventilation Release Fraction is less than 0.90 and does not contact the Unit Supervisors (US). Refer to Answer Sheet for correct value or look at performance step 4.

SAT UNSAT N/A COMMENTS:_____________________________

Performance Step 6: Critical Not Critical X

[11] DETERMINE the elevated (stack) noble gas release rate once per shift by completing the following steps:

[11.1] RECORD the highest noble gas count rates (counts per second, cps) for the 0-RM-90-147 and 0-RM-90-148 monitors in the appropriate columns of Attachment 6 in accordance with one of the following steps:

[11.1.1] IF both the 0-RR-90-147 and at least one of the radiation monitors are operable, THEN OBTAIN the necessary information from 0-RR-90-147 on Panel 9-2. IF applicable, THEN RECORD OOS in the appropriate column of Attachment 6 if one of the monitors is out of service.

Standard:

Steps [11.1] and [11.1.1] have already been completed and the data has been recorded on Attachment 11 page 7. Steps [11.1.2] and [11.2.3] are not applicable and will not be performed SAT UNSAT N/A COMMENTS:

Adniin RO/SRO A3 PAGE 8 OF 14 Performance Step 7: Critical Not Critical X NOTE If O-SI-4.8.B. 1 .a.2 is in effect for the stack monitors, the Chemical Laboratory will report the stack release rate in !ICi!sec for each grab sample. The reported release rate will assume a maximum flow rate and will yield a conservative (high) release value. In this case, Steps 7.O[1 1.2] and 7.O[1 1.3] are NOT applicable.

[11.2] DETERMINE the stack flow rate and RECORD in the appropriate colunm of Attachment 6.

[11.2.1] IF O-FI-90-271 on Panel 1-9-53 is operable, THEN RECORD the stack flow in standard cubic feet per minute (scfin).

Standard:

Steps [11.2] and [11.2.1] have already been completed and the data has been recorded on Attachment 11 page 7. Steps [11.2.2] and [11.2.3] are not applicable and will not be performed SAT_ UNSAT N/A COMMENTS:

Admin RO/SRO A3 PAGE 9 OF 14 Performance Step 8: Critical X Not Critical

[11.3] DETERMINE the stack release rate by using the gross count rate and total stack flow in accordance with the following equation. When there are two gross count rate readings, USE the highest gross count rate. IF both monitors (0-RM-90-147/8) are INOP, THEN CONTINUE with Step 7.O[1 1.4].

Total Stack Flow (scfhi) x Gross Count Rate (cps) x 1.23 E-03 [QICi/sec)/(cps-scflTl)]

Standard:

Determines that the Highest Gross Count Rate is the O-RM-90-147 (Red Pen) and records this reading on Attachment 11 page 7; calculates the Stack Release Rate by multiplying Total Stack Flow, the Highest Gross Count Rate, and 1.23 E-03 [(tCi/sec) together. Refer to Answer Sheet for correct value or see below.

5 x 22700 x 5.75x10 3 1.23x10 = 7 1.605+/-O.005x10 SAT_ UNSAT N/A COMMENTS:________________________________

Performance Step 9: Critical X Not Critical

[11.4] RECORD in the appropriate column of Attachment 6 either the release rate calculated in Step 7.0[1 1.3] or as reported by the Chemical Laboratory for an inoperable monitor.

Standard:

Records the Stack Release Rate calculated in previous step on Attachment 11 page 7.

SAT_ UNSAT N/A COMMENTS:________________________________

Admin RO/SRO A3 PAGE 10 OF 14 Performance Step 10: Critical Not Critical X NOTE Alternative sampling for the WRGERM monitor is satisfied by taking readings from the normal stack release monitors, 0-RM-90-147 and/or 0-RM-90-148, when operable or by manual sampling in accordance with 0-SI-4.8.B.1.a.2 when the normal stack monitors are inoperable. This alternate sampling succession satisfies the requirement for a preplanned alternate method as required in TABLE 3.3.5-1 of the TRM.

[11.5] Wide Range Gaseous Effluent Radiation Monitor (WRGERM), 0-RM-90-306, Panel 2-9-10.

[11.5.1] IF the monitor is inoperable, THEN RECORD INOP in the appropriate column of Attachment 6 and CONTiNUE with Step 7.0[1 1.6]. Otherwise, CONTiNUE with Step 7.0[1 1.5.2].

[11.5.2] ENSURE 0-RM-90-306 is in the Sample Mode.

[11.5.3] RECORD the noble gas release rate in tCi/sec in the appropriate colunm of Attachment 6. RECORD results to two decimal places (e.g., 2.95E 00).

Standard:

Step [11.5], [11.5.2], and [11.5.3] have already been completed and the data has been recorded on Attachment 11 page 8; steps [11.5.1] and [11.6] are not applicable and will not be performed SAT UNSAT N/A _COMMENTS:____________________________

Admin RO/SRO A3 PAGE 11 OF 14 Performance Step 11: Critical Not Critical X

[11.7] IF all release streams to the stack are isolated, THEN USE a release rate factor of 0.00. Otherwise, USE 1.00. RECORD the release rate factor in the appropriate colunm of Attachment 6.

Standard:

Step [11.7] has already been completed and a Release Rate Factor of 1.00 has already been recorded on Attachment 11 page 8 SAT_ UNSAT N/A COMMENTS:________________________________

Performance Step 12: Critical Not Critical

[11.8] CALCULATE the actual release rate by multiplying the highest release rate (0-RM-90-147/148 or 0-RM-90-306) by the release factor. RECORD the information in the Actual Release Rate column on Attachment 6.

Standard:

Records the Highest Stack Release Rate (Stack Release) on Attachment 11 page 8; calculates the Actual Release Rate by multiplying the Highest Stack Release Rate (Stack Release) by the Release Rate Factor (1.00) determined in previous step; records on Attachment 11 page 8. Refer to Answer Sheet for correct value or see below.

7 1.605+/-0.005x10 x 1.00 = 7 1.605+/-O.005x10 SAT_ UNSAT N/A COMMENTS:______________________________

Adniin RO/SRO A3 PAGE 12 OF 14 Performance Step 13: Critical X Not Critical NOTE For reporting purposes, the release fractions should only be recorded to three decimal places.

EXAMPLES A release fraction of 0.12345 should be recorded only as 0.123.

A release fraction of 0.00012 should be recorded only as 0.000.

[11.9] CALCULATE the stack release fraction by dividing the actual release rate by 1.44 E+07 (or 14,400,000) jiCi/sec. RECORD this information on both Attachment 2 and Attachment 6.

Standard:

Calculates the Stack Release Fraction by dividing the Actual Release Rate determined in previous step by 14,400,000 iCi/sec; records this data on Attachment 11 page 8 and page 2. Refer to Answer Sheet for correct value or see below.

7 / l.44x10 1.605+/-0.005x10 7 = 1.1111.118 SAT_ UNSAT N/A COMMENTS:________________________________

Admin RO/SRO A3 PAGE 13 OF 14 Performance Step 14: Critical Not Critical

[11.10] VERIFY the acceptance criteria as given in Step 6.OB.2 has been met. The stack release fraction must be less than or equal to 0.10. IF the acceptance criterion has failed, THEN IMMEDIATELY CONTACT the Unit Supervisors. (AC)

Standard:

Determines that the Stack Release Fraction does not meet the Acceptance Criteria (AC)

SAT UNSAT N/A COMMENTS:________________________________

Performance Step 15: Critical X Not Critical

[12] CALCULATE the total site release fraction by adding the building ventilation and stack release fractions on Attachment 2. VERIFY the site release fraction acceptance criteria as given in Step 6.OB.3 has been met. IF the acceptance criterion has failed, THEN IMMEDIATELY CONTACT the Unit Supervisors. (AC)

Standard:

Calculates the Total Site Release Fraction by adding the Building Ventilation Release Rate Fraction and the Stack Release Rate Fraction; records this data on Attachment 11 page 2. Refer to Answer Sheet for correct value or see below. Determines that it does not meet Acceptance Criteria (AC). Determines that the venting flowrate must be reduced until the Stack Release Fraction and the Total Site Release Fraction meet their respective Acceptance Criteria iaw 2-EOI-Appendix-12 0.095 + 1.111-1.118 = 1.206-1.213 SAT_ UNSAT N/A COMMENTS:______________________________

Admin RO/SRO A3 PAGE 14 OF 14 Performance Step 16: Critical X Not Critical

12. ADJUST 2-FIC-84-19, PATH B VENT FLOW CONT, or 2-FIC-84-20, PATH A VENT FLOW CONT, as applicable, to maintain ALL of the following:

Stable flow as indicated on controller, AND

2-PA-84-21, VENT PRESS TO SGT HIGH, alarm light extinguished, AND

Release rates as determined below:

i. IF PRIMARY CONTAINMENT FLOODING per C-i, Alternate Level Control, is in progress, THEN MAINTAIN release rates below those specified in Attachment 2.

ii. IF Severe Accident Management Guidelines are being executed, THEN MAINTAIN release rates below those specified by the TSC SAM Team.

iii. IF Venting for ANY other reason than items i or ii above, THEN MAINTAIN release rates below

Stack release rate of 1.4 x 107 .tCi/s AND

0-SI-4.8.B.1.a.1 release fraction of 1.

Standard:

Determines that the venting flowrate must be reduced in accordance with 2-EOI Appendix-12, Primary Containment Venting, step (12.iii) until the Stack Release Fraction and the Total Site Release Fraction meet their respective Acceptance Criteria SAT_ UNSAT_ N/A COMMENTS:______

STOP TIME END OF TASK

fye BFN Airborne Effluent Release Rate 0-Sl-48.B.1.a.1 Unit 0 Rev. 0055 Page 49 of 56 Attachment 11 (Page 1 of 8)

EPIP Release Rate Log NOTES

1) This attachment is used to record data during EOls and REP conditions.

8 are similar to

2) Page 2 of 8 is similar to Attachment 2. 3 of 8 through 6 of 8 are similar to Attachment 4, and 7 of 8 and 8 of Attachment 6.

3) Pages from this attachment may be used to document plant release data on as frequent a basis as needed.

4) Multiple copies of forms from this attachment may be used as needed.

5) Any entries on this form may be NAed as needed.

Special Instructions for this attachment.

A. RECORD the From To dates.

B. RECORD the day of the month (under DAY) and time on each line as needed.

C. Instructions for recording the data for each item are as given in the main body of the SI.

Ar 1ey) r BFN Unit 0 Airborne Effluent Release Rate O-Sl-4.8.B.1 .a.1 Rev. 0055 Page 50 of 56 Attachment 11 (Page 2 of 8)

Site Effluent Release Rate Summary From7tf To D t SI STEP Reactor Power (MWT)

TotalSite A I BuildIng Ventilation Stack Release Rate Release Rate UnIt 1 Unit 2 Unit 3 Release Rate Fraction Fraction Fraction V M 7.0[7] 7.0(8.1] 7.0[8.1j 7.0[8.1J 7.0[10.61 7.0111.9] 7.01121 E 7.016J 1oij OI5 ia 3/C 1.Iii-I.Ii L2.rIo-1L

(E Av( ke 1 )(1 BFN Airborne Effluent Release Rate O-Sl-4.8.B.1.a.1 Unit 0 Rev. 0055 Page 51 of 56 Attachment 11 (Page 3 of 8)

Buildinci Effluent Release Rate Loci Unit I-From 1 7;d To Unit I Reactor Building Turbine Building 0 T A I l-RM-90-249 l-RM-90-251 l-RM-90-250 V M Release Rate Actual Rate Release Rate Actual Rate E Release Rate Actual Rate (iCiisoc) Release Factor (pCi!sec) ftiCilsec) Release Factor (pCllsec)

(C&sec) Release Factor i(

1ClIsec) 7.0[1O.1] 7.0(10.2] 7.0(10.3] 7.0(10.1] 7.0(10.21 7.0(10.3]

7.0110.11 7.0110.2] 7.0[10.3]

l a 4ooo Lf 0 o S7 11

( i-I frI 1 keL(

BFN Airborne Effluent Release Rate 0-Sl-4.8.B.1.a.1 Unit 0 Rev. 0055 Page 52 of 56 Attachment 11 (Page 4 of 8)

BuildinQ Effluent Release Rate Log Unit 2 -

From To______

Unit 2 Reactor Building Turbine Building D T 2-RM-90-249 2-RM-90-251 2-RM-90-250 V M Release Rate Actual Rate Release Rate Actual Rate E Release Rate Actual Rate (jiCllsec) Release Factor (ILCI/sec) (jICI!sec) Release Factor (tCIIsec)

(iCI!sec) Release Factor 4iClIsec) 7.0(10.3j 7.0(10.11 7.0(10.21 7.0(10.31 7.0110.11 7.0(10.2] 7.0(10.3]

7.0(10.1] 7.0(10.2]

o,4 43oo o. 73 3(3? 1o f.oo oo f. oo 22oo

, Avec k BFN Airborne Effluent Release Rate 0-SI-4.8.B.1 .a.1 Unit 0 Rev. 0055 Page 53 of 56 Attachment 11 (Page 5 of 8)

Building Effluent Release Rate Log Unit 3 -

4 From

( 7 To_____

Unit 3 Reactor Building Turbine Building D T A I 3-RM-90-249 3.RM-90-251 3-RM-90-250 V M Release Rate Actual Rate Release Rate Actual Rate E Release Rate Actual Rate (jtCllsec) Release Factor 4tCWsec) (iLClIsec) Release Factor (jiCllsec)

(j.iCi!sec) Release Factor ftiClIsec) 7.0(10.11 7.0110.2) 7.0(10.31 7.0(10.1] 7.0[1O.2J 7.0(10.31 7.0110.11 7.0(10.21 7.0(10.31 a (oO j3q c: 1c / 9o0 , 25 / 1.25

Ae6r e14*

BFN Airborne Effluent Release Rate 0-Sl-4.88.1 .a.1 Unit 0 Rev. 0055 Page 54 of 56 Attachment 11 (Page 6 of 8)

BuildinQ Effluent Release Rate LoQ Unit 0 From fo9 To T Radwaste Building Unit Total Release Rates D

A (iCIIsec)

O-RM-90-252 Y M Building Ventilation Release Rate Building E Release Rate Actual Rate Ventilation Release Release Fraction i(

1CiIsec) Unit 1 Unit 2 Unit 3 (jiCi!sec (jCUsec) Factor 7.O[1O.31 7.O[1O.41 7.O[1O.4J 7.O[1O.4j 7.O[1O.5j 7.OtlO.61 7.O[1O.1j 7.O[1O.2j (Z. 137- ILk, 63 6t7 £/OL( frlit- (qi4, p. c

(i 4rr Key )&* 3, BFN Airborne Effluent Release Rate 0-Sl-4.8.B.1.a..1 Unit 0 Rev. 0055 Page 55 of 56 Attachment 11 (Page 7 of 8)

From To Elevated Effluent Release Rate Log O-RM-90-148 STACK FLOW RATE STACK RELEASE D T 0-RM-90-147 RATE (NOTE 2)

HIGHEST GROSS O-FI-90-271 A I Red Pen Green Pen COUNT RATE INOP<16,366 Y M (CPS) (NOTE 1) -OR- ArT 7 CONVERSION GROSS COUNT GROSS COUNT FACTOR 7.011 1.3] & 7.011 1.4]

RATE (CPS) 7.0111 1] 7.0[1 1.2]

E RATE (CPS) 7.0111 .11 1&L 6,7cIo 4.xio$ 75yjo ,17OQ l23E.03 tof.oo/c 1.23E.03 1.23E.03 1.23E.03 1.23E-03 f.23E.03 1.23E.03 1.23E.03 1.23E.03 1.23E03 t23E-03 I.23E.03 I Minimum acceptable flow rate for 0-Fl-90-271 operability is 16,366 SCFM (See note 3).

2 Data from manual sampling results or 0-90-147/148 [(Stack Flow) X Highest Gross Count X I .23E-03J.

3 The minimum acceptable flow rate was revised to 16,366 SCFM (BFPER980545).

Aver 1ey 51 BFN Airborne Effluent Release Rate O-SI-4.8.B.1.a.1 Unit 0 Rev. 0055 Page 56 of 56 Attachment 11 (Page 8 of 8)

Building Effluent Release Rate Log Unit 0 -

From7iay To WRGERMS Noble Gas HIghest Stack Release Release Rate Factor Actual Release Rate Stack Release Fraction DAY TIME (Note 2)

Release Rate Rate (pCilsec) (0.00 or 1.00) (pCi/sac) 0-RM-90-306 (pCilsec) 7.0111.7] 7.0[1l.8J 7.0111.9]

(Note 1).

7.0111.5]

r&k( OI 7 f,olPo. ocxio /000 7 Q+/-O.W Xio /.f/l-/./(8 I Use the higher of the Stack release rate or the WRGERMS release rate.

2 Divide actual Stack release rate (.tCiIsec) by 1 .44E+07 iiCi/sec.

(.

(

Browns Ferry Nuclear Plant Unit 0 Surveillance Instruction 0-SI-4.8.B..1 .a.1 Airborne Effluent Release Rate Revision 0055 Quality Related Level of Use: Reference Use Level of Use or Other Information: Key Number P1470 Effective Date: 04-01-2011 Responsible Organization: GEM, Chemistry Prepared By: John Marshall Approved By: Jeffery Fenton

BFN Airborne Effluent Release Rate O-Sl-4.8.B.f .a.1 Unit 0 Rev. 0055 Page 2 of 56 Current Revision Description Type of Change: Corrective Action Tracking Number: 064 PER CA 271917-001 Deleted old Attachment I as required by NPG-SPP-06.9.2.

Added reference to NPG-SPP-06.9.2 Surveillance Test Program.

Changed steps as required due to Surveillance Task Sheet (STS) being utilized instead of Atttachment 1.

Changed 2-FR-66-111 to 2-XR-66-103 after DCN 70195, S-2 was implemented.

BFN Airborne Effluent Release Rate 0-51-4.8.6.1 .a..1 Unit 0 Rev. 0055 Page 3 of 56 Table of Contents

1.0 INTRODUCTION

4 1.1 Purpose .4 1.2 Scope 4 1.3 Frequency 5

2.0 REFERENCES

6 3.0 PRECAUTIONS AND LIMITATIONS 7 4.0 PREREQUISI1ES 7 5.0 SPECIAL TOOLS AND EQUIPMENT RECOMMENDED 8 6.0 ACCEPTANCE CRITERIA 8 7.0 PROCEDURE STEPS 12 8.0 ILLUSTRPTIONS,A.r.rACHrVIENTS 27 : Independent Review and Remarks Log 28 : Site Effluent Release Rate Summary 30 : Fan Status Report 31 : BuildIng Effluent Release Rate Log 34 : BuildIng Ventilation System Release Factors 38 : Elevated Effluent Release Rate Log 40 : Airborne Effluent for Total Stack Flow Rates 42 Achment 8: Otfgas Instrumentation Log 44 : Airborne Effluent Release Rate 47 0: Sample Flow Abnormal Log 48 Attachmnent 11: EP1P Release Rate Log . 49

BFN Airborne Effluent Release Rate 0-SI-4.8.B.1.a.1 Unit 0 Rev. 0055 Page 4 of 56

1.0 INTRODUCTION

1.1 Purpose This Surveillance Instruction (SI) is used by Browns Ferry Operations and Radlochemical Laboratory personnel to satisfy the following Technical Requirements Manual (TRM) requirements, ODCM requirements, and data recording functions:

Airborne effluent release rates in accordance with 00CM Surveillance Requirement 2.2.2.1.1 .a.

The Instrumentation checks required by ODCM Table 2.1-2.

The Wide Range Gaseous Effluent Radiation Monitor (WRGERMS),

O-RM-90-306, inoperability requirements in accordance with TABLE 3.3.5-1 of the TRM.

The WRGERMS instrumentation check required by TABLE 3.3.5-1 of the TRM.

Attachment his used to record data during EOls and REP conditions.

1.2 Scope

ODCM Control 1.2.2.1 requires that the general public dose rate from noble gas effluents to be limited to less than 500 mRem per year to the total body and less than 3000 mRem per year to the skin. The Off site Dose Calculation Manual (00CM) describes the methodology by which the dose rate limits are converted to plant process variables such as the stack noble gas radioactive release rate limit. The limiting release rates for the authorized effluent release points have been calculated as 0.15 cuiies (Cl) per second for the building level release points and 14.4 Cl per second for the stack.

To ensure compliance with ODCM Control 1.2.2.1, each airborne effluent release point is required to be continuously monitored while actively releasing an airborne stream. This is usually accomplished by in-line process instrumentation which has Control Room alarm capabilities. If a monitor Is inoperable, releases via that gas stream may continue provided compensatory sampling measures are initiated. Compensatory sampling is accomplished by having the Radiochemical Laboratory personnel obtain and analyze grab samples at a prescribed frequency.

Technical Instruction (TI) 15 provides the engineering basis for establishing instrumentation alarm set points, monitor sampling rates, and release point allocation factors for the various plant radiation monitors. The conservative parameters prescribed by Tl-15 ensure 00CM Control 1.2.2.1 limits are satisfied.

1.2 Scope (continued)

Instrumentation checks will be used to provide a reasonable assurance that an unmonitored release does NOT go undetected. The instrument checks will be performed on the required monitoring instrumentation at a frequency such that a failed monitor is readily detected. The instrument checks will usually consist of data acquisltlonhlnstrument readings of such a detail that they will permit the calculation of the total site release rate.

NOTE The source check formerly in this SI (Rev. 40 and previous Revs) are now in 0-Sl-2.1-2.

Additionally, this SI provides the pre-planned alternate monitoring instructions 1 in the for the WRGERMS Instrumentation, 0-RM-90-306 and 0-RR-90-360 event that the minimum number of operable Instrument channels is less than the required number as given in TABLE 3.3.5-1 in the TRM.

1.3 Frequency The normal performance band for this SI Is one week. The procedure will typically start at 0700 Friday and end 0659 the following Friday.

Once per shift, the following checks will be made:

Release rate information will be obtained for each effluent stream having continuous monitoring capabilities.

The overall site release rate will be calculated from the release rate information.

Offgas pretreatment and post-treatment monitors, offgas flow rate, and offgas hydrogen concentration will be recorded during main condenser and offgas treatment systems operations.

The WRGERMS instrumentation operability will be demonstrated by an instrumentation check.

Once per day, each effluent radiation monitor shall demonstrate the operability of its sampling rate instrumentation and associated sample flow alarms.

BFN Airborne Effluent Release Rate 0-Sl-4.8.B.1.a.1 Unit 0 Rev. 0055 Page 6 of 56

2.0 REFERENCES

Browns Ferry Nuclear Plant Technical Requirements Manual (TRM).

Updated Final Safety Analysis Report (UFSAR)

Section 7.12, Process Radiation Monitoring.

Section 9.5, Gaseous Radwaste System (Modified).

Operating Instructions (01)

1-, 2-, and 3-01-90, RadIation Monitoring System Surveillance Instructions (SI)

0-SI-2.1-2, Airborne Effluent Radiation Monitor Source Checks.

0-Sl-4.8.B.1.a.2, Airborne Effluent Release Rate by Manual Sampling when a Gaseous Effluent Monitor is Inoperable.

1-, 2-, and 3-SI-4.8.B.1.a.3, Off Gas Post-Treatment Release Rate by Manual Samphng.

1-, 2-, and 3-SI-4.8.B.5.a, Off Gas Hydrogen Concentration by Manual Sampling.

Technical Instructions (TI)

TI-15, Radioactive Gaseous Effluent Engineering Calculations and Measurements.

0-Tl-336, Continuous Air Monitor Flow Regulator Adjustment.

Offsite Dose Calculation Manual (ODCM).

Part 302 to Title 40 of the Code of Federal Regulations (40 CFR 302), DesIgnation, Reportable Quantities, and Notification.

Memorandum from John W. Sabados to Masoud Bajestani,

Subject:

Sampling Set points for the Eberline Continuous Air Monitor (R46 901116823).

I BFN Unit 0 Airborne Effluent Release Rate 0-SI-4.8.B.1a.1 Rev. 0055 L Page7of56 Date______

2.0 REFERENCES

(continued)

Controlled Vendor Manuals (CVM)

Technical Manual for the 250 CAM Monitoring System, BFN-CVM-2083.

Technical Manual for the 252 CAM Monitoring System, BFN-CVM-2084.

Technical Manual for the 249-251 CAM Monitoring System, BFN-CVM-2085.

Technical and Operating Manual for the CT-2B(s) Control Terminal, BFN-CVM-2090.

Memorandum from M. Bajestani to J. W. Sabados,

Subject:

Steam Packing Exhauster flow (R40 911018914).

Stack Post Mod. Test for OCN WI 7999 (PMT-256) 20 April, 1993.

Technical Requirements Manual Memorandum from Rick Givens to Phil Chadwell,

Subject:

Stack Flow Requirements (R70 980730 843) IBFPER90OJ.

NPG-SPP-06.9.2 Surveillance Test Program V 3.0 PRECAUTIONS AND LIMITATIONS

[NRCICJ Radiation monitors may be removed from service for maintenance, calibration, or testing for periods NOT to exceed 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . If it becomes apparent that a monitor cannot be returned to service within the 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , the Unit Supervisor shall be V

immediately notified to ensure compensatory sampling has been initiated.

(1.ER 250189021)

The night shifts and day shifts are defined by the day on which the shift begins.

(i.e., Friday dayshift is Friday 0700-1900, Friday night shift is Friday 1900 to Saturday 0700.)

0 PREREQUISITES VERIFY this copy of the procedure is the most current revision.

(f3Pf F.

OBTAIN a Surveillance Task Sheet (STS) for this procedure and Work Activity. (Key Number P1 470) 1

BFN Airborne Effluent Release Rate 0-SI-4.8.B..1 .a.1 Unit 0 Rev 0055 Page 8 of 56 5.0 SPECIAL TOOLS AND EQUIPMENT RECOMMENDED None 6.0 ACCEPTANCE CRITERIA A. Responses which fail to meet the acceptance criteria constitute unsatisfactory surveillance instruction results and require Immediate notification of the Unit Supervisor at the time of failure. Failure of release rate acceptance criteria requires notification of the Chemistry Manager. Failure of release rate acceptance criteria will require a National Response Center reportability determination in accordance with Part 302 to Title 40 of the Code of Federal Regulation (40 CFR 302).

B. The noble gas release rate must be limited such that the off site dose and dose rates are in compliance with ODCM Control 1.2.2.1. This will be accomplished by establishing release rate limits for the building/ground and the stack/elevated release points. The corresponding release rate limits will be checked in accordance with the values listed below.

1. The sum of the building release rate fraction must be less than or equal to 0.90. The building release rate fraction is defined as the radioactive noble gas release rate at each monitored building release point divided by the ODCM building release limit of 1.50 E+05 iiCi!sec.

2. The stack release rate fraction must be less than or equal to 0.10. The stack release rate fraction is defined as the radioactive noble gas release rate at the stack dMded by the ODCM release rate limit of 1.44 E+07 i.Ci/sec.

3. The total site release rate fraction must be less than or equal to 1.00. The total site release rate fraction is defined as the sum of the building and stack release rate fractions.

4. Compensatory sampling measures must be initiated whenever a radiation monitor is out of service and effluent releases are continuing via that release point.

BFN Airborne Effluent Release Rate 0-Sl-4.8.B.1.a.1 UnIt 0 Rev. 0055 Page 9 of 56 6.0 ACCEPTANCE CRITERIA (continued)

C. The radioactive gaseous effluent instrumentation operability shall be demonstrated by performance of shiftly andlor daily instrument checks as noted below.

1. Shiftly Checks. The following instrumentation checks must be accomplished at least once per shift during the noted periods of required operability. These instrumentation checks will be used to satisfy ODCM Surveillance Requirements in 2.2.2.1.1 .a, Table 2.1-2, TRM Table 3.3.5-1, and TRM TSR 3.3.9.1 (noble gas monitor and hydrogen analyzer daily requirements only).

Monitor(s) Required Period of Operability 1-, 2-, 3-RM-90-249, When actively releasing an airborne effluent 1-, 2-, 3-RM-90-250, stream (I.e., vents are open and the ventilation 1-, 2-, 3-RM-90-251, fans are on).

and O-RM-90-252 O-RM-90-147 andlor 148 When actively releasing an airborne effluent stream.

O-RM-90-306, and When one or more of the site units are in either O-RR-90-360 MODES I or 2.

1-, 2-, 3-RM-90-265, When actively processing an off gas stream (i.e.,

and!or unit FCV-66-28 Is open).

1-, 2-, 3-RM-90-266 1-, 2-, 3-H2R-66-96 During main condenser offgas treatment system (Channels A and/or B) operations.

The shiftly checks shall be accomplished by recording the release rates or release concentrations as displayed on the appropriate control room recorders. If a monitor is out of service during a required period of,operabllity, compensatory sampling measures will be initiated in accordance with the instructions given in Steps 7.O[9.5],

7.O[1O.1 .3], and/or 7.Ofl 1.1.3].

BFN Airborne Effluent Release Rate 0-SI-4.8.B..1.a.1 UnIt 0 Rev. 0055 Page 10 of 56 6.0 ACCEPTANCE CRITERIA (continued)

2. Daily Checks. The following instrumentation checks must be accomplished at least once per day during the noted periods of required operability.

These instrumentation checks will be used to satisfy 00CM surveillance requirements In Table 2.1-2 (sample flow instrumentation and sample flow annunciators only).

InstrumentatIon Required Period of Operability 1-, 2-, 3-RM-90-249, When actively releasing an airborne effluent 1-, 2-, 3-RM-90-250, stream (i.e., vents are open and the ventilation 1-, 2-, 3-RM-90-251, fans are on).

and 0-RM-90-252 sample flow instrumentation 0-RM-90-147/148 sample When actively releasing an airborne effluent flow rate and stream.

O-FA-90-150 flow abnormal alarm 1-, 2-, 3-PA-90-262 sample When actively processing an off gas stream (i.e.,

pressure abnormal alarm unit FCV-66-28 is open).

The daily checks shall be accomplished by recording the sample flow rates from the appropriate control room instrumentation and/or testing the alarm annunciator condition. Satisfactory sample flow rate checks must fall within the range specified in the following table. Satisfactory annunciator test results will consist of a simple goIno.goa test.

If a monitor Is out of service during a required period of operability, compensatory sampling measures will be initiated in accordance with the Instructions given in Steps 7.C[9.5], 7.O[1 0.1.3], and/or 7.O[1 1.1,3]. Compensatory sample flow rate measurements are required to be made every four hours, but are NOT required to satisfy the sample rate limits in the following table.

Sample Flow (scfm)

Monitor Low High 1-, 2-, 3-RM-90-249 1.73 2.27 1-, 2-, 3-RM-90-251 O-RM-90-252 1.12 1.87 1-, 2-, 3-RM-90-250 3.6 4.4 0-RM-90-1 471148 1.1 1.5

BFN Airborne Effluent Release Rate 0-SI-4.8.B.1.a.1 Unit 0 Rev. 0055 Page 11 of 56 6.0 ACCEPTANCE CRITERIA (continued)

D. The concentration of hydrogen gas in the off gas shall be less than or equal to 4 percent by volume (TRM LCO 3.7.2) as measured by the applicable unit H2R-66-96 Hydrogen Analyzer or as determined from off gas grab samples.

E. Acceptance criteria determination steps will be designated by (AC).

F. The off gas pretreatment radiation levels (1-, 2-, and 3-RM-090-0157) and the off gas flow rate (1-FR-066-01 11 , 2-XR-66-1 03. and 3-FR-066-01 11) instrumentation readings are required for monitoring system performance and for failed fuel performance calculations. There is no Technical Specification surveillance requirements associated with these observations. The observation will be made shiftly during periods of main condenser/offgas treatment system operation.

G. In the event that 1-, 2-, or 3-PA-090-0262 is inoperable, but 1-, 2, or 3 RM-090-0265 or 0266 is operable, the off gas post treatment flow must be recorded at least once every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and the flow must be at least 0.06 cfm. If both 1-, 2, or 3 RM-090-0265 and 0266 are Inoperable a flow Is not required. If the flow acceptance criteria is not met, declare 1-, 2, or 3 RM-090-0265 and 0266 inoperable and notify Chemistry to initiatel-, 2, or 3-S14.8.B.1.a.3.

BFN Airborne Effluent Release Rate 0-SI-4.8.B.1 .a.1 UnIt 0 Rev. 0055

. Pagei2ofSG Date1R

() PROCEDURE STEPS VAIl notes, remarks, and comments erded on Attachment 1.

Each statement is to be numbered and cross-referenced to the appropriate

,ttachment or SI step.

?5 Attachments NOT used in the performance of this SI do NOT need to be included in the completed SI package.

OBTAIN permission from the Unit I Unit Supervisor to perform this instruction. bI UI OBTAIN permission from the Unit 2 Unit Supervisor to perform this instruction.

U2 OBTAIN permission from the Unit 3 Unit Supervisor to perform A this instruction.

U3 (NRCIC] NOTIFY the Unit Operator (U2) of the intent to begin this iflStflJCtiofl. IRPT 82-16w LER 259!82321 On the Surveillance Task Sheet (STS)

RECORD the Start Date & lime.

SI step performance and acceptance criteria verification are to be noted on the appropriate SI attachments for Steps 7.016] through 7.0[15]

REVIEW the Precautions and Limitations in Section 3.0.

INITIAL on Attachment 2.

ENSURE that all Prerequisites In Section 4.0 have been met.

)L INITIAL on Attachment 2.

BFN Airborne Effluent Release Rate 0-SI-48.B.1 .a.1 Unit 0 Rev. 0055 Page 13 of 56 Dat&72ay PROCEDURE STEPS (continued)

OBTAIN the following information.

1I15 Once per shift, RECORD on Attachment 2 each units 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months average

/b power level in megawatts thermal (MWT). IF shutdown, THEN ENTER 0.

Due to variations In required performance frequency and to minimize impact on personnel, Steps 7.0(93,7.0(10], and 7.0(11] through 7.0(15] can be completed Independently. If the stack flow instrumentation (0-FI-90-271) Is Inoperable or out of service and 0-FI-90-348 is NOT used, Attachment 7 must be completed before Step 7.0[1 1] can be completed.

Status Determination RM-90-249 Once per shift: RECORD on Attachment 3 the operating status of each ventilation fan monitored by this CAM. The status shall be indicated with X in the appropriate ONIOFF column.

9 . Once per day (night shift): IF all fans serviced by this CAM are off and the monitor is out of service, THEN VERIFY the exhausts fan control switches are tagged out of service and VERIFY the fan dampers are closed.

6-90-250

.1 Once per shift: CHECK the status of each fan contributing flow to the ventilation path monitored by the RM-90-250 CAM. USE an A or B to denote which fan is operating. INDICATE the fan status by using the 0 column for all fans off (If applicable), the S column for fans on slow, or the F column for fans on fast.

RM-90-251 j) Once per shift: RECORD on Attachment 3 the operating status of each ventilation fan monitored by this CAM. The status shall be indicated with X in the appropriate ON/OFF column.

BFN Airborne Effluent Release Rate 0-Sl-4.8.B.1.a.1 Unit 0 Rev. 0055 Page 14 of 56 PROCEDURE STEPS (continued)

.2] Once per day (Night shift): IF all fans serviced by this CAM are off and the monitor is out of service, THEN ENSURE the exhausts fan control switches are tagged out of service and VERIFY the fan dampers are closed.

O-RM-90-252 (Unit I Only) 0 Once each shift RECORD the operating status of fans monitored by this CAM with an X in the appropriate column of Attachment 3.

USE column for all fans off, column 1 for one fan on, or column 2 for two fans on.

I IF any of the indicated fans (stack dilution or CAM) are operating and the corresponding monitor is declared inoperable, THEN CONTACT the Chemical Laboratory and ENSURE that compensatory sampling In accordance with O-Sl-4.8.B.1.a.2 is being conducted.

[ Prior to 0659 Friday morning, TOTAL the number of shifts each column of Attachment 3 was marked. RECORD the totals at the bottom of Attachment 3.

BFN Airborne Effluent Release Rate O-SI-4.8.B.1.a.1 UnIt 0 Rev. 0055 Page 15 of 56 Date______

(3) PROCEDURE STEPS (continued)

.?5DETERMINE the building ventilation noble gas release rate once per shift by completing the following steps and VERIFY that all monitors with an open release path are OPERABLE:

I . For each monitor listed on Attachment 4, COMPLETE one of the FOLLOWING four steps:

0 . From the CONTINUOUS AIR MONITORING SYSTEM OPERATOR CONSOLE, O-CONS-90-361, PANEL 1-9-2, OBTAIN the noble gas release rate by USING the touchscreen options on the console. SELECT the noble gas option on the screen (NGAS). RECORD the noble gas release rate (p.Cilsec) In the appropriate columns of Attachment 4 for each operable building ventilation radiation monitor. The radiation monitor should register a positive release rate; OTHERWISE, DECLARE the monitor inoperable. This recording is performed as an Instrument Check (CHANNEL CHECK).

[10.1.2] IF the operator console 0-CONS-90-361 is NOT available and the CAMs are operating, THEN OBTAIN the release rate data from the local display on each CAM by SELECTING channel I with the thumb wheel or directly reading the Chemistry CAM display. The radiation monitor should register a positive release rate; OTHERWISE, DECLARE the monitor inoperable. This recording is performed as an Instrument Check (CHANNEL CHECK).

BFN Airborne Effluent Release Rate 0-Sl.4.8.B.1 .a.1 Unit 0 Rev. 0055 Page 16 of 56 4

1 L(

Date21

!2i7 PROCEDURE STEPS (continued)

If 0-Sl-4.8.B.1 .a.2 is in effect for the CAMs, the Chemical Lboratory will report the release rate in J.LCilsec for each grab sample. The reported release rate will assume a maximum flow rate and will yield a conservative (high) release value.

[10.1.3] For out of service and/or inoperable CAMs with ventilation system in service, CONTACT the Chemical Laboratory and ENSURE that A manual sampling Is being accomplished in accordance with 0-Sl-4.8.B.1 .a.2. RECORD on Attachment 4 the release rate for each inoperable CAM as reported by the Chemical Laboratory.

[10.1.4] IF the ventilation system for a CAM is totally i isolated (i.e., no environmental releases occurring),

iA THEN RECORD OOS in all three columns on Attachment 4.

For each monitor, USE Attachments 3 and 5 and DETERMINE the release factor based on fan status. RECORD the release factors from attachment 5 in the appropriate columns on Attachment 4.

10.3] MULTIPLY the release rate by the release factor and RECORD the answer under the column labeled 11 Actual Rated on Attachment 4.

[10.4] For each unit, SUM the actual rates for the RM-90-249, RM-90-250, and RM-90-251 monitors. RECORD the unit total release rates in the appropriate columns on Attachment 4.

[10.5] SUM the three unit total release rates and the 0-RM-90-252 actual rate.

RECORD the building ventilation release rate on Attachment 4.

I r

BFN Airborne Effluent Release Rate 0.SI-48.B.1.a.1 UnitO Rev 0055 Page 17 of 56 PROCEDURE STEPS (continued)

NOTE For reporting purposes, the release fraction should only be recorded to three decimal places.

EXAMPLES A release fractIon of 0.12345 should be recorded as 0.123.

A release fractIon of 0.00012 should be recorded as 0.000.

[10.61 DETERMINE the building ventilation release fraction by dividing the total building ventilation release rate by 1.50 E+05 (or 150,000) jCiIsec.

RECORD the fraction on both Attachment 2 and Attachment 4.

[10.7] VERIFY the acceptance criteria as given in Step 6.OB.1 has been met.

The building ventilation release fraction must be less than or equal to 0.90. IF the acceptance criteria have failed, THEN IMMEDIATELY CONTACT the Unit Supervisors. (AC)

BFN Airborne Effluent Release Rate 0-SI-4.8.B.1.a.1 UnitO Rev. 0055 Page 18 of 56 Date______

PROCEDURE STEPS (continued)

(jj) DETERMIN E the elevated (stack) noble gas release rate once per shift by completing the following steps:

RECORD the highest noble gas count rates (counts per second, cps) for the O-RM-90-147 and 0-RM-90-148 monitors in the appropriate columns of Attachment 6 in accordance with one of the following steps:

.1 IF both the 0-RR-90-147 and at least one of the radiation monitors are operable, THEN OBTAIN the necessary Information from 0-RR-90-147 on Panel 9-2. IF applicable, THEN RECORD OOS in the appropriate column of Attachment 6 if one of the monitors is out of service.

[11.1.2] IF 0-RR-90-147 is inoperable and at least one of the radiation monitors is operable, THEN OBTAIN the necessary data from the 0-RM-90-147B andlor 0-RM-90-148B monitors located on Panel 1-9-10. IF applicable, ThEN RECORD OOS in the appropriate column of Attachment 6 if one of the monitors Is out of service.

[11.1.3] IF both monitors are inoperable, ThEN CONTACT the Chemical Laboratory and ENSURE that manual sampling has been initiated in accordance with 0-Sl-4.8.B.1 .a.2.

RECORD OOS in the appropriate columns of Attachment 6.

BFN Airborne Effluent Release Rate 0-Sl-4.8.B.1 .a.1 UnIt 0 Rev. 0055 Page 19 of 56 PROCEDURE STEPS (continued)

If O-Sl-4.8.B.1 .a.2 is in effect for the stack monitors, the Chemical Laboratory will report the stack release rate in iiCilsec for each grab sample. The reported release rate will assume a maximum flow rate and will yield a conservative (high) release value. In this case, Steps 7.O[1 1.2] and 7.O[1 1.3] are NOT applicable.

I . ] DETERMINE the stack flow rate and RECORD in the appropriate column of Attachment 6.

IF O-Fl-90-271 on Panel 1-9-53 is operable, THEN RECORD the stack flow in standard cubic feet per minute (scfm).

[11.2.2] If O-FI-90-271 on Panel 1-9-53 is inoperable, the flow can be determined from O-Fl-90-348 on Panel 25-412 In the WRGERMS

,JIA building. IF O-Fl-90-348 is used for the flow, THEN MAKE a note in the remarks log that O-Fl-90-348 was used.

[11.2.3] iF O-Fl-90-271 on Panel 1-9-53 is inoperable and O-Fl-90-348 is NOT used, THEN ESTIMATE the stack flow every four hours using Attachment 7.

RECORD the total stack flow in scfm on Attachment 7. RECORD on Attachment 6 the most current value of the 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months observations from Attachment 7.

11.3] DETERMINE the stack release rate by using the gross count rate and total stack flow in accordance with the following equation. When there are two gross count rate readings, USE the highest gross count rate. IF both monitors (O-RM-90-14718) are INOP, THEN CONTINUE with Step 7.O[1 1.4].

Total Stack Flow (scfm) x Gross Count Rate (cps) x 1.23 E-03 [(p.Cilsec)!(cps-scfm)]

111.4] RECORD in the appropriate column of Attachment 6 eIther the release rate calculated in Step 7.O[1 1.3] or as reported by the Chemical Laboratory for an inoperable monitor.

BFN Airborne Effluent Release Rate 0-Sl-4.8.B.1.a.1 Unit 0 Rev. 0055 Page 20 of 56 PROCEDURE STEPS (continued)

Alternative sampling for the WRGERM monitor Is satisfied by taking readings from the normal stack release monitors, 0-RM-90-147 and/or 0-RM-90-148, when operable or by manual sampling in accordance with 0-Sl-4.8.B.1 .a.2 when the normal stack monitors are inoperable. This alternate sampling succession satisfies the requirement for a preplanned alternate method as required in TABLE 3.3.5-1 of the TRM.

.5 Wide Range Gaseous Effluent Radiation Monitor (WRGERM),

0-RM-90-306, Panel 2-9-10.

[11.5.13 IF the monitor is Inoperable, THEN tJIA RECORD 9NOP in the appropriate column of Attachment 6 and CONTINUE with Step 7.0[1 1.6]. Otherwise, CONTINUE with Step 7.0[1 1.5.2].

ENSURE 0-RM-90-306 is in the Sample Mode.

RECORD the noble gas release rate in pCi/sec In the appropriate column of Attachment 6. RECORD results to two decimal places (e.g., 2.95E 00).

[11.6] IF the WRGERM monitor is Inoperable for a period greater than one day, THEN CONTACT the Chemistry Manager. IF the monitor remains inoperable for a period of seven days, THEN INITIATE a Problem Evaluation Report within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months In accordance with TRM Table 3.3.5-1 (Action E.2).

all release streams to the stack are isolated, THEN USE a release rate factor of 0.00. Otherwise, USE 1.00. RECORD the release rate factor In the appropriate column of Attachment 6.

() CALCULAT E the actual release rate by multiplying the highest release rate (0-RM-90-1471148 or 0-RM-90-306) by the release factor.

RECORD the information in the Actual Release Rate column on Attachment 6.

BFN Airborne Effluent Release Rate 0-SI4.8.B.1 .a..1 Unit 0 Rev. 0055 Page 21 of 56 PROCEDURE STEPS (continued)

For reporting purposes, the release fractions should only be recorded to three decimal places.

A release fraction 010.12345 should be recorded only as 0.123.

A release fraction of 0.00012 should be recorded only as 0.000.

[11.9] CALCULATE the stack release fraction by dividing the actual release rate by 1.44 E+07 (or 14,400,000) iCiIsec. RECORD this information on both Attachment 2 and Attachment 6.

[11.101 VERIFY the acceptance criteria as given in Step 6.OB.2 has been met.

The stack release fraction must be less than or equal to 0.10. IF the acceptance criterion has failed, THEN IMMEDIATELY CONTACT the Unit Supervisors. (AC)

[12] CALCULATE the total site release fraction by adding the building ventilation and stack release fractions on Attachment 2. VERIFY the site release fraction acceptance criteria as given in Step 6.OB.3 has been met. IF the acceptance criterion has failed, THEN IMMEDIATELY CONTACT the Unit Supervisors. (AC)

NOTE Verify 2-FCV-66-28 is unrestrained, open and locked.

[13] Once per shift, RECORD the Unit 1,2, and 3 offgas instrumentation readings on Attachment 8.

[13.1] In the UFCV.. 28 column, PLACE an X In the appropriate box (open or closed).

[13.2] IF the units FCV-66-28 is CLOSED, THEN RECORD all other offgas readings as NIA (NOT applicable).

CONTINUE with Step 7.O[13.6].

BFN Airborne Effluent Release Rate 0-Si-4.8.B.1 .a.1 Unit 0 Rev. 0055 Page 22 of 56 7.0 PROCEDURE STEPS (continued)

[13.3) IF the unit is NOT under main condenser/offgas treatment system operations, THEN RECORD the offgas flowrate recorder, offgas pretreatment radiation monitor, and the offgas recombiner readings as N!A (NOT applicable, i.e., NOT required). CONTiNUE with Step 7.0(13.5].

[13.4] RECORD the offgas flowrate recorder [Readings from FR-66-20 (Units 1,2 and 3) should be recorded If FR-66-1 11 is inoperable. IF readings are taken from FR-66-20 on Units 1,2 or 3, THEN MAKE a note in the remarks log that readings were taken from FR-66-20), offgas pretreatment radiation monitor, the offgas post-treatment radiation monitors, and the offgas recombiner readings.

IF the Instrumentation is inoperable, THEN RECORD the readings as INOP. For the FR-66-1 11, IF the narrow range is saturated (upscale; most readings are greater than 30 scfm),

THEN USE the wide range recorder OTHERWISE use the narrow range.

[13.5) IF both of the offgas post-treatment monitors (RM-90-265 and RM-90-266) for a particular unit are inoperable and the unit FCV-66-28 valve is OPEN, THEN CONTACT the Chemical Laboratory and ENSURE that manual sampling has been Initiated in accordance with the applicable Units 1-,

2-, and 3-Sl-4.8.B.1.a.3.

[13.6] IF the observations have been complete for all units, THEN CONTINUE with Step 7.0[14]. OTHERWISE, CONTINUE with the next unit.

(14] Once per day (day shift), RECORD on Attachment 9 the various radiation monitors sample flow rate and/or the abnormal sampling annunciator response In accordance with the following instructions:

[14.1] GE Stack Gas Monitor: RECORD the sample flow rate from the STACK GAS SAMPLE FLOW indicator/transmitter, 0-FIT-090-0153.

BFN Airborne Effluent Release Rate O-Sl-4.8.B.1 .a.1 Unit 0 Rev 0055 Page 23 of 56 7.0 PROCEDURE STEPS (continued)

[14.2] Continuous Air Monitors:

[14.2.1] From the CONTINUOUS AIR MONITORING SYSTEM OPERATOR CONSOLE, O-CONS-90-361, PANEL 1-9-2, OBTAIN the noble gas sampling rate by USING the touchscreen options on the console. SELECT the flow option on the screen (FLOW). RECORD the noble gas sampling rate (scfm) in the appropriate columns of Attachment 9 for each operable building ventilation radiation monitor.

[14.2.2] IF the operator console O-CONS-90-361 is NOT available and the CAMs are operating, THEN OBTAIN the sampling rate data from the local display on each CAM by SELECTING channel 15 wIth the thumb wheel or directly reading the Chemistry CAM display.

[14.2.3] IF the sampling flow rate data is NOT available, THEN REQUEST the US to declare the CAM Inoperable, CONTACT the Chemical Laboratory, and ENSURE manual sampling has been initiated in accordance with O-Sl-4.8.B.1 .a.2.

NOTE The following alarm annunciators will be tested dunng the performance of Steps 7.O[14.3]

and 7.O[14.4]. Appropriate communications must be established with the unit control room(s) prior to initiating the alarm.

O-FA-090-0150 STACK GAS SAMPLE FLOW ABNORMAL (1-XA-055-0022B, Window 1) 1-PA-090-0262 OFFGAS SAMPLE LINE PRESSURE ABNORMAL (1-XA-055-0004C, Window 28) 2-PA-090-0262 OG POST TRTMT SAMPLE LINE PRESS ABNORMAL (2-XA-055-0004C, Window 28) 3-PA-090-0262 OFFGAS SAMPLE LINE PRESSURE ABNORMAL (3-XA-055-0004C, Window 28)

BFN Airborne Effluent Release Rate 0-SI-4.8.B.1.a.1 UnIt 0 Rev. 0055 Page 24 of 56 7.0 PROCEDURE STEPS (continued)

[14.3] Stack Sample Flow Abnormal NOTE All manipulations are performed from the Stack unless noted otherwise.

[14.3.1] ESTABLISH communications with Unit I Operator.

[14.3.2] VERIFY 0-FA-090-0150, STACK GAS SAMPLE FLOW ABNORMAL on 1-XA-055-0022B window I on Panel 9-22 RESET.

[14.3.31 OBSERVE 0-FIT-090-0153, STACK GAS SAMPLE FLOW indication.

[14.3.4] PLACE 0-FC-090-0153, STACK GAS SAMPLE FLOW CONTROLLER to MAN.

[14.3.5] PLACE 0-FC-090-0153, STACK GAS SAMPLE FLOW CONTROLLER valve positioner to OPEN.

[14.3.6] WHEN 0-FIT-090-0153, STACK GAS SAMPLE FLOW Indicates 3.0 SCFM or greater, THEN VERIFY O-FA-090-0150, STACK GAS SAMPLE FLOW ABNORMAL IN ALARM.

[14.3.7] PLACE 0-FC-090-0153, STACK GAS SAMPLE FLOW CONTROLLER valve positioner to STOP.

[14.3.8] PLACE 0-FC-090-0153, STACK GAS SAMPLE FLOW CONTROLLER to AUTO.

[14.3.9] OBSERVE 0-FIT-090-0153, STACK GAS SAMPLE FLOW indication returns to approximately the value observed in Step 7.0[14.3.3].

[14.3.10] VERIFY 0-FA-090-0150, STACK GAS SAMPLE FLOW ABNORMAL will RESET.

[14.3.11] IF O-FA-090-0150, STACK GAS SAMPLE FLOW ABNORMAL fails to alarm or reset and 0-RM-090-0147/0148 are operable, THEN PERFORM Attachment 10 to record sample flow readings every four hours.

BFN Airborne Effluent Release Rate 0-Sl-4.8.B.1.a.1 UnitO Rev. 0055 Page 25 of 56 Date 7.0 PROCEDURE STEPS (continued)

[14.4] Offgas Post-Treatment Sample Flow Abnormal

[14.4.1] NOTIFY the Unit Operators that they will receive annunciation on the following alarms:

1-PA-090-0262 OG POST TRTMT SAMPLE LINE PRESS ABNORMAL (1-XA-055-0004C, Window 28) 2-PA-090-0262 OG POST TRTMT SAMPLE LINE PRESS ABNORMAL (2-XA-055-0004C, Window 28) 3-PA-090-0262 OFFGAS SAMPLE LINE PRESSURE ABNORMAL (3-XA-055-0004C, Window 28)

[14.4.2] On Panel 25-94 In the Offgas Post-Treatment Building, CLOSE the unit SHV-090-0512 valve.

[14.4.3] VERIFY with the UO that the annunciator is in ALARM.(AC)

[14.4.4] OPEN the unit SHV-090-0512 valve.

[14.4.5] VERIFY with the UO that the annunciator will clear when reset.

(AC)

[14.4.6] IF PA-090-0262 fails the AC and RM-090-0265/0266 are operable with the FCV-066-0028 valve open, THEN USE Attachment 10 to record the sample flow readings every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

[14.4.7] CONTINUE with the next unit, until all three unit offgas post-treatment systems have been completed.

[151 PERFORM the following reviews at the completion of each shift or as stated:

[15.1] Unit Supervisor PERFORM Independent Verification of calculations and Acceptance Criteria on Attachments 2,4, 6, 7,8, and 9.

[15.2] STk REVIEW the data for Technical Requirements Manual and ODCM compliance.

BFN Airborne Effluent Release Rate 0-Sl-4.8.B.1.a.1 Unit 0 Rev. 0055 Page 26 of 56 Date________

7.0 PROCEDURE STEPS (continued)

[16] PERFORM the following during night shift:

[16.1] MAKE a copy of the up-to-date Attachments 3, 6, and 8. PLACE the copies In a folder marked for the Radiochemical Laboratory pickup.

KEEP the folder at the log AUOs desk until picked up by a Chemistry person.

NOTE The following steps are to be performed and initialed at the end of the SI performance week.

[17] REVIEW all applicable attachments and VERIFY they are complete.

[18] ENSURE all initials which appear In this instruction have been properly recorded and identified as required on Surveillance Task Sheet (STS). This includes, but Is NOT limited to AUOs, Unit Supervisors, Shift Manager, and STAs.

[19] ENSURE all Acceptance Criteria listed in Step 6.0 were met.

[20] For each Acceptance Criteria failure, ENSURE a PER and/or WO is initiated as applicable. ENSURE each PER and/or WO is identified in the Remarks Log. N1A if no Acceptance Criteria is failed.

[21] On the Surveillance Task Sheet (STS)

RECORD the Completion Date & Time

REVIEW and COMLPETE the Surveillance Task Sheet (STS) through the Test Director/Lead Perform & Date fields

[22] NOTIFY the Unit Operators and the Unit Supervisors that this instruction is complete.

BFN Airborne Effluent Release Rate 0-SI-4.8.B.1.a.1 UnitO Rev. 0055 Page 27 of 56 8.0 ILLUSTRATIONSIATTACHMENTS Attachment 1: Independent Review and Remarks Log Attachment 2: SIte Effluent Release Rate Summary Attachment 3: Fan Status Report Attachment 4: Building Effluent Release Rate Log Attachment 5: BuIlding Ventilation System Release Factors Attachment 6: Elevated Effluent Release Rate Log Attachment 7: Airborne Effluent for Total Stack Flow Rates Attachment 8: Offgas Instrumentation Log Attachment 9: Airborne Effluent Release Rate Attachment 10: Sample Flow Abnormal Log Attachment 11: EPIP Release Rate Log

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BFN Airborne Effluent Release Rate O-Sl-4.8.B.1.a.1 Unit 0 Rev. 0055 Page 38 of 56 Attachment 5 (Page 1 of 2)

Building Ventilation System Release Factors NOTE If one or more of the fans are off and one or more of the fans are on, assume off fans are on slow. (This will cover the case where the fans are off off slow; off, slow, off etc.)

1-, 2-. and 3- RM-9O-250 Fan Status (Note)_________ Release Factor Refuel Reactor Twbtne Unit I UnIt 2 Unit 3 Off Off Off 0.00 0.00 0.00 Stow Slow Stow 0.49 0.53 0.49 Fast Slow Slow 0.63 0.60 0.59 Stow Fast Slow 0.64 0.73 0.69 Stow Slow Fast 0.72 0.73 0.71 Fast Fast Stow 0.77 0.80 0.78 Fast Slow Fast 0.86 0.80 0.81 Stow Fast Fast 0.87 0.94 0.91 Fast Fast Fast 1.00 1.00 1.00 0-RM-90-252 Number Fans On 0 1 2 Fans Release Factor 0.00 0.62 1.00

(

BFN Airborne Effluent Release Rate 0-Sl-4.8.B.1 al UnIt 0 Rev. 0055 Page 39 of 56 Attachment 5 (Page 2 of 2)

Turbine Floor CAM Release Factors I -RM-90-249, 2-RM-90-249, and 3-RM-90-251 Number Fans On 0 1 2 3 4 Release Factor 0.00 0.25 0.50 0.75 1.00 1-RM-90-251, 2-RM-90-251, and 3-RM-90-249 Number Fans On 0 1 2 3 4 5 Release Factor 0.00 0.20 0.40 0.60 0.80 1.00

(

BFN Airborne Effluent Release Rate 0-Sl..4.8.B.1.a.1 Unit 0 Rev. 0055 Page 49 of 56 Attachment 11 (Page 1 of 8)

EPIP Release Rate Log NOTES

1) This attachment is used to record data during EOls and REP conditions.

2) Page 2 of 8 is simflar to Attachment 2. 3 of 8 through 6 of 8 are similar to Attachment 4, and 7 of 8 and 8 of 8 are similar to Attachment 6.

3) Pages from this attachment may be used to document plant release data on as frequent a basis as needed.

4) Multiple copies of forms from this attachment may be used as needed.

5) Any entries on this form may be NAed as needed.

Special Instructions for this attachment.

A. RECORD the From To dates.

B. RECORD the day of the month (under DAY) and time on each line as needed.

C. Instructions for recording the data for each item are as given in the main body of the SI.

I BPN Airborne Effluent Release Rate 0$l-4.8.B.1.a.1 Unit 0 Rev. 0055 Page 50 of 56 Attachment 11 (Page 2 of 8)

Site Effluent Release Rate Summary From D T SI STEP Reactor Power (MWI)

A I TotalSite BuildIng Ventilation Stack Release Rate Release Rate Y M Unit I Unit 2 UnIt 3 Release Rate Fraction Fraction Fraction E 7.016) 7.0)7J 7.0[8.1 7.0[8.IJ 7.018.1) 7.0110.61 7.O[11.9J 7.0112)

T&IJDj i4 31o3 Ø

C I BFN Airborne Effluent Release Rate 0-Sl-4.8.B.1.a1 Unit 0 Rev. 0055 Page 51 of 56 Attachment 11 (Page 3 of 8)

Building Effluent Release Rate Loa - Unit I From To_______

Unit I 0 T Reactor But!d!ng Turbine Building A

1-RM.90.250 l-RM-90.249 1-RM4O-251 Y M E Release Rate Actual Rate Release Rate Actual Rate Release Rate Actual Rate

(pCfIseo) Release Factor (ijClfsec) (pClec) Release Factor (jiCUaec) WC1ec) Release Factor (iiCllsec) 7.0110.11 7.0110.2) 7.0(10.3) 7.0(10.1) 7.0(102) 7.0(10.3) 7.0(10.11 7.011021 7.0(10.3)

°

I BFN Airborne Effluent Release Rate 0-Sl-48.B.1.a.1 Unit 0 Rev. 0055 Page 52 of 56 Attachment 11 (Page 4 of 8)

BuildinpEffluent Release Ratei,oa Unit 2 From To______

Unit 2 D T Reactor BuUdfn Twblne Bulldbig A I 2-RM.90.250 2-RM-80.249 2-RM-G0-251 V M E Release Rate Actual Rate Release Rate Actual Rate Release Rate Actual Rate (ClI8ac) Release Factor WCMec) (i*ClIsec) Release Factor (p016cc) (ILCUSOC) Release Factor (pClIsec) 7.0110.1) 7.011021 7.0110.31 7.0110.11 7.0(102J 7.0(10.31 7.0(10.11 7.0(10.2) 7.0110.31

&4 gi 43oo D.7S 1.00 1. oo

I BFN AIrborne Effluent Release Rate 0-SI-4.8B.1.a.1 UnIt 0 Rev. 0055 Page 53 of 56 Attachment 11 (PageS of 8)

Building Effluent Release Rate L0Q Unit 3 From To UnIt 3 D T ROactOrBU5tTIg TwblneBuUdtng A

3-RM.90.250 3.RM-0-249 3-RM4O.251 Y M E Release Rate Actual Rate Release Rate Actual Rate Release Rate Actual Rate.

(pCVsec) Release Factor (pCUsoc) (iaClec) Release Factor OtCUsec) (CtIsec) Release Factor (iiCuaec) 7.0110.11 7.0110.21 7.0110.31 7.0(10.11 7.011021 7.0L10.3) 7.0110.11 7.0110.21 7.0(10.31

( ORi /4o, IIoo

I BFN Airborne Effluent Release Rate 0-Sl.4.8.B.1.a.1 Unit 0 Rev. 0055 Page 54 of 56 Attachment 11 (PageS of 8)

Building Effluent Release Rate Lo Unit 0 From1Je To 0 T Radwasto Building Unit Taint Release Rates A I 0-RM-B0-252 (liCUsec)

V M Building Ventilafton E Release Rate Actual Rate pete p, Building Release Ventilation (pCIIsec) Factor (liClIsec) Unit I UnIt 2 UnIt 3 (itCUaec) Release Fraction 7.Otl 0.1J 7.011021 7.OLIO.3J 7.10.4) 7.0110.41 7.0110.41 7.0110.51 7.0110.61 oI 0. L?

C I BFN Airborne Effluent Release Rate 0-SI-4.8.B.1..a.1 I Unit 0 Rev. 0055

[ PageSSof5G Attachment 11 (Page 7 of 8)

From To_______

Elevated Effluent Release Rate Log D T O.RM-9O-147 ORMJI)-148 STACK FLOW RATE STACK RELEASE A HIGHEST GROSS O.Fi0-27i RATE (NOTE 2) i Red Pen Omen Pen INOPC16.365 Y M (CUSEC)

GROSS COUNT GROSS COUNT (NOTE 1) -OR-Arr 7 CONVERSION E RATE (CPS) 7.0111.11 RATE (CPS) 7.011 1.1) 7.01112) FACTOR 7.0111.31 & 7.0111.4) r1 5.1j 5 0

g,g, 123E t23&03 I Minimum acceptable flow rate for 0-Fl-S0-271 operability is 16,366 SCFM (See note 3).

2 Data from manual sampling results or 0-90-1471148 1(Stack Flow) X Highest Gross Count X 1.23E-03].

3 The minimum acceptable flow rate was revised to 16,366 SCFM (BFPER9BO545).

I BFN Airborne Effluent Release Rate 0-Sl-4.8.B.1.a.1 Unit 0 Rev. 0055 Page 56 of 56 Attachment 11 (Page 8 of 8)

BuildinQ Effluent Release Rate Lou Unit 0 -

From To_______

DAY TiME WRGERMS Nol3te Gas Highest Stack Release Release Rate Factor Actual Release Rate Slack Release FractIon Release Rate Rate (tCUsec) (0.00 or 1.00) (pCusec) (Note 2) 0-Isec)

(Note 1). 7.0111.7) 7.oJ11.8) 1.0111.9) 1 Sx /01

. / Q7 I Use the higher of the Stack release rate or the VVRGERMS release rate.

2 Divide actual Stack release rate (tiC Tlsec) by 1.44E+07 tiCllsec.

F I N AL Admin SRO A4 PAGE 1 OF 5 OPERATOR:

SRO___ DATE:

JPMNTJMBER: SROA4 TASK NUMBER: Emergency Plan TITLE: Classify the event per REP (Uncontrolled water level decrease in SFSP)

K/ANUMBER: 2.4.41 K/A RATING: SRO4.6 PRA:

TASK STANDARD: The event is classified as an ALERT based on uncontrolled water level decrease in spent fuel pooi with irradiated fuel assemblies expected to result in irradiated fuel assemblies being uncovered.

LOCATION OF PERFORMANCE: Classroom REFERENCES/PROCEDURES NEEDED: EPIP 1, EPIP 3 VALIDATION TIME: 30 minutes MAX. TIME ALLOWED: 15 minutes to classify and 15 minutes to notify PERFORMANCE TIME:

COMMENTS:______________________________

Additional comment sheets attached? YES NO RESULTS: SATISFACTORY UNSATISFACTORY SIGNATURE: DATE:

EXAMINER

INITIAL CONDITIONS: You are the Shift Manager (SM). Unit 1 and Unit 2 are at 100% power.

The Unit 1 board operator has just acknowledged alarm Start of Strong Motion Accelerograph, 1-XA-55-22C, Window 5 and multiple personnel in the Unit 1/2 Control Room felt the ground shake. The Unit 2 board operator then acknowledged alarm, Fuel Pool Skimmer Surge Tank Level Lo/Lo-Lo, and referred to ARP 2-XA-55-4C, Window 4. An AUO was dispatched to panels 25-15 and 25-16. Subsequently, alarms, Fuel Pool System Abnormal, 2-XA-55-4C, Window 1 AND Fuel Pool Floor Area Radiation High, 2-XA-55-3A, Window 1 were received.

The AUO determines the cause of the alarms to be lowering level in the Spent Fuel Storage Pool.

The AUO reports that the Fuel Pool liner appears to be leaking and level is slowly trending downward. Condensate makeup valve 2-SHV-078-0532 is danger tagged closed and all other methods of makeup to the Spent Fuel Storage Pool are unavailable. System Engineering has determined that it will be one (1) hour before the fuel in the Spent Fuel Pool will be in danger of being uncovered. 2-SHV-078-0532, Condensate makeup valve, cannot be untagged for another (2) hours to provide an adequate makeup source.

The TSC and CECC are not staffed.

Reactor Water Level (+33 inches on normal range) and steady Reactor Pressure 1035 psig and steady DW Pressure 1.35 psig and steady DW Temperature 148 degrees F and steady DW Radiation RR-90-256 reading normal Torus Temperature 89 F° and steady Torus Pressure 0.20 psig and steady Torus Level -1 inch on narrow range and steady Fuel Pool Level 2 feet below normal (trending down slowly at approximately 4 inches/minute)

Radiation around fuel pool 2-RI-90-IA indicates 21 mR/HR and slowly rising 2-RT-90-2A indicates 20 mR/HR and slowly rising 2-RI-90-3A indicates 20 mR/HR and slowly rising Wind Direction 1050 Wind Speed 20 mph NOTE: No abnormal radiological release is expected offsite.

INITIATING CUE: Identify the HIGHEST REQUIRED emergency classification, and complete the associated initial notification form. Raise your hand immediately once you have classified the event, and the examiner will then provide you with the EPIP youve chosen so you can begin completing the initial notification form.

JPM is Time Critical

Admin SRO A4 PAGE 3 OF 5 Classroom INITIAL CONDITIONS: You are the Shift Manager (SM). Unit 1 and Unit 2 are at 100% power.

The Unit I board operator has just acknowledged alarm Start of Strong Motion Accelerograph, 1-XA-55-22C, Window 5 and multiple personnel in the Unit 1/2 Control Room felt the ground shake. The Unit 2 board operator then acknowledged alarm, Fuel Pool Skimmer Surge Tank Level Lo/Lo-Lo, and referred to ARP 2-XA-55-4C, Window 4. An AUO was dispatched to panels 25-15 and 25-16. Subsequently, alarms, Fuel Pool System Abnormal, 2-XA-55-4C, Window I AND Fuel Pool Floor Area Radiation High, 2-XA-55-3A, Window 1 were received.

The AUO determines the cause of the alarms to be lowering level in the Spent Fuel Storage Pool.

The AUO reports that the Fuel Pool liner appears to be leaking and level is slowly trending downward. Condensate makeup valve 2-SHV-078-0532 is danger tagged closed and all other methods of makeup to the Spent Fuel Storage Pool are unavailable. System Engineering has determined that it will be one (1) hour before the fuel in the Spent Fuel Pool will be in danger of being uncovered. 2-SHV-078-0532, Condensate makeup valve, cannot be untagged for another (2) hours to provide an adequate makeup source.

The TSC and CECC are not staffed.

Reactor Water Level (+33 inches on normal range) and steady Reactor Pressure 1035 psig and steady DW Pressure 1.35 psig and steady DW Temperature 148 degrees F and steady DW Radiation RR-90-256 reading normal Torus Temperature 89 F° and steady Torus Pressure 0.20 psig and steady Torus Level -1 inch on narrow range and steady Fuel Pool Level 2 feet below normal (trending down slowly at approximately 4 inches/minute)

Radiation around fuel pool 2-RI-90-1A indicates 21 mRIHR and slowly rising 2-RI-90-2A indicates 20 mR/HR and slowly rising 2-Rl-90-3A indicates 20 mR/HR and slowly rising Wind Direction 105° Wind Speed 20 mph NOTE: No abnormal radiological release is expected offsite.

INITIATING CUE: Identify the HIGHEST REQUIRED emergency classification, and complete the associated initial notification form. Raise your hand immediately once you have classified the event, and the examiner will then provide you with the EPIP youve chosen so you can begin completing the initial notification form.

JPM is Time Critical

Adrriin SRO A4 PAGE 4 OF 5 START TIME____

Performance Step 1: Critical X Not Critical Refers to EPIP 1 to classif emergency event.

Standard:

SHIFT MANAGER refers to EPIP land declares an ALERT, EAL l.1-A2, based on uncontrolled water level decrease in Spent Fuel Storage Pool expected to result in irradiated fuel assemblies being uncovered.

SAT_ UNSAT N/A COMMENTS:___________________________

TIME Classified

Adniin SRO A4 PAGE 5 OF 5 START TIME____

Performance Step 2: Critical Not Critical Implements EPIP-3 Alert and completes Appendix A of EPIP 3 Standard:

Shift Manager completes Appendix A of EPIP 3 within 15 minutes of event classification SAT_ UNSAT N/A COMMENTS:_____________________________

TIME Appendix A Complete Performance Step 3: Critical X Not Critical Completes Appendix A of EPIP 3 Standard:

Following are Critical portions of Appendix A: EAL Designator 1.1-A2, Unit 2 is checked, Time and Date Event declared, PAR recommendation NONE is checked, and This is a drill is checked.

SAT_ UNSAT N/A COMMENTS:________________________________

END OF TASK

BROWNS FERRY ALERT EPIP3 APPENDIX A Page 1 of I ALERT INITIAL NOTIFICATION FORM

1. This is a Drill Q This is an Actual Event Repeat This is an Actual Event

2. This is No.frit. , Browns Ferry has declared an ALERT affecting:

fl UNIT 1 3 SUNIT2 [] UNIT 3 [] COMMON

3. EAL Designator: 1. 1 2-. (USE ONLY ONE EAL DESIGNATOR)

4. Brief Description of the Event:

(iAcoa\4rot(tA tijoc(er I,. vet cleSe_ ; ,c/

S4vr fooI expeo1 if jesul( / ;rr.d;4kd f(

se(ec ,e;yi t,icovcrS.

5. Radiological Conditions: (Check one under both Airborne and Liquid column.)

Airborne Releases Offsite Liquid Releases Offsite Minor releases within federally pproved limits 1 (Minor releases within federally approved limits 1

Q Releases above federally approved limits 1 Li Releases above federally approved limits 1

L1 Release information not known LJ Release information not known

( Tech Specs!ODCM) ( Tech SpecsIODCM)

6. Event Declared: Time: gfliL OCL..rtO( Date: fq1

7. Provide Protective Action Recommendation: None

8. Please repeat the information you have received to ensure accuracy.

9. ODS FAX number 5-7514620 State of Alabama FAX number 9-1 -205-280-2495 E I 4

r.+Ia PAGE 8 OF 24 REViSION 0033

ML12331A314

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